AmeriGas Partners (APU) 10-K 20 Nov 18 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Sep. 30, 2018	Nov. 13, 2018	Mar. 31, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	AMERIGAS PARTNERS LP
Entity Central Index Key	932,628
Document Type	10-K
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 2,760,131,827
Entity Common Stock, Shares Outstanding		92,977,072

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Current assets:
Cash and cash equivalents	$ 6,878	$ 7,316
Accounts receivable (less allowances for doubtful accounts of $12,825 and $11,820, respectively)	206,576	197,776
Accounts receivable — related parties	3,248	3,665
Inventories	130,527	116,679
Derivative instruments	38,661	30,483
Prepaid expenses	27,981	25,605
Other current assets	38,020	32,250
Total current assets	451,891	413,774
Property, plant and equipment (less accumulated depreciation of $1,151,726 and $1,511,890, respectively)	1,148,383	1,206,710
Goodwill	2,003,671	2,002,010
Intangible assets	279,608	390,040
Derivative instruments	6,347	1,320
Other assets	35,918	45,407
Total assets	3,925,818	4,059,261
Current liabilities:
Current maturities of long-term debt	8,626	8,447
Short-term borrowings	232,000	140,000
Accounts payable — trade	137,050	119,686
Accounts payable — related parties	1,482	304
Employee compensation and benefits accrued	56,557	45,926
Interest accrued	44,574	44,135
Customer deposits and advances	91,829	109,453
Other current liabilities	105,910	113,581
Total current liabilities	678,028	581,532
Long-term debt	2,561,007	2,563,832
Other noncurrent liabilities	117,115	130,826
Total liabilities	3,356,150	3,276,190
Commitments and contingencies (Note 12)
AmeriGas Partners, L.P. partners’ capital:
Common unitholders (units issued — 92,977,072 and 92,958,586, respectively)	523,925	733,104
General partner	12,682	14,795
Total AmeriGas Partners, L.P. partners’ capital	536,607	747,899
Noncontrolling interest	33,061	35,172
Total partners’ capital	569,668	783,071
Total liabilities and partners’ capital	$ 3,925,818	$ 4,059,261

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Statement of Financial Position [Abstract]
Accounts receivable, allowances for doubtful accounts	$ 12,825	$ 11,820
Property, plant and equipment, accumulated depreciation and amortization	$ 1,151,726	$ 1,511,890
Common unitholders, units issued	92,977,072	92,958,586

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Revenues:
Propane	$ 2,545,794	$ 2,183,538	$ 2,053,160
Other	277,184	269,957	258,657
Revenues	2,822,978	2,453,495	2,311,817
Costs and expenses:
Cost of sales — propane (excluding depreciation and amortization shown below)	1,215,616	891,261	719,842
Cost of sales — other (excluding depreciation and amortization shown below)	86,576	80,611	78,857
Operating and administrative expenses	923,064	915,133	928,786
Impairment of tradenames and trademarks	75,000	0	0
Depreciation and amortization	185,753	190,505	189,980
Other operating income, net	(24,373)	(11,873)	(28,252)
Costs and expenses	2,461,636	2,065,637	1,889,213
Operating income	361,342	387,858	422,604
Loss on extinguishments of debt	0	(59,729)	(48,889)
Interest expense	(163,125)	(160,226)	(164,095)
Income before income taxes	198,217	167,903	209,620
Income tax (expense) benefit	(4,215)	(2,034)	1,573
Net income including noncontrolling interest	194,002	165,869	211,193
Deduct net income attributable to noncontrolling interest	(3,480)	(3,810)	(4,209)
Net income attributable to AmeriGas Partners, L.P.	190,522	162,059	206,984
General partner’s interest in net income attributable to AmeriGas Partners, L.P.	47,226	45,146	40,227
Limited partners’ interest in net income attributable to AmeriGas Partners, L.P.	$ 143,296	$ 116,913	$ 166,757
Income per limited partner unit (Note 2):
Basic (in dollars per unit)	$ 1.54	$ 1.25	$ 1.77
Diluted (in dollars per unit)	$ 1.54	$ 1.25	$ 1.77
Weighted-average limited partner units outstanding (thousands):
Basic (in units)	93,034	92,996	92,949
Diluted (in units)	93,086	93,050	93,023

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income including noncontrolling interest	$ 194,002	$ 165,869	$ 211,193
Adjustments to reconcile net income including noncontrolling interest to net cash provided by operating activities:
Depreciation and amortization	185,753	190,505	189,980
Provision for uncollectible accounts	14,016	17,693	11,215
Loss on extinguishments of debt	0	59,729	48,889
Change in unrealized gains and losses on derivative instruments	(12,473)	(31,062)	(66,079)
Impairment of tradenames and trademarks	75,000	0	0
Other, net	(1,110)	23,350	2,112
Net change in:
Accounts receivable	(22,849)	(35,132)	3,963
Inventories	(13,783)	(37,398)	15,478
Accounts payable	18,573	26,325	(5,267)
Other current assets	(393)	(8,661)	3,895
Other current liabilities	(26,467)	(14,436)	7,564
Net cash provided by operating activities	410,269	356,782	422,943
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(101,277)	(98,164)	(101,693)
Proceeds from disposals of assets	27,180	19,935	14,636
Acquisitions of businesses, net of cash acquired	(10,090)	(36,824)	(37,560)
Net cash used by investing activities	(84,187)	(115,053)	(124,617)
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions	(402,645)	(398,877)	(387,659)
Noncontrolling interest activity	(5,591)	(3,626)	(5,378)
Increase (decrease) in short-term borrowings	92,000	(13,200)	85,100
Issuance of long-term debt, net of issuance costs	0	1,207,727	1,331,293
Repayment of long-term debt, including redemption premiums	(9,054)	(1,043,744)	(1,321,750)
Proceeds associated with equity based compensation plans, net of tax withheld	801	1,465	1,127
Capital contributions from General Partner	8	15	11
Other	(2,039)	0	0
Net cash used by financing activities	(326,520)	(250,240)	(297,256)
Cash and cash equivalents (decrease) increase	(438)	(8,511)	1,070
CASH AND CASH EQUIVALENTS
End of year	6,878	7,316	15,827
Beginning of year	7,316	15,827	14,757
(Decrease) increase	(438)	(8,511)	1,070
SUPPLEMENTAL CASH FLOW INFORMATION
Cash paid for interest	$ 158,421	$ 152,165	$ 167,460

Consolidated Statements of Part

Consolidated Statements of Partners' Capital - USD ($) $ in Thousands	Total	Total AmeriGas Partners, L.P. partners’ capital	Common unitholders	General partner	Noncontrolling Interest
Beginning balance (in units) at Sep. 30, 2015			92,889,980
Beginning balance at Sep. 30, 2015	$ 1,200,373	$ 1,164,216	$ 1,145,291	$ 18,925	$ 36,157
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income including noncontrolling interest	211,193	206,984	166,757	40,227	4,209
Distributions	(393,076)	(387,659)	(345,644)	(42,015)	(5,417)
Unit-based compensation expense	1,242	1,242	$ 1,242
General Partner contribution to AmeriGas Propane, L.P.	39				39
Common Units issued in connection with employee and director plans, net of tax withheld (in units)			33,430
Common Units issued in connection with employee and director plans, net of tax withheld	(562)	(562)	$ (573)	11
Ending balance (in units) at Sep. 30, 2016			92,923,410
Ending balance at Sep. 30, 2016	1,019,209	984,221	$ 967,073	17,148	34,988
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income including noncontrolling interest	165,869	162,059	116,913	45,146	3,810
Distributions	(404,105)	(398,877)	(351,363)	(47,514)	(5,228)
Unit-based compensation expense	1,237	1,237	$ 1,237
General Partner contribution to AmeriGas Propane, L.P.	1,602				1,602
Common Units issued in connection with employee and director plans, net of tax withheld (in units)			35,176
Common Units issued in connection with employee and director plans, net of tax withheld	(741)	(741)	$ (756)	15
Ending balance (in units) at Sep. 30, 2017			92,958,586
Ending balance at Sep. 30, 2017	783,071	747,899	$ 733,104	14,795	35,172
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income including noncontrolling interest	194,002	190,522	143,296	47,226	3,480
Distributions	(408,236)	(402,645)	(353,298)	(49,347)	(5,591)
Unit-based compensation expense	1,273	1,273	$ 1,273
Common Units issued in connection with employee and director plans, net of tax withheld (in units)			18,486
Common Units issued in connection with employee and director plans, net of tax withheld	(442)	(442)	$ (450)	8
Ending balance (in units) at Sep. 30, 2018			92,977,072
Ending balance at Sep. 30, 2018	$ 569,668	$ 536,607	$ 523,925	$ 12,682	$ 33,061

Nature of Operations

Nature of Operations	12 Months Ended
	Sep. 30, 2018
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”). AmeriGas Partners and AmeriGas OLP are Delaware limited partnerships. AmeriGas Partners, AmeriGas OLP and all of their subsidiaries are collectively referred to herein as “the Partnership” or “we.” AmeriGas OLP is engaged in the distribution of propane and related equipment and supplies. AmeriGas OLP 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 September 30, 2018 , 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 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 AmeriGas OLP 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 13 ).

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Basis of Presentation. Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). 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. Certain prior-year amounts have been reclassified to conform to the current-year presentation. Principles of Consolidation. The consolidated financial statements include the accounts of AmeriGas Partners, its majority-owned subsidiary AmeriGas OLP, and its 100% -owned finance subsidiaries AmeriGas Finance Corp., AmeriGas Eagle Finance Corp., AP Eagle Finance Corp., and AmeriGas Finance LLC. AmeriGas Partners and AmeriGas OLP are under the common control of the General Partner. The General Partner of AmeriGas OLP, which is also the General Partner of AmeriGas Partners, makes all decisions for AmeriGas OLP; limited partners of AmeriGas OLP do not have the ability to remove the General Partner or participate in the decision-making for AmeriGas OLP. The accounts of AmeriGas OLP are included based upon the determination that AmeriGas Partners has a controlling financial interest in and is the primary beneficiary of AmeriGas OLP. We eliminate intercompany accounts and transactions when we consolidate. Finance Corps. AmeriGas Finance Corp., AmeriGas Eagle 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. Fair Value Measurements. The Partnership applies fair value measurements on a recurring and, as otherwise required under GAAP, also on a nonrecurring basis. Fair value in GAAP is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value measurements performed on a recurring basis principally relate to commodity derivative instruments. GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). A level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: • Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. • Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. We evaluate the need for credit adjustments to our derivative instrument fair values. These credit adjustments were not material to the fair values of our derivative instruments. Derivative Instruments. Derivative instruments are reported on the Consolidated Balance Sheets at their fair values, unless the normal purchase and normal sale (“NPNS”) exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it qualifies and is designated as a hedge for accounting purposes. We do not currently have derivative instruments that are designated and qualify as cash flow hedges. Changes in the fair values of our commodity derivative instruments are reflected in “Cost of sales - propane” on the Consolidated Statements of Operations. Cash flows from commodity derivative instruments are included in cash flows from operating activities. For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 16 . Revenue Recognition. Revenues from the sale of propane are recognized principally upon delivery. Revenues from the sale of appliances and equipment are recognized at the later of sale or installation. Revenues from repair or maintenance services are recognized upon completion of services. Revenues from annually billed fees are generally recorded on a straight-line basis over one year. We present revenue-related taxes collected on behalf of customers and remitted to taxing authorities, principally sales and use taxes, on a net basis. Accounts Receivable. Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience and the assessment of the collectability of specific amounts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. Delivery Expenses. Expenses associated with the delivery of propane to customers (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “ Operating and administrative expenses ” on the Consolidated Statements of Operations. Depreciation expense associated with delivery vehicles is classified in “ Depreciation and amortization ” on the Consolidated Statements of Operations. Income Taxes. AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to their individual partners. AmeriGas OLP has corporate subsidiaries which are directly subject to federal and state income taxes. Accordingly, our consolidated financial statements reflect income taxes related to these corporate subsidiaries. Legislation in certain states allows for taxation of partnerships’ income and the accompanying financial statements reflect state income taxes resulting from such legislation. Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders. This is a result of (1) differences between the tax basis and financial reporting basis of assets and liabilities and (2) the taxable income allocation requirements of the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P., as amended (“Partnership Agreement”) and the Internal Revenue Code. Cash and Cash Equivalents. For cash flow purposes, cash and cash equivalents include cash on hand, cash in banks and highly liquid investments with maturities of three months or less when purchased. Inventories. Our inventories are stated at the lower of cost or net realizable value. We determine cost using an average cost method for propane, specific identification for appliances and the first-in, first-out (“FIFO”) method for all other inventories. Property, Plant and Equipment and Related Depreciation. We record property, plant and equipment at cost. The amounts we assign to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition. When we retire or otherwise dispose of plant and equipment, we eliminate the associated cost and accumulated depreciation and recognize any resulting gain or loss in " Other operating income, net " on the Consolidated Statements of Operations. We record depreciation expense on plant and equipment using the straight-line method over estimated service lives. At September 30, 2018 , estimated useful lives by type were as follows: Asset Type Minimum Estimated Useful Life (in years) Maximum Estimated Useful Life (in years) Buildings and improvements 15 40 Storage, customer tanks and cylinders and related assets 6 30 Vehicles, equipment and office furniture and fixtures 3 10 Computer software 3 10 We include in property, plant and equipment costs associated with computer software we develop or obtain for use in our businesses. We classify amortization of computer software and related costs included in property, plant and equipment as depreciation expense. Depreciation expense totaled $145,826 , $152,511 and $151,575 for Fiscal 2018, Fiscal 2017 and Fiscal 2016, respectively. No depreciation expense is included in cost of sales on the Consolidated Statements of Operations. Segment Information. We have determined that we have a single reportable operating segment that engages in the distribution of propane and related equipment and supplies. No single customer represents ten percent or more of consolidated revenues. In addition, substantially all of our revenues are derived from sources within the United States and substantially all of our long-lived assets are located in the United States. Goodwill and Intangible Assets. We amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. Estimated useful lives of definite-lived intangible assets, consisting of customer relationships, noncompete agreements and, beginning in April 2018, the carrying amounts of tradenames and trademarks, do not exceed 15 years. We review definite-lived intangible assets for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may not be recoverable. Determining whether an impairment loss occurred requires comparing the carrying amount to the sum of undiscounted cash flows expected to be generated by the asset. Prior to April 2018, our tradenames and trademark intangible assets with indefinite lives were not amortized but were tested annually for impairment (and more frequently if indicators of impairment were present). We tested these indefinite-lived intangible assets by comparing their book values to their estimated fair values. The estimated fair values of the Partnership’s tradenames and trademarks were determined using the “relief from royalty” method. This method requires the Partnership to, among other things, forecast future revenues expected to be derived from the use of these tradenames and trademarks and to determine a fair royalty rate from their use. These future estimated royalties are then discounted to present value using a discount rate based upon a weighted average cost of capital adjusted for the risks inherent in the forecasted financial information and those specific to the asset itself. In April 2018, the Partnership’s senior management approved a plan to discontinue the use of these tradenames and trademarks, primarily associated with its January 2012 acquisition of Heritage Propane, over a period of approximately three years. As a result, during the third quarter of Fiscal 2018, the Partnership determined that these tradenames and trademarks no longer had indefinite lives and, in accordance with GAAP associated with intangible assets, adjusted the carrying amounts of these tradenames and trademarks to their estimated fair values. For further information on these tradenames and trademarks, see Notes 10 and 15 . We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is the operating segment, or a business one level below the operating segment (a component) if discrete financial information is prepared and regularly reviewed by segment management. Components are aggregated as a single reporting unit if they have similar economic characteristics. A reporting unit with goodwill is required to perform an impairment test annually or whenever events or circumstances indicate that the value of goodwill may be impaired. We are required to recognize an impairment charge under GAAP if the carrying amount of a reporting unit exceeds its fair value. From time to time, we may assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. Among the significant factors considered in performing the qualitative assessment is the market price of AmeriGas Partners Common Units. We may bypass the qualitative assessment and perform the quantitative assessment by comparing the fair value of the reporting unit with its carrying amount, including goodwill. We determine fair value generally based on a weighting of income and market approaches. For purposes of the income approach, fair value is determined based upon the present value of the estimated future cash flows, including an estimate of the terminal value based upon these cash flows, discounted at an appropriate risk-adjusted rate. We use our internal forecasts to estimate future cash flows which may include estimates of long-term future growth rates based upon our most recent long-term outlook. Cash flow estimates used to establish fair values under our income approach involve management judgments based on a broad range of information and historical results. In addition, external economic and competitive conditions can influence future performance. For purposes of the market approach, we use valuation multiples for companies comparable to our reporting unit. The market approach requires judgment to determine the appropriate valuation multiple. If the carrying amount of our reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill. There were no accumulated goodwill impairment losses at September 30, 2018 and 2017 . There were no provisions for goodwill impairments recorded during Fiscal 2018 , Fiscal 2017 or Fiscal 2016 and there were no provisions for intangible asset impairment recorded during Fiscal 2017 or Fiscal 2016 . No amortization expense of intangible assets is included in cost of sales in the Consolidated Statements of Operations. For further information on our goodwill and intangible assets, see Note 10 . Impairment of Long-Lived Assets. We evaluate long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. We evaluate recoverability based upon undiscounted future cash flows expected to be generated by such assets. If the undiscounted future cash flows indicate that the recorded amounts are not expected to be recoverable, such long-lived assets are reduced to their estimated fair values. No material provisions for impairments were recorded during Fiscal 2018 , Fiscal 2017 or Fiscal 2016 . Debt Issuance Costs. We defer and amortize debt issuance costs and debt premiums and discounts over the expected lives of the respective debt issues considering maturity dates. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issue costs associated with revolving credit agreements are included in “Other assets” on the Consolidated Balance Sheets. Amortization of the debt issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt prior to their stated maturity are generally recognized and included in “Loss on extinguishments of debt” on the Consolidated Statements of Operations. Customer Deposits. We offer certain of our customers prepayment programs which require customers to pay a fixed periodic amount or to otherwise prepay a portion of their anticipated propane purchases. Customer prepayments, in excess of associated billings, are classified as “ Customer deposits and advances ” on the Consolidated Balance Sheets. Equity-Based Compensation. The General Partner may grant Common Unit awards (as further described in Note 11 ) to employees and non-employee directors under its Common Unit plans, and employees of the General Partner may be granted stock options for UGI Common Stock. All of our equity-based compensation is measured at fair value on the grant date, date of modification or end of the period, as applicable, and recognized in earnings over the requisite service period. Depending upon the settlement terms of the awards, all or a portion of the fair value of equity-based awards may be presented as a liability or as equity on our Consolidated Balance Sheets. Equity-based compensation costs associated with the portion of Common Unit awards classified as equity are measured based upon their estimated fair value on the date of grant or modification. Equity-based compensation costs associated with the portion of Common Unit awards classified as liabilities are measured based upon their estimated fair value at the date of grant and remeasured as of the end of each period. We account for forfeitures of equity-based payments when they occur. For a further description of our equity-based compensation plans and related disclosures, see Note 11 . Environmental Matters . We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. Under GAAP, if the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, such liabilities are discounted to reflect the time value of money. Loss Contingencies Subject to Insurance. The Partnership is subject to risk of loss for general, automobile and product liability, and workers’ compensation claims for which it obtains insurance coverage under insurance policies that are subject to self-insured retentions or deductibles. In accordance with GAAP, the Partnership establishes reserves for pending legal actions, and for pending and incurred but not reported claims associated with general, automobile and workers’ compensation when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. The Partnership maintains insurance coverage such that its net exposure for claims covered by insurance would be limited to the self-insured retentions or deductibles, claims above which would be paid by the insurance carrier. For such claims, the Partnership records a receivable related to the amount of the liability expected to be paid by insurance. Allocation of Net Income (Loss). 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 Partnership Agreement (see Note 5 ). 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: 2018 2017 2016 Net income attributable to AmeriGas Partners, L.P. $ 190,522 $ 162,059 $ 206,984 Adjust for general partner share and theoretical distributions of net income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs (47,233 ) (46,054 ) (42,024 ) Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs $ 143,289 $ 116,005 $ 164,960 Weighted average Common Units outstanding — basic (thousands) 93,034 92,996 92,949 Potentially dilutive Common Units (thousands) 52 54 74 Weighted average Common Units outstanding — diluted (thousands) 93,086 93,050 93,023 Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for Fiscal 2017 and Fiscal 2016 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 $0.01 , and $0.02 , respectively. There was no such effect for Fiscal 2018. 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. Correction of Prior Period Errors. During the first quarter of Fiscal 2017, the Partnership determined that it had not properly recorded gains on sales of property, plant and equipment relating to certain assets acquired in the acquisition of Heritage Propane in Fiscal 2012. Also, during the fourth quarter of Fiscal 2017, the Partnership determined that it had not properly recorded depreciation expense on certain assets acquired in the acquisition of Heritage Propane in Fiscal 2012. The partnership evaluated the impact of these errors on prior periods and determined that the effects were not material to the financial statements for Fiscal 2017, or any prior period financial statements, and recorded the cumulative effect of the error in accounting for certain disposals as of October 1, 2016, and recorded the cumulative effect of the error in accounting for depreciation expense relating to certain assets acquired in the Heritage Propane acquisitions as of July 1, 2017. The correction of the error related to gains on sales of certain property, plant and equipment obtained in the Heritage Propane acquisition decreased Fiscal 2017 other operating income, net by $8,847 and decreased Fiscal 2017 depreciation by $1,162 . The correction of the error related to depreciation expense of certain assets acquired in the Heritage Propane acquisition increased Fiscal 2017 depreciation by $7,350 .

Accounting Changes

Accounting Changes	12 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Accounting Changes	Accounting Changes New Accounting Standards Adopted Effective October 1, 2018 Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). The guidance provided under this ASU, as amended, supersedes the revenue recognition requirements in Accounting Standards Codification (“ASC”) No. 605, “Revenue Recognition,” and most industry-specific guidance included in the ASC. ASU 2014-09 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. In addition, the new guidance requires enhanced disclosures to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers and requires, among other things, the disaggregation of revenues into categories that show how economic factors affect the nature, timing and uncertainty of revenues and cash flows. We adopted this ASU effective October 1, 2018, using the modified retrospective transition method. The Partnership has completed the process of analyzing the impact of the new guidance using an integrated approach which includes evaluating differences in the amount and timing of revenue recognition from applying the requirements of the new guidance, reviewing its accounting policies and practices, and assessing the need for changes to its processes, accounting systems and design of internal controls. The adoption of this new guidance will not have a material impact on our consolidated financial statements. Cloud Computing Implementation Costs. In August 2018, the FASB issued ASU No. 2018-15, “Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The new guidance requires a customer in a cloud computing arrangement that is a service contract to capitalize certain implementation costs as if the arrangement was an internal-use software project. These deferred implementation costs are expensed over the fixed, noncancelable term of the service arrangement plus any reasonably certain renewal periods. The new guidance also requires the entity to present the expense related to the capitalized implementation costs in the same income statement line as the hosting service fees; to classify payments for capitalized implementation costs in the statement of cash flows in the same manner as payments for hosting service fees; and to present the capitalized implementation costs in the balance sheet in the same line item in which prepaid hosting service fees are presented. The new guidance can be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. We adopted this ASU effective October 1, 2018, and applied the guidance prospectively to all implementation costs associated with cloud computing arrangements that are service contracts incurred after October 1, 2018. Other Accounting Principles Not Yet Adopted Fair Value Measurements Disclosures. In August 2018, the FASB issued ASU No. 2018-13, “Changes to the Disclosure Requirements for Fair Value Measurement.” This ASU modifies the disclosure requirements for fair value measurements by removing, modifying, or adding certain disclosures. The amendments in this ASU are effective for annual periods beginning after December 15, 2019 (Fiscal 2021). The guidance regarding removed and modified disclosures will be adopted on a retrospective basis and the guidance regarding new disclosures will be adopted on a prospective basis. Early adoption is permitted. The Partnership is in the process of assessing the impact on its financial statement disclosures from the adoption of the new guidance and determining the period in which the new guidance will be adopted. Derivatives and Hedging. In August 2017, the FASB issued ASU No. 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” This ASU amends and simplifies existing guidance to allow companies to more accurately present the economic effects of risk management activities in the financial statements. The amendments in this ASU are effective for the Partnership for interim and annual periods beginning October 1, 2019 (Fiscal 2020). Early adoption is permitted. For cash flow and net investment hedges as of the adoption date, the guidance requires a modified retrospective approach. The amended presentation and disclosure guidance is required only prospectively. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the period in which the new guidance will be adopted. Leases. In February 2016, the FASB issued ASU No. 2016-02, "Leases." This ASU, as subsequently updated, 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 the Partnership for interim and annual periods beginning October 1, 2019 (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 unless an entity chooses the transition option in ASU 2018-11, “Leases: Targeted Improvements” which, among other things, provides entities with a transition option to recognize the cumulative-effect adjustment from the modified retrospective application to the opening balance of retained earnings in the period of adoption. We will adopt ASU No. 2016-02, as updated, effective October 1, 2019 and expect to elect the proposed transition option which would allow the Partnership to maintain historical presentation for periods before October 1, 2019. The Partnership has completed a preliminary assessment for evaluating the impact of the guidance and anticipates that its adoption will result in a significant amount of right-of-use assets and lease liabilities for leases in effect at the adoption date. The Partnership has begun implementation activities including accumulating contracts and lease data in formats compatible with a new lease management system that will assist with the initial adoption of the standard.

Acquisitions

Acquisitions	12 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Acquisitions	Acquisitions During Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , AmeriGas OLP acquired a number of domestic retail propane distribution businesses for total net cash consideration of $10,090 , $36,824 and $37,560 , respectively. In conjunction with these acquisitions, liabilities of $2,695 in Fiscal 2018 , $10,848 in Fiscal 2017 and $11,819 in Fiscal 2016 were incurred. The operating results of these businesses have been included in our operating results from their respective dates of acquisition. The total purchase price of these acquisitions has been allocated to the assets acquired and liabilities assumed as follows: 2018 2017 2016 Net current assets (liabilities) $ 926 $ 1,176 $ (162 ) Property, plant and equipment 2,987 6,712 9,322 Goodwill 4,528 23,029 24,213 Customer relationships and noncompete agreements (estimated useful life of 10 and 5 years, respectively) 4,344 16,714 16,006 Other assets — 41 — Total $ 12,785 $ 47,672 $ 49,379 The goodwill above results principally from anticipated synergies between the acquired businesses and our existing propane business. The pro forma effects of these transactions were not material.

Quarterly Distributions of Avai

Quarterly Distributions of Available Cash	12 Months Ended
	Sep. 30, 2018
Distributions Made to Members or Limited Partners [Abstract]
Quarterly Distributions of Available Cash	Quarterly Distributions of Available Cash The Partnership makes distributions to its partners approximately 45 days after the end of each fiscal quarter in a total amount equal to its Available Cash (as defined in the Partnership Agreement) for such quarter. Available Cash generally means: 1. all cash on hand at the end of such quarter, plus 2. all additional cash on hand as of the date of determination resulting from borrowings after the end of such quarter, less 3. the amount of cash reserves established by the General Partner in its reasonable discretion. The General Partner may establish reserves for the proper conduct of the Partnership’s business and for distributions during the next four quarters. Distributions of Available Cash are made 98% to limited partners and 2% to the General Partner (giving effect to the 1.01% interest of the General Partner in distributions of Available Cash from AmeriGas OLP to AmeriGas Partners) until Available Cash exceeds the Minimum Quarterly Distribution of $0.55 and the First Target Distribution of $0.055 per Common Unit (or a total of $0.605 per Common Unit). When Available Cash exceeds $0.605 per Common Unit in any quarter, the General Partner will receive a greater percentage of the total Partnership distribution (the “incentive distribution”) but only with respect to the amount by which the distribution per Common Unit to limited partners exceeds $0.605 . Quarterly distributions of Available Cash per limited partner unit paid during Fiscal 2018 , Fiscal 2017 and Fiscal 2016 were as follows: 2018 2017 2016 1st Quarter $ 0.95 $ 0.94 $ 0.92 2nd Quarter $ 0.95 $ 0.94 $ 0.92 3rd Quarter $ 0.95 $ 0.95 $ 0.94 4th Quarter $ 0.95 $ 0.95 $ 0.94 During Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , the Partnership made quarterly distributions to Common Unitholders in excess of $0.605 per limited partner unit. As a result, the General Partner received a greater percentage of the total Partnership distribution than its aggregate 2% general partner interest in AmeriGas OLP and AmeriGas Partners. During Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , the total amount of distributions received by the General Partner with respect to its aggregate 2% general partner ownership interests totaled $54,938 , $52,742 and $47,432 , respectively. Included in these amounts are incentive distributions received by the General Partner during Fiscal 2018 , Fiscal 2017 and Fiscal 2016 of $45,321 , $43,525 and $38,157 , respectively.

Debt

Debt	12 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Debt	Debt Long-term debt comprises the following at September 30: 2018 2017 AmeriGas Partners Senior Notes: 5.50% due May 2025 (a) $ 700,000 $ 700,000 5.875% due August 2026 (a) 675,000 675,000 5.75% due May 2027 (a) 525,000 525,000 5.625% due May 2024 (a) 675,000 675,000 Heritage Operating, L.P. (“HOLP”) Senior Secured Notes 7,516 11,348 Other 14,615 17,262 Total long-term debt 2,597,131 2,603,610 Less: unamortized debt issuance costs (27,498 ) (31,331 ) Less: current maturities (8,626 ) (8,447 ) Total long-term debt due after one year $ 2,561,007 $ 2,563,832 (a) AmeriGas Partners and AmeriGas Finance Corp. co-issued these senior notes. Scheduled principal repayments of long-term debt for each of the next five fiscal years ending September 30 are as follows: Fiscal 2019 — $8,758 ; Fiscal 2020 — $7,950 ; Fiscal 2021 — $3,559 ; Fiscal 2022 — $1,598 ; Fiscal 2023 — $266 . AmeriGas Partners Senior Notes During Fiscal 2017, AmeriGas Partners and AmeriGas Finance Corp. issued, in underwritten offerings, $700,000 principal amount of 5.50% Senior Notes due May 2025 and $525,000 principal amount of 5.75% Senior Notes due May 2027 (collectively, the “AmeriGas 2017 Senior Notes”). The AmeriGas 2017 Senior Notes rank equally with AmeriGas Partners’ existing outstanding senior notes. The net proceeds from the issuance of the AmeriGas 2017 Senior Notes were used (1) for the early repayment, pursuant to tender offers and notices of redemption, of all of AmeriGas Partners’ 7.00% Senior Notes, having an aggregate principal balance of $980,844 plus accrued and unpaid interest and early redemption premiums, and (2) for general corporate purposes. During Fiscal 2016, AmeriGas Partners and AmeriGas Finance Corp. issued in an underwritten offering $675,000 principal amount of 5.625% Senior Notes due May 2024 and $675,000 principal amount of 5.875% Senior Notes due August 2026 (collectively, the “AmeriGas 2016 Senior Notes”). The AmeriGas 2016 Senior Notes rank equally with AmeriGas Partners’ existing outstanding senior notes. The net proceeds from the issuance of the AmeriGas 2016 Senior Notes were used (1) for the early repayment, pursuant to tender offers and notices of redemption, of all of AmeriGas Partners’ 6.50% Senior Notes, 6.75% Senior Notes and 6.25% Senior Notes, having an aggregate principal balance of $1,270,001 plus accrued and unpaid interest and early redemption premiums and (2) for general corporate purposes. In connection with the early repayments of the Partnership’s Senior Notes, during Fiscal 2017 and Fiscal 2016, the Partnership recognized losses which are reflected in “ Loss on extinguishments of debt ” on the Consolidated Statements of Operations and comprise the following: 2017 2016 Early redemption premiums $ 51,253 $ 39,569 Write-off of unamortized debt issuance costs 8,476 9,320 Loss on extinguishments of debt $ 59,729 $ 48,889 HOLP Senior Secured Notes The Partnership’s total long-term debt at September 30, 2018 and 2017 , includes $7,516 and $11,348 , respectively, of HOLP Senior Secured Notes including unamortized premium of $244 and $439 , respectively. The effective interest rate on the HOLP Notes is 6.75% at September 30, 2018 and 2017 . The HOLP Senior Secured Notes are collateralized by AmeriGas OLP’s receivables, contracts, equipment, inventory, general intangibles and cash. AmeriGas OLP Credit Agreement In December 2017, AmeriGas OLP entered into the Second Amended and Restated Credit Agreement (“AmeriGas OLP Credit Agreement”) with a group of banks. The AmeriGas OLP Credit Agreement amends and restates an AmeriGas OLP previously existing credit agreement (collectively, the “credit agreements”). The AmeriGas OLP Credit Agreement provides for borrowings up to $600,000 (including a $150,000 sublimit for letters of credit) and expires in December 2022. The AmeriGas OLP 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 AmeriGas OLP Credit Agreement, plus a margin. The applicable margin on base rate borrowings ranges from 0.50% to 1.75% , and the applicable margin on Eurodollar Rate borrowings ranges from 1.50% to 2.75% . The aforementioned margins on borrowings are dependent upon AmeriGas Partners’ ratio of debt to earnings before interest expense, income taxes, depreciation and amortization (each as defined in the AmeriGas OLP Credit Agreement). At September 30, 2018 and 2017 , there were $232,000 and $140,000 of borrowings outstanding under the credit agreements, which amounts are reflected as “ Short-term borrowings ” on the Consolidated Balance Sheets. The weighted-average interest rates on borrowings under the credit agreements at September 30, 2018 and 2017 were 4.58% and 3.74% , respectively. Issued and outstanding letters of credit, which reduce available borrowings under the credit agreements, totaled $63,497 and $67,211 at September 30, 2018 and 2017 , respectively. Restrictive Covenants The AmeriGas Partners Senior Notes restrict the ability of the Partnership and AmeriGas OLP to, among other things, incur additional indebtedness, make investments, incur liens, issue preferred interests, prepay subordinated indebtedness, and effect mergers, consolidations and sales of assets. Under the Senior Notes indentures, AmeriGas Partners is generally permitted to make cash distributions equal to available cash, as defined, as of the end of the immediately preceding quarter, if certain conditions are met. These conditions include: 1. no event of default exists or would exist upon making such distributions and 2. the Partnership’s consolidated fixed charge coverage ratio, as defined, is greater than 1.75 -to-1. If the ratio in item 2 above is less than or equal to 1.75 -to-1, the Partnership may make cash distributions in a total amount not to exceed $300,000 less the total amount of distributions made during the immediately preceding 16 Fiscal quarters. At September 30, 2018 , the Partnership was not restricted by the consolidated fixed charge coverage ratio from making cash distributions. See the provisions of the Partnership Agreement relating to distributions of Available Cash in Note 5 . The HOLP Senior Secured Notes contain restrictive covenants including the maintenance of financial covenants and limitations on the disposition of assets, changes in ownership, additional indebtedness, restrictive payments and the creation of liens. The financial covenants require AmeriGas OLP to maintain a ratio of Consolidated Funded Indebtedness to Consolidated EBITDA (as defined) below certain thresholds and to maintain a minimum ratio of Consolidated EBITDA to Consolidated Interest Expense (as defined). The AmeriGas OLP 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 AmeriGas OLP 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. At September 30, 2018 , the amount of net assets of the Partnership’s subsidiaries that was restricted from transfer as a result of the amount of Available Cash, computed in accordance with the Partnership Agreement, applicable debt agreements and AmeriGas OLP’s partnership agreement, totaled approximately $ 2,800,000 .

Employee Retirement Plans

Employee Retirement Plans	12 Months Ended
	Sep. 30, 2018
Retirement Benefits [Abstract]
Employee Retirement Plans	Employee Retirement Plans The General Partner sponsors a 401(k) savings plan for eligible employees. Participants in the savings plan may contribute a portion of their compensation on a before-tax basis. Generally, employee contributions are matched on a dollar-for-dollar ( 100% ) basis up to 5% of eligible compensation. The cost of benefits under our savings plan was $11,412 in Fiscal 2018 , $10,775 in Fiscal 2017 and $10,335 in Fiscal 2016 . The General Partner also sponsors a nonqualified deferred compensation plan and a nonqualified supplemental executive retirement plan. These plans provide benefits to executives that would otherwise be provided under the Partnership’s retirement plans but are prohibited due to Internal Revenue Code limits. Costs associated with these plans were not material in Fiscal 2018 , Fiscal 2017 and Fiscal 2016 .

Inventories

Inventories	12 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Inventories	Inventories Inventories comprise the following at September 30: 2018 2017 Propane gas $ 114,005 $ 99,035 Materials, supplies and other 10,546 11,899 Appliances for sale 5,976 5,745 Total inventories $ 130,527 $ 116,679 In addition to inventories on hand, we also enter into contracts to purchase propane to meet a portion of our supply requirements. Generally, these contracts are one - to three -year agreements subject to annual price and quantity adjustments.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment comprise the following at September 30: 2018 2017 Land $ 135,809 $ 135,965 Buildings and improvements 197,148 196,798 Transportation equipment 214,526 250,493 Storage facilities 212,686 268,415 Equipment, primarily cylinders and tanks 1,330,049 1,612,375 Work in process 27,859 19,517 Other 182,032 235,037 Gross property, plant and equipment 2,300,109 2,718,600 Less accumulated depreciation (1,151,726 ) (1,511,890 ) Net property, plant and equipment $ 1,148,383 $ 1,206,710

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Sep. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	Goodwill and Intangible Assets Changes in the carrying amount of goodwill are as follows: Balance September 30, 2016 $ 1,978,981 Acquisitions 23,029 Balance September 30, 2017 2,002,010 Acquisitions 4,528 Dispositions (2,867 ) Balance September 30, 2018 $ 2,003,671 The Partnership’s intangible assets comprise the following at September 30: 2018 2017 Customer relationships and noncompete agreements (subject to amortization) $ 497,373 $ 497,385 Trademarks and tradenames (subject to amortization) 7,944 — Trademarks and tradenames (not subject to amortization) — 82,944 Gross carrying amount 505,317 580,329 Accumulated amortization (225,709 ) (190,289 ) Intangible assets, net $ 279,608 $ 390,040 Amortization expense of intangible assets was $39,927 , $37,994 and $38,405 in Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , respectively. Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2019 — $40,389 ; Fiscal 2020 — $39,152 ; Fiscal 2021 — $35,914 ; Fiscal 2022 — $32,963 ; Fiscal 2023 — $31,627 . In April 2018, a plan to discontinue the use of indefinite-lived tradenames and trademarks, primarily those associated with the Partnership’s January 2012 acquisition of Heritage Propane, was presented to the Partnership’s senior management. After considering the merits of the plan, the Partnership’s senior management approved a plan to discontinue the use of these tradenames and trademarks over a period of approximately three years. As a result, during the third quarter of Fiscal 2018, the Partnership determined that these tradenames and trademarks no longer had indefinite lives and, in accordance with GAAP associated with intangible assets, adjusted the carrying amounts of these tradenames and trademarks to their estimated fair values of approximately $7,944 . During the third quarter of Fiscal 2018, the Partnership recorded a non-cash impairment charge of $75,000 which amount is reflected in “Impairment of tradenames and trademarks” on the Consolidated Statements of Operations, and is amortizing the remaining fair value of these tradenames and trademarks over their estimated period of benefit of three years. See Note 15 for further information on the determination of fair values for the affected tradenames and trademarks.

Partners' Capital and Equity Co

Partners' Capital and Equity Compensation Plans	12 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Partners' Capital and Equity Compensation Plans	Partners’ Capital and Equity Compensation Plans Partners’ Capital In accordance with the Partnership Agreement, the General Partner may, in its sole discretion, cause the Partnership to issue an unlimited number of additional Common Units and other equity securities of the Partnership ranking on a parity with the Common Units. On November 7, 2017, AmeriGas Partners entered into a Standby Equity Commitment Agreement (the “Commitment Agreement”) with the General Partner and UGI. Under the terms of the Commitment Agreement, UGI has committed to make up to $225,000 of capital contributions to the Partnership through July 1, 2019 (the “Commitment Period”). UGI’s capital contributions may be made from time to time during the Commitment Period upon request of the Partnership. There have been no capital contributions made to the Partnership under the Commitment Agreement. In consideration for any capital contributions pursuant to the Commitment Agreement, the Partnership will issue to UGI or a wholly owned subsidiary new Class B Common Units representing limited partner interests in the Partnership (“Class B Units”). The Class B Units will be issued at a price per unit equal to the 20 -day volume-weighted average price of the Partnership’s Common Units prior to the date of the Partnership’s related capital call. The Class B Units will be entitled to cumulative quarterly distributions at a rate equal to the annualized Common Unit yield at the time of the applicable capital call, plus 130 basis points. The Partnership may choose to make the distributions in cash or in kind in the form of additional Class B Units. While outstanding, the Class B Units will not be subject to any incentive distributions from the Partnership. At any time after five years from the initial issuance of the Class B Units, holders may elect to convert all or any portion of the Class B Units they own into Common Units on a one -for-one basis. At any time after six years from the initial issuance of the Class B Units, the Partnership may elect to convert all or any portion of the Class B Units into Common Units if (i) the closing trading price of the Common Units is greater than 110% of the applicable purchase price for the Class B Units and (ii) the Common Units are listed or admitted for trading on a National Securities Exchange. Upon certain events involving a change of control, and immediately prior to a liquidation or winding up of the Partnership, the Class B Units will automatically convert into Common Units on a one -for-one basis. Equity Compensation Plans The General Partner grants equity-based awards to employees and non-employee directors comprising grants of AmeriGas Partners equity instruments as further described below. We recognized total pre-tax equity-based compensation expense of $3,432 , $3,920 and $4,025 in Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , respectively. Under the AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P. (“2010 Plan”), the General Partner may award to employees and non-employee directors grants of Common Units (comprising “AmeriGas Stock Units” and “AmeriGas Performance Units”), options, phantom units, unit appreciation rights and other Common Unit-based awards. The total aggregate number of Common Units that may be issued under the 2010 Plan is 2,800,000 . The exercise price for options may not be less than the fair market value on the date of grant. Awards granted under the 2010 Plan may vest immediately or ratably over a period of years, and options can be exercised no later than ten years from the grant date. In addition, the 2010 Plan provides that Common Unit-based awards may also provide for the crediting of Common Unit distribution equivalents to participants’ accounts. AmeriGas Stock Unit and AmeriGas Performance Unit awards entitle the grantee to AmeriGas Partners Common Units or cash once the service condition is met and, with respect to AmeriGas Performance Units, subject to market performance conditions, and for certain awards granted on or after January 1, 2015, actual net customer acquisition and retention performance. Recipients of AmeriGas Performance Units are awarded a target number of AmeriGas Performance Units. The number of AmeriGas Performance Units ultimately paid at the end of the performance period (generally three years ) may be higher or lower than the target number, or it may be zero. For that portion of Performance Unit awards whose ultimate payout is based upon market-based conditions (as further described below), the number of awards ultimately paid is based upon AmeriGas Partners’ Total Unitholder Return (“TUR”) percentile rank relative to entities in a master limited partnership peer group (“Alerian MLP Group”) and, for certain AmeriGas Performance Awards granted in January 2014, based upon AmeriGas Partners’ TUR relative to the two other publicly traded propane master limited partnerships in the Alerian MLP Group (“Propane MLP Group”). For Performance Unit awards granted on or after January 1, 2015, the number of AmeriGas Performance Units ultimately paid is based upon AmeriGas Partner’s TUR percentile rank relative to entities in the Alerian MLP Group as modified by AmeriGas Partners’ performance relative to the Propane MLP Group. With respect to AmeriGas Performance Unit awards subject to measurement compared with the Alerian MLP Group, grantees may receive from 0% to 200% of the target award granted. For such grants issued on or after January 1, 2013, if AmeriGas Partners’ TUR is below the 25th percentile compared to the peer group, the grantee will not be paid. At the 25th percentile, the employee will be paid an award equal to 25% of the target award; at the 40th percentile, 70% ; at the 50th percentile, 100% ; at the 60th percentile, 125% ; at the 75th percentile, 162.5% ; and at the 90th percentile or above, 200% . The actual amount of the award is interpolated between these percentile rankings. For such grants issued on or after January 1, 2015, the amount ultimately paid shall be modified based upon AmeriGas Partners’ TUR ranking relative to the Propane MLP Group over the performance period (“MLP Modifier”). Such modification ranges from 70% to 130% , but in no event shall the amount ultimately paid, after such modification, exceed 200% of the target award grant. With respect to AmeriGas Performance Unit awards granted in January 2014 subject to measurement compared with the Propane MLP Group, grantees were eligible to receive 150% of the target award if AmeriGas Partners’ TUR exceeded the TUR of the other two members of the Propane MLP Group. Otherwise there would be no payout of such AmeriGas Performance Units. For those performance awards granted on or after January 1, 2015 that are subject to the MLP Modifier, if one of the other two members of the Propane MLP Group ceases to exist as a publicly traded company or declares bankruptcy (“MLP Event”) and, depending upon the timing of such MLP Event, the ultimate amount of such AmeriGas Performance Unit awards to be issued, and the amount of distribution equivalents to be paid, would depend upon AmeriGas Partners’ TUR rank relative to (1) the Alerian MLP Group for the entire performance period; (2) the Alerian MLP Group for the entire performance period and the Propane MLP Group (through the date of the MLP Event); or (3) the Propane MLP Group through the date of the MLP Event. With respect to AmeriGas Performance Unit awards granted in January 2015 whose payout was based upon net customer gain and retention performance, grantees could ultimately receive between 0% and 200% of the target award based upon the annual actual net customer gain and retention performance as adjusted for the net customer gain and retention performance over the three -year performance period. With respect to AmeriGas Performance Unit awards granted January 2016 and thereafter whose payout is based upon net customer gain and retention performance, grantees may ultimately receive between 0% and 200% of the target award based upon the actual net customer gain and retention performance over the entire three -year performance period. Common Unit distribution equivalents are paid in cash only on AmeriGas Performance Units that eventually vest. Generally, except in the event of retirement, death or disability, each grant, unless paid, will terminate when the participant ceases to be employed. There are certain change of control and retirement eligibility conditions that, if met, generally result in accelerated vesting or elimination of further service requirements. Under GAAP, AmeriGas Performance Unit awards that are subject to market-based conditions are equity awards that, if settled in Common Units, result in the recognition of compensation cost over the requisite employee service period regardless of whether the market-based condition is satisfied. The fair values of AmeriGas Performance Units subject to market-based conditions are estimated using a Monte Carlo valuation model. The fair value associated with the target award which will be paid in Common Units, is accounted for as equity, and the fair value of the award over the target, as well as all Common Unit distribution equivalents, which will be paid in cash, is accounted for as a liability. For purposes of valuing AmeriGas Performance Unit awards that are subject to market-based conditions, expected volatility is based on the historical volatility of Common Units over a three -year period. The risk-free interest rate is based on the rates on U.S. Treasury bonds at the time of grant. Volatility for all entities in the peer group is based on historical volatility. The expected term of the AmeriGas Performance Unit awards is three years based on the performance period. AmeriGas Performance Unit awards whose ultimate payout is based upon net customer acquisition and retention performance measures are recorded as expense when it is probable all or a portion of the award will be paid. The fair value associated with the target award is the market price of the Common Units on the date of grant. The fair value of the award over the target, as well as all Common Unit distribution equivalents, which will be paid in cash, is accounted for as a liability. The following table summarizes the weighted-average assumptions used to determine the fair value of AmeriGas Performance Unit awards subject to market-based conditions and related compensation costs: Grants Awarded in Fiscal Year 2018 2017 2016 Risk-free rate 2.0% 1.5% 1.3% Expected life 3 years 3 years 3 years Expected volatility 21.1% 21.7% 20.6% Dividend Yield 8.2% 7.8% 10.7% The General Partner granted awards under the 2010 Plan representing 84,811 , 67,563 and 73,080 Common Units in Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , respectively, having weighted-average grant date fair values per Common Unit subject to award of $50.05 , $52.37 and $37.93 , respectively. At September 30, 2018 , 2,242,468 Common Units were available for future award grants under the 2010 Plan. The following table summarizes AmeriGas Common Unit-based award activity for Fiscal 2018 : Common Units Weighted-Average Grant-Date Fair Value (per Unit) Total Units at September 30, 2017 (a) 218,224 $ 50.03 AmeriGas Performance Units: Granted 55,550 $ 52.14 Forfeited (1,900 ) $ 56.70 Awards paid (18,874 ) $ 86.53 Performance criteria not met (37,099 ) $ 51.93 AmeriGas Stock Units: Granted 29,261 $ 46.09 Forfeited (400 ) $ 45.66 Awards paid (8,000 ) $ 45.62 Total Units at September 30, 2018 (a) 236,762 $ 47.12 (a) Total units includes AmeriGas Stock Units issued to non-employee directors, which vest on the grant date, and AmeriGas Performance Units and AmeriGas Stock Units issued to retirement-eligible employees that vest on an accelerated basis. Total vested restricted units at September 30, 2018 and September 30, 2017 were 71,148 and 65,989 , respectively. During Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , the Partnership paid AmeriGas Performance Unit and AmeriGas Stock Unit awards in Common Units and cash as follows: 2018 2017 2016 AmeriGas Performance Unit awards: Number of Common Units subject to original Awards granted, net of forfeitures 65,525 53,800 44,800 Performance periods beginning in fiscal years: 2015 2014 2013 Payment of awards: AmeriGas Partners Common Units issued, net of units withheld for taxes 13,164 29,489 23,017 Cash paid $ 1,227 $ 2,928 $ 1,718 AmeriGas Stock Unit awards: Number of Common Units subject to original Awards granted, net of forfeitures 14,811 32,658 20,336 Payment of awards: AmeriGas Partners Common Units issued, net of units withheld for taxes 5,322 3,932 9,272 Cash paid $ 131 $ 95 $ 370 As of September 30, 2018 , there was $1,162 of unrecognized equity-based compensation expense related to non-vested UGI stock options that is expected to be recognized over a weighted-average period of 1.8 years. As of September 30, 2018 , there was a total of approximately $1,922 of unrecognized compensation cost associated with 236,762 Common Units subject to award that is expected to be recognized over a weighted-average period of 1.7 years. The total fair values of Common Unit-based awards that vested during Fiscal 2018 , Fiscal 2017 and Fiscal 2016 were $2,156 , $2,056 and $1,968 , respectively. As of September 30, 2018 and 2017 , total liabilities of $2,297 and $2,501 associated with Common Unit-based awards are reflected in employee compensation and benefits accrued and other noncurrent liabilities in the Consolidated Balance Sheets. It is the Partnership’s practice to issue new AmeriGas Partners Common Units for the portion of any Common Unit-based awards paid in AmeriGas Partners Common Units.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Commitments We lease various buildings and other facilities and vehicles, computer and office equipment under operating leases. Certain of the leases contain renewal and purchase options and also contain step-rent provisions. Our aggregate rental expense for such leases was $83,418 in Fiscal 2018 , $78,880 in Fiscal 2017 and $73,043 in Fiscal 2016 . Minimum future payments under noncancelable operating leases are as follows: Year Ending September 30, 2019 $ 74,748 2020 68,350 2021 60,713 2022 52,771 2023 45,816 Thereafter 105,502 Total minimum operating lease payments $ 407,900 Certain of our operating lease arrangements, primarily vehicle leases with remaining lease terms of one to ten years, have residual value guarantees. At the end of the lease term, we guarantee that the fair value of the equipment will equal or exceed the guaranteed amount or we will pay the lessors the difference. Although such fair values at the end of the leases have historically exceeded the guaranteed amount, at September 30, 2018 , the maximum potential amount of future payments under lease guarantees, assuming the leased equipment was deemed worthless at the end of the lease term, was approximately $55,000 . The fair values of residual lease guarantees were not material at September 30, 2018 . Contingencies Saranac Lake Environmental Matter. In 2008, the New York State Department of Environmental Conservation (“NYDEC”) notified AmeriGas OLP that the NYDEC had placed property purportedly owned by AmeriGas OLP in Saranac Lake, New York on the New York State Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by the NYDEC disclosed contamination related to a former manufactured gas plant (“MGP”). AmeriGas OLP responded to the NYDEC in 2009 to dispute the contention it was a potentially responsible party (“PRP”) as it did not operate the MGP and appeared to only own a portion of the site. In 2017, the NYDEC communicated to AmeriGas OLP that the NYDEC had previously issued three Records of Decision (“RODs”) related to remediation of the site totaling approximately $27,700 and requested additional information regarding AmeriGas OLP’s purported ownership. AmeriGas renewed its challenge to designation as a PRP and identified potential defenses. The NYDEC subsequently identified a third party PRP with respect to the site. The NYDEC commenced implementation of the remediation plan in the spring of 2018. Based on our evaluation of the available information, the Partnership accrued an undiscounted environmental remediation liability of $7,545 related to the site during the third quarter of Fiscal 2017 which amount is included in “Operating and administrative expenses” on the Consolidated Statement of Operations. Our share of the actual remediation costs could be significantly more or less than the accrued amount. Purported Class Action Lawsuits. Between May and October of 2014, 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 (“District Court”). As of June 2018, as the result of rulings on a series of procedural filings, including petitions filed with the Eighth Circuit and the U.S. Supreme Court, both the federal and state law claims of the direct customer plaintiffs and the state law claims of the indirect customer plaintiffs have been remanded to the District Court. The decision of the District Court to dismiss the federal antitrust claims of the indirect customer plaintiffs was upheld by the Eighth Circuit. Motions are pending before the District Court regarding the indirect purchasers’ state law claims. 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 statements.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	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 $575,699 in Fiscal 2018 , $561,574 in Fiscal 2017 and $556,964 in Fiscal 2016 , 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 $17,225 in Fiscal 2018 , $16,862 in Fiscal 2017 and $18,680 in Fiscal 2016 . 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 $3,391 in Fiscal 2018 , $3,283 in Fiscal 2017 and $2,323 in Fiscal 2016 . 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 is generally based on market price at the time of purchase. Purchases from affiliates of UGI during Fiscal 2018 were not material. There were no purchases of propane by AmeriGas OLP from Energy Services during Fiscal 2017 and Fiscal 2016 . In addition, AmeriGas OLP sells propane to affiliates of UGI. Sales of propane to affiliates of UGI were not material during Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , respectively. On November 7, 2017, AmeriGas Partners entered into the Commitment Agreement with the General Partner and UGI pursuant to which UGI has committed to make up to $225,000 of capital contributions to the Partnership through July 1, 2019, for consideration comprising new Class B Common Units representing limited partner interests in the Partnership. See Note 11 for additional information on this agreement.

Other Current Liabilities

Other Current Liabilities	12 Months Ended
	Sep. 30, 2018
Payables and Accruals [Abstract]
Other Current Liabilities	Other Current Liabilities Other current liabilities comprise the following at September 30: 2018 2017 Litigation, property and casualty liabilities $ 56,860 $ 65,071 Taxes other than income taxes 11,945 12,207 Deferred tank rent revenue 16,336 16,533 Other 20,769 19,770 Total other current liabilities $ 105,910 $ 113,581

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	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 described in Note 2 , as of September 30, 2018 and 2017 : Asset (Liability) Level 1 Level 2 Level 3 Total September 30, 2018: Derivative instruments: Assets: Commodity contracts $ — $ 52,529 $ — $ 52,529 Liabilities: Commodity contracts $ — $ (251 ) $ — $ (251 ) September 30, 2017: Derivative instruments: Assets: Commodity contracts $ — $ 40,714 $ — $ 40,714 Liabilities: Commodity contracts $ — $ (920 ) $ — $ (920 ) 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. Nonrecurring Fair Value Measurements As discussed in Note 10 , in April 2018, the Partnership’s senior management approved a plan to discontinue the use of indefinite-lived tradenames and trademarks, primarily those associated with the Partnership’s January 2012 acquisition of Heritage Propane. This action required the Partnership to remeasure the fair values of these tradenames and trademarks based upon their remaining period of benefit. The Partnership used the relief from royalty method to estimate the fair values of the tradenames and trademarks, which method estimates our theoretical royalty savings from ownership of the tradenames and trademarks. Key assumptions used in this method include discount rates, royalty rates, growth rates and sales projections. These assumptions reflect current economic conditions, management expectations and projected future cash flows expected to be generated from these tradenames and trademarks. The Partnership has determined that the lowest level of the input that is significant to the fair value measurement are unobservable inputs that fall within Level 3 of the fair value hierarchy. As of the April 2018 measurement date, these tradenames and trademarks had an estimated fair value of $7,944 . 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. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amount and estimated fair value of our long-term debt (including current maturities but excluding unamortized debt issuance costs) at September 30, 2018 and September 30, 2017 were as follows: 2018 2017 Carrying amount $ 2,597,131 $ 2,603,610 Estimated fair value $ 2,562,206 $ 2,699,428 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	12 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities The Partnership is exposed to certain market risks associated with its ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage these risks. The primary risk managed by derivative instruments is commodity price 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, 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 agreements to reduce the effects of short-term commodity price volatility . At September 30, 2018 and 2017 , total volumes associated with propane commodity derivatives totaled 244.8 million gallons and 213.6 million gallons, respectively. At September 30, 2018 , the maximum period over which we are economically hedging propane market price risk is 24 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 September 30, 2018 . 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 September 30, 2018 , 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 are presented net by counterparty on the 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 the 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 by type, as well as the effects of offsetting, as of September 30, 2018 and 2017 : 2018 2017 Derivative assets: Derivatives not designated as hedging instruments: Commodity contracts $ 52,529 $ 40,714 Total derivative assets — gross 52,529 40,714 Gross amounts offset in the balance sheet (251 ) (920 ) Cash collateral received (7,270 ) (7,991 ) Total derivative assets — net $ 45,008 $ 31,803 Derivative liabilities: Derivatives not designated as hedging instruments: Commodity contracts $ (251 ) $ (920 ) Total derivative liabilities — gross (251 ) (920 ) Gross amounts offset in the balance sheet 251 920 Total derivative liabilities — net $ — $ — Effects of Derivative Instruments The following table provides information on the effects of derivative instruments on the Consolidated Statements of Operations for Fiscal 2018 , Fiscal 2017 and Fiscal 2016 : Gain Location of Gain Recognized in Income Recognized in Income 2018 2017 2016 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ 62,316 $ 65,644 $ 2,567 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 certain of these contracts have the requisite elements of a derivative instrument, these contracts qualify for NPNS 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.

Other Operating Income, Net

Other Operating Income, Net	12 Months Ended
	Sep. 30, 2018
Other Income and Expenses [Abstract]
Other Operating Income, Net	Other Operating Income, Net Other operating income, net, comprises the following: 2018 2017 2016 Finance charges $ 16,379 $ 11,805 $ 15,201 Gains (losses) on sales of fixed assets (a) 5,236 (2,197 ) 8,062 Other 2,758 2,265 4,989 Total other operating income, net $ 24,373 $ 11,873 $ 28,252 (a) Fiscal 2017 amount includes a loss of $8,847 from correction of error (see Note 2).

Quarterly Data (Unaudited)

Quarterly Data (Unaudited)	12 Months Ended
	Sep. 30, 2018
Quarterly Financial Information Disclosure [Abstract]
Quarterly Data (Unaudited)	Quarterly Data (Unaudited) The following unaudited quarterly data includes all adjustments (consisting only of normal recurring adjustments with the exception of those indicated below) which we consider necessary for a fair presentation unless otherwise indicated. Our quarterly results fluctuate primarily because of the seasonal nature of our propane business and the effects of unrealized gains and losses on commodity derivative instruments used to economically hedge commodity price risk (see Note 16). December 31, March 31, June 30, September 30, 2017 2016 (c) 2018 2017 (c) 2018 (a) 2017 (b) (c) 2018 2017 Revenues $ 787,296 $ 677,166 $ 1,040,332 $ 863,660 $ 528,403 $ 467,496 $ 466,947 $ 445,173 Operating income (loss) $ 148,825 $ 167,631 $ 235,817 $ 199,864 $ (33,699 ) $ (1,137 ) $ 10,399 $ 21,500 Net income (loss) including noncontrolling interest $ 105,870 $ 93,615 $ 194,166 $ 137,083 $ (74,772 ) $ (46,794 ) $ (31,262 ) $ (18,035 ) Net income (loss) attributable to AmeriGas Partners, L.P. $ 104,421 $ 91,954 $ 191,824 $ 135,088 $ (74,396 ) $ (46,752 ) $ (31,327 ) $ (18,231 ) Income (loss) per limited partner unit (d): Basic $ 0.97 $ 0.87 $ 1.44 $ 1.14 $ (0.91 ) $ (0.62 ) $ (0.46 ) $ (0.32 ) Diluted $ 0.97 $ 0.87 $ 1.44 $ 1.14 $ (0.91 ) $ (0.62 ) $ (0.46 ) $ (0.32 ) (a) The quarter ended June 30, 2018, includes the impact of the impairment of Heritage tradenames and trademarks of $75,000 ( $74,242 after noncontrolling interest) (See Note 10). (b) Includes an environmental accrual associated with the site of a former MGP obtained in a prior-year acquisition of $7,545 ( $7,469 after noncontrolling interest) (See Note 12 ). (c) The quarters ended December 31, 2016, March 31, 2017 and June 30, 2017 include loss on extinguishments of debt of $33,151 , $22,144 and $4,434 , respectively (see Note 6). (d) Theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. in accordance with accounting guidance regarding the application of the two-class method for determining earnings per share (see Note 2 ) resulted in a different allocation of net income attributable to AmeriGas Partners, L.P. to the General Partner and the limited partners in the computation of income per limited partner unit which had the effect of decreasing quarterly earnings per limited partner unit for the quarters ended December 31 and March 31 as follows: December 31, March 31, Quarter ended: 2017 2016 2018 2017 Decrease in income per limited partner unit $ (0.02 ) $ — $ (0.48 ) $ (0.19 )

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information of Registrant (Parent Company)	12 Months Ended
	Sep. 30, 2018
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I - Condensed Financial Information of Registrant (Parent Company)	SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) BALANCE SHEETS (Thousands of dollars) September 30, 2018 2017 ASSETS Current assets: Cash $ 1,105 $ 1,529 Total current assets 1,105 1,529 Investment in AmeriGas Propane, L.P. 3,128,927 3,335,902 Other assets 56 56 Total assets $ 3,130,088 $ 3,337,487 LIABILITIES AND PARTNERS’ CAPITAL Current liabilities: Accounts payable and other liabilities $ 2,879 $ 2,820 Accrued interest 42,921 42,921 Total current liabilities 45,800 45,741 Long-term debt 2,547,681 2,543,847 Commitments and contingencies Partners’ capital: Common unitholders 523,925 733,104 General partner 12,682 14,795 Total partners’ capital 536,607 747,899 Total liabilities and partners’ capital $ 3,130,088 $ 3,337,487 Commitments and Contingencies There are no scheduled principal repayments of long-term debt during the next five fiscal years. AMERIGAS PARTNERS, L.P. SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) STATEMENTS OF OPERATIONS (Thousands of dollars, except per unit amounts) Year Ended September 30, 2018 2017 2016 Operating expenses, net $ (258 ) $ (300 ) $ (255 ) Loss on extinguishments of debt — (59,729 ) (48,889 ) Interest expense (including related party interest expense) (150,204 ) (151,294 ) (156,350 ) Loss before equity in income of AmeriGas Propane, L.P. (150,462 ) (211,323 ) (205,494 ) Equity in income of AmeriGas Propane, L.P. 340,984 373,382 412,478 Net income attributable to AmeriGas Partners $ 190,522 $ 162,059 $ 206,984 General partner’s interest in net income attributable to AmeriGas Partners $ 47,226 $ 45,146 $ 40,227 Limited partners’ interest in net income attributable to AmeriGas Partners $ 143,296 $ 116,913 $ 166,757 Income per limited partner unit — basic and diluted $ 1.54 $ 1.25 $ 1.77 Weighted average limited partner units outstanding — basic (thousands) 93,034 92,996 92,949 Weighted average limited partner units outstanding — diluted (thousands) 93,086 93,050 93,023 AMERIGAS PARTNERS, L.P. SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) STATEMENTS OF CASH FLOWS (Thousands of dollars) Year Ended September 30, 2018 2017 2016 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 401,412 $ 368,634 $ 371,536 CASH FLOWS FROM INVESTING ACTIVITIES Contributions to AmeriGas Propane, L.P. — (157,000 ) (3,900 ) Net cash used by investing activities — (157,000 ) (3,900 ) CASH FLOWS FROM FINANCING ACTIVITIES Distributions (402,645 ) (398,877 ) (387,659 ) Issuance of long-term debt, net of issuance costs — 1,207,727 1,331,293 Repayment of long-term debt, including redemption premiums — (1,032,097 ) (1,309,588 ) Proceeds associated with equity based compensation plans, net of tax withheld 801 1,465 1,127 Capital contribution from General Partner 8 15 11 Net cash used by financing activities (401,836 ) (221,767 ) (364,816 ) (Decrease) increase in cash and cash equivalents $ (424 ) $ (10,133 ) $ 2,820 CASH AND CASH EQUIVALENTS: End of year $ 1,105 $ 1,529 $ 11,662 Beginning of year 1,529 11,662 8,842 (Decrease) increase $ (424 ) $ (10,133 ) $ 2,820 (a) Includes cash distributions received from AmeriGas Propane, L.P. of $547,958 , $512,326 and $530,912 for Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , respectively.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Sep. 30, 2018
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Thousands of dollars) Balance at beginning of year Charged to costs and expenses Other Balance at end of year Year Ended September 30, 2018 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 11,820 $ 14,016 $ (13,011 ) (1) $ 12,825 Year Ended September 30, 2017 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 11,436 $ 17,693 $ (17,309 ) (1) $ 11,820 Year Ended September 30, 2016 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 12,257 $ 11,215 $ (12,036 ) (1) $ 11,436 (1) Uncollectible accounts written off, net of recoveries.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation. Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). 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.
Reclassification	Certain prior-year amounts have been reclassified to conform to the current-year presentation.
Principles of Consolidation	Principles of Consolidation. The consolidated financial statements include the accounts of AmeriGas Partners, its majority-owned subsidiary AmeriGas OLP, and its 100% -owned finance subsidiaries AmeriGas Finance Corp., AmeriGas Eagle Finance Corp., AP Eagle Finance Corp., and AmeriGas Finance LLC. AmeriGas Partners and AmeriGas OLP are under the common control of the General Partner. The General Partner of AmeriGas OLP, which is also the General Partner of AmeriGas Partners, makes all decisions for AmeriGas OLP; limited partners of AmeriGas OLP do not have the ability to remove the General Partner or participate in the decision-making for AmeriGas OLP. The accounts of AmeriGas OLP are included based upon the determination that AmeriGas Partners has a controlling financial interest in and is the primary beneficiary of AmeriGas OLP. We eliminate intercompany accounts and transactions when we consolidate.
Finance Corps	Finance Corps. AmeriGas Finance Corp., AmeriGas Eagle 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.
Fair Value Measurements	Fair Value Measurements. The Partnership applies fair value measurements on a recurring and, as otherwise required under GAAP, also on a nonrecurring basis. Fair value in GAAP is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value measurements performed on a recurring basis principally relate to commodity derivative instruments. GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). A level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: • Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. • Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. We evaluate the need for credit adjustments to our derivative instrument fair values. These credit adjustments were not material to the fair values of our derivative instruments.
Derivative Instruments	Derivative Instruments. Derivative instruments are reported on the Consolidated Balance Sheets at their fair values, unless the normal purchase and normal sale (“NPNS”) exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it qualifies and is designated as a hedge for accounting purposes. We do not currently have derivative instruments that are designated and qualify as cash flow hedges. Changes in the fair values of our commodity derivative instruments are reflected in “Cost of sales - propane” on the Consolidated Statements of Operations. Cash flows from commodity derivative instruments are included in cash flows from operating activities. For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 16 .
Revenue Recognition	Revenue Recognition. Revenues from the sale of propane are recognized principally upon delivery. Revenues from the sale of appliances and equipment are recognized at the later of sale or installation. Revenues from repair or maintenance services are recognized upon completion of services. Revenues from annually billed fees are generally recorded on a straight-line basis over one year. We present revenue-related taxes collected on behalf of customers and remitted to taxing authorities, principally sales and use taxes, on a net basis.
Accounts Receivable	Accounts Receivable. Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience and the assessment of the collectability of specific amounts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible.
Delivery Expenses	Delivery Expenses. Expenses associated with the delivery of propane to customers (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “ Operating and administrative expenses ” on the Consolidated Statements of Operations. Depreciation expense associated with delivery vehicles is classified in “ Depreciation and amortization ” on the Consolidated Statements of Operations.
Income Taxes	Income Taxes. AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to their individual partners. AmeriGas OLP has corporate subsidiaries which are directly subject to federal and state income taxes. Accordingly, our consolidated financial statements reflect income taxes related to these corporate subsidiaries. Legislation in certain states allows for taxation of partnerships’ income and the accompanying financial statements reflect state income taxes resulting from such legislation. Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders. This is a result of (1) differences between the tax basis and financial reporting basis of assets and liabilities and (2) the taxable income allocation requirements of the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P., as amended (“Partnership Agreement”) and the Internal Revenue Code.
Cash and Cash Equivalents	Cash and Cash Equivalents. For cash flow purposes, cash and cash equivalents include cash on hand, cash in banks and highly liquid investments with maturities of three months or less when purchased.
Inventories	Inventories. Our inventories are stated at the lower of cost or net realizable value. We determine cost using an average cost method for propane, specific identification for appliances and the first-in, first-out (“FIFO”) method for all other inventories.
Property, Plant and Equipment and Related Depreciation	Property, Plant and Equipment and Related Depreciation. We record property, plant and equipment at cost. The amounts we assign to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition. When we retire or otherwise dispose of plant and equipment, we eliminate the associated cost and accumulated depreciation and recognize any resulting gain or loss in " Other operating income, net " on the Consolidated Statements of Operations. We record depreciation expense on plant and equipment using the straight-line method over estimated service lives. At September 30, 2018 , estimated useful lives by type were as follows: Asset Type Minimum Estimated Useful Life (in years) Maximum Estimated Useful Life (in years) Buildings and improvements 15 40 Storage, customer tanks and cylinders and related assets 6 30 Vehicles, equipment and office furniture and fixtures 3 10 Computer software 3 10 We include in property, plant and equipment costs associated with computer software we develop or obtain for use in our businesses. We classify amortization of computer software and related costs included in property, plant and equipment as depreciation expense.
Segment Information	Segment Information. We have determined that we have a single reportable operating segment that engages in the distribution of propane and related equipment and supplies. No single customer represents ten percent or more of consolidated revenues. In addition, substantially all of our revenues are derived from sources within the United States and substantially all of our long-lived assets are located in the United States.
Goodwill and Intangible Assets	Goodwill and Intangible Assets. We amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. Estimated useful lives of definite-lived intangible assets, consisting of customer relationships, noncompete agreements and, beginning in April 2018, the carrying amounts of tradenames and trademarks, do not exceed 15 years. We review definite-lived intangible assets for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may not be recoverable. Determining whether an impairment loss occurred requires comparing the carrying amount to the sum of undiscounted cash flows expected to be generated by the asset. Prior to April 2018, our tradenames and trademark intangible assets with indefinite lives were not amortized but were tested annually for impairment (and more frequently if indicators of impairment were present). We tested these indefinite-lived intangible assets by comparing their book values to their estimated fair values. The estimated fair values of the Partnership’s tradenames and trademarks were determined using the “relief from royalty” method. This method requires the Partnership to, among other things, forecast future revenues expected to be derived from the use of these tradenames and trademarks and to determine a fair royalty rate from their use. These future estimated royalties are then discounted to present value using a discount rate based upon a weighted average cost of capital adjusted for the risks inherent in the forecasted financial information and those specific to the asset itself. In April 2018, the Partnership’s senior management approved a plan to discontinue the use of these tradenames and trademarks, primarily associated with its January 2012 acquisition of Heritage Propane, over a period of approximately three years. As a result, during the third quarter of Fiscal 2018, the Partnership determined that these tradenames and trademarks no longer had indefinite lives and, in accordance with GAAP associated with intangible assets, adjusted the carrying amounts of these tradenames and trademarks to their estimated fair values. For further information on these tradenames and trademarks, see Notes 10 and 15 . We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is the operating segment, or a business one level below the operating segment (a component) if discrete financial information is prepared and regularly reviewed by segment management. Components are aggregated as a single reporting unit if they have similar economic characteristics. A reporting unit with goodwill is required to perform an impairment test annually or whenever events or circumstances indicate that the value of goodwill may be impaired. We are required to recognize an impairment charge under GAAP if the carrying amount of a reporting unit exceeds its fair value. From time to time, we may assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. Among the significant factors considered in performing the qualitative assessment is the market price of AmeriGas Partners Common Units. We may bypass the qualitative assessment and perform the quantitative assessment by comparing the fair value of the reporting unit with its carrying amount, including goodwill. We determine fair value generally based on a weighting of income and market approaches. For purposes of the income approach, fair value is determined based upon the present value of the estimated future cash flows, including an estimate of the terminal value based upon these cash flows, discounted at an appropriate risk-adjusted rate. We use our internal forecasts to estimate future cash flows which may include estimates of long-term future growth rates based upon our most recent long-term outlook. Cash flow estimates used to establish fair values under our income approach involve management judgments based on a broad range of information and historical results. In addition, external economic and competitive conditions can influence future performance. For purposes of the market approach, we use valuation multiples for companies comparable to our reporting unit. The market approach requires judgment to determine the appropriate valuation multiple. If the carrying amount of our reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets. We evaluate long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. We evaluate recoverability based upon undiscounted future cash flows expected to be generated by such assets. If the undiscounted future cash flows indicate that the recorded amounts are not expected to be recoverable, such long-lived assets are reduced to their estimated fair values.
Debt Issuance Costs	Debt Issuance Costs. We defer and amortize debt issuance costs and debt premiums and discounts over the expected lives of the respective debt issues considering maturity dates. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issue costs associated with revolving credit agreements are included in “Other assets” on the Consolidated Balance Sheets. Amortization of the debt issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt prior to their stated maturity are generally recognized and included in “Loss on extinguishments of debt” on the Consolidated Statements of Operations.
Customer Deposits	Customer Deposits. We offer certain of our customers prepayment programs which require customers to pay a fixed periodic amount or to otherwise prepay a portion of their anticipated propane purchases. Customer prepayments, in excess of associated billings, are classified as “ Customer deposits and advances ” on the Consolidated Balance Sheets.
Equity-Based Compensation	Equity-Based Compensation. The General Partner may grant Common Unit awards (as further described in Note 11 ) to employees and non-employee directors under its Common Unit plans, and employees of the General Partner may be granted stock options for UGI Common Stock. All of our equity-based compensation is measured at fair value on the grant date, date of modification or end of the period, as applicable, and recognized in earnings over the requisite service period. Depending upon the settlement terms of the awards, all or a portion of the fair value of equity-based awards may be presented as a liability or as equity on our Consolidated Balance Sheets. Equity-based compensation costs associated with the portion of Common Unit awards classified as equity are measured based upon their estimated fair value on the date of grant or modification. Equity-based compensation costs associated with the portion of Common Unit awards classified as liabilities are measured based upon their estimated fair value at the date of grant and remeasured as of the end of each period. We account for forfeitures of equity-based payments when they occur. For a further description of our equity-based compensation plans and related disclosures, see Note 11 .
Environmental Matters	Environmental Matters . We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. Under GAAP, if the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, such liabilities are discounted to reflect the time value of money.
Loss Contingencies Subject to Insurance	Loss Contingencies Subject to Insurance. The Partnership is subject to risk of loss for general, automobile and product liability, and workers’ compensation claims for which it obtains insurance coverage under insurance policies that are subject to self-insured retentions or deductibles. In accordance with GAAP, the Partnership establishes reserves for pending legal actions, and for pending and incurred but not reported claims associated with general, automobile and workers’ compensation when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. The Partnership maintains insurance coverage such that its net exposure for claims covered by insurance would be limited to the self-insured retentions or deductibles, claims above which would be paid by the insurance carrier. For such claims, the Partnership records a receivable related to the amount of the liability expected to be paid by insurance.
Allocation of Net Income (Loss)	Allocation of Net Income (Loss). 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 Partnership Agreement (see Note 5 ).
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).
Accounting Changes	New Accounting Standards Adopted Effective October 1, 2018 Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). The guidance provided under this ASU, as amended, supersedes the revenue recognition requirements in Accounting Standards Codification (“ASC”) No. 605, “Revenue Recognition,” and most industry-specific guidance included in the ASC. ASU 2014-09 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. In addition, the new guidance requires enhanced disclosures to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers and requires, among other things, the disaggregation of revenues into categories that show how economic factors affect the nature, timing and uncertainty of revenues and cash flows. We adopted this ASU effective October 1, 2018, using the modified retrospective transition method. The Partnership has completed the process of analyzing the impact of the new guidance using an integrated approach which includes evaluating differences in the amount and timing of revenue recognition from applying the requirements of the new guidance, reviewing its accounting policies and practices, and assessing the need for changes to its processes, accounting systems and design of internal controls. The adoption of this new guidance will not have a material impact on our consolidated financial statements. Cloud Computing Implementation Costs. In August 2018, the FASB issued ASU No. 2018-15, “Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The new guidance requires a customer in a cloud computing arrangement that is a service contract to capitalize certain implementation costs as if the arrangement was an internal-use software project. These deferred implementation costs are expensed over the fixed, noncancelable term of the service arrangement plus any reasonably certain renewal periods. The new guidance also requires the entity to present the expense related to the capitalized implementation costs in the same income statement line as the hosting service fees; to classify payments for capitalized implementation costs in the statement of cash flows in the same manner as payments for hosting service fees; and to present the capitalized implementation costs in the balance sheet in the same line item in which prepaid hosting service fees are presented. The new guidance can be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. We adopted this ASU effective October 1, 2018, and applied the guidance prospectively to all implementation costs associated with cloud computing arrangements that are service contracts incurred after October 1, 2018. Other Accounting Principles Not Yet Adopted Fair Value Measurements Disclosures. In August 2018, the FASB issued ASU No. 2018-13, “Changes to the Disclosure Requirements for Fair Value Measurement.” This ASU modifies the disclosure requirements for fair value measurements by removing, modifying, or adding certain disclosures. The amendments in this ASU are effective for annual periods beginning after December 15, 2019 (Fiscal 2021). The guidance regarding removed and modified disclosures will be adopted on a retrospective basis and the guidance regarding new disclosures will be adopted on a prospective basis. Early adoption is permitted. The Partnership is in the process of assessing the impact on its financial statement disclosures from the adoption of the new guidance and determining the period in which the new guidance will be adopted. Derivatives and Hedging. In August 2017, the FASB issued ASU No. 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” This ASU amends and simplifies existing guidance to allow companies to more accurately present the economic effects of risk management activities in the financial statements. The amendments in this ASU are effective for the Partnership for interim and annual periods beginning October 1, 2019 (Fiscal 2020). Early adoption is permitted. For cash flow and net investment hedges as of the adoption date, the guidance requires a modified retrospective approach. The amended presentation and disclosure guidance is required only prospectively. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the period in which the new guidance will be adopted. Leases. In February 2016, the FASB issued ASU No. 2016-02, "Leases." This ASU, as subsequently updated, 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 the Partnership for interim and annual periods beginning October 1, 2019 (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 unless an entity chooses the transition option in ASU 2018-11, “Leases: Targeted Improvements” which, among other things, provides entities with a transition option to recognize the cumulative-effect adjustment from the modified retrospective application to the opening balance of retained earnings in the period of adoption. We will adopt ASU No. 2016-02, as updated, effective October 1, 2019 and expect to elect the proposed transition option which would allow the Partnership to maintain historical presentation for periods before October 1, 2019. The Partnership has completed a preliminary assessment for evaluating the impact of the guidance and anticipates that its adoption will result in a significant amount of right-of-use assets and lease liabilities for leases in effect at the adoption date. The Partnership has begun implementation activities including accumulating contracts and lease data in formats compatible with a new lease management system that will assist with the initial adoption of the standard.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Estimated Useful Lives by Type	We record depreciation expense on plant and equipment using the straight-line method over estimated service lives. At September 30, 2018 , estimated useful lives by type were as follows: Asset Type Minimum Estimated Useful Life (in years) Maximum Estimated Useful Life (in years) Buildings and improvements 15 40 Storage, customer tanks and cylinders and related assets 6 30 Vehicles, equipment and office furniture and fixtures 3 10 Computer software 3 10 Property, plant and equipment comprise the following at September 30: 2018 2017 Land $ 135,809 $ 135,965 Buildings and improvements 197,148 196,798 Transportation equipment 214,526 250,493 Storage facilities 212,686 268,415 Equipment, primarily cylinders and tanks 1,330,049 1,612,375 Work in process 27,859 19,517 Other 182,032 235,037 Gross property, plant and equipment 2,300,109 2,718,600 Less accumulated depreciation (1,151,726 ) (1,511,890 ) Net property, plant and equipment $ 1,148,383 $ 1,206,710
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: 2018 2017 2016 Net income attributable to AmeriGas Partners, L.P. $ 190,522 $ 162,059 $ 206,984 Adjust for general partner share and theoretical distributions of net income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs (47,233 ) (46,054 ) (42,024 ) Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs $ 143,289 $ 116,005 $ 164,960 Weighted average Common Units outstanding — basic (thousands) 93,034 92,996 92,949 Potentially dilutive Common Units (thousands) 52 54 74 Weighted average Common Units outstanding — diluted (thousands) 93,086 93,050 93,023

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Allocation of Purchase Price	The total purchase price of these acquisitions has been allocated to the assets acquired and liabilities assumed as follows: 2018 2017 2016 Net current assets (liabilities) $ 926 $ 1,176 $ (162 ) Property, plant and equipment 2,987 6,712 9,322 Goodwill 4,528 23,029 24,213 Customer relationships and noncompete agreements (estimated useful life of 10 and 5 years, respectively) 4,344 16,714 16,006 Other assets — 41 — Total $ 12,785 $ 47,672 $ 49,379

Quarterly Distributions of Av_2

Quarterly Distributions of Available Cash (Tables)	12 Months Ended
	Sep. 30, 2018
Distributions Made to Members or Limited Partners [Abstract]
Quarterly Distributions of Available Cash Per Limited Partner Unit	Quarterly distributions of Available Cash per limited partner unit paid during Fiscal 2018 , Fiscal 2017 and Fiscal 2016 were as follows: 2018 2017 2016 1st Quarter $ 0.95 $ 0.94 $ 0.92 2nd Quarter $ 0.95 $ 0.94 $ 0.92 3rd Quarter $ 0.95 $ 0.95 $ 0.94 4th Quarter $ 0.95 $ 0.95 $ 0.94

Debt (Tables)

Debt (Tables)	12 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Schedule of Long Term Debt	Long-term debt comprises the following at September 30: 2018 2017 AmeriGas Partners Senior Notes: 5.50% due May 2025 (a) $ 700,000 $ 700,000 5.875% due August 2026 (a) 675,000 675,000 5.75% due May 2027 (a) 525,000 525,000 5.625% due May 2024 (a) 675,000 675,000 Heritage Operating, L.P. (“HOLP”) Senior Secured Notes 7,516 11,348 Other 14,615 17,262 Total long-term debt 2,597,131 2,603,610 Less: unamortized debt issuance costs (27,498 ) (31,331 ) Less: current maturities (8,626 ) (8,447 ) Total long-term debt due after one year $ 2,561,007 $ 2,563,832 (a) AmeriGas Partners and AmeriGas Finance Corp. co-issued these senior notes.
Losses on Extinguishments of Debt	In connection with the early repayments of the Partnership’s Senior Notes, during Fiscal 2017 and Fiscal 2016, the Partnership recognized losses which are reflected in “ Loss on extinguishments of debt ” on the Consolidated Statements of Operations and comprise the following: 2017 2016 Early redemption premiums $ 51,253 $ 39,569 Write-off of unamortized debt issuance costs 8,476 9,320 Loss on extinguishments of debt $ 59,729 $ 48,889

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Summary of Inventories	Inventories comprise the following at September 30: 2018 2017 Propane gas $ 114,005 $ 99,035 Materials, supplies and other 10,546 11,899 Appliances for sale 5,976 5,745 Total inventories $ 130,527 $ 116,679

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Summary of Property, Plant and Equipment	We record depreciation expense on plant and equipment using the straight-line method over estimated service lives. At September 30, 2018 , estimated useful lives by type were as follows: Asset Type Minimum Estimated Useful Life (in years) Maximum Estimated Useful Life (in years) Buildings and improvements 15 40 Storage, customer tanks and cylinders and related assets 6 30 Vehicles, equipment and office furniture and fixtures 3 10 Computer software 3 10 Property, plant and equipment comprise the following at September 30: 2018 2017 Land $ 135,809 $ 135,965 Buildings and improvements 197,148 196,798 Transportation equipment 214,526 250,493 Storage facilities 212,686 268,415 Equipment, primarily cylinders and tanks 1,330,049 1,612,375 Work in process 27,859 19,517 Other 182,032 235,037 Gross property, plant and equipment 2,300,109 2,718,600 Less accumulated depreciation (1,151,726 ) (1,511,890 ) Net property, plant and equipment $ 1,148,383 $ 1,206,710

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Sep. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Changes in the Carrying Amount of Goodwill	Changes in the carrying amount of goodwill are as follows: Balance September 30, 2016 $ 1,978,981 Acquisitions 23,029 Balance September 30, 2017 2,002,010 Acquisitions 4,528 Dispositions (2,867 ) Balance September 30, 2018 $ 2,003,671
Components of Intangible Assets	The Partnership’s intangible assets comprise the following at September 30: 2018 2017 Customer relationships and noncompete agreements (subject to amortization) $ 497,373 $ 497,385 Trademarks and tradenames (subject to amortization) 7,944 — Trademarks and tradenames (not subject to amortization) — 82,944 Gross carrying amount 505,317 580,329 Accumulated amortization (225,709 ) (190,289 ) Intangible assets, net $ 279,608 $ 390,040

Partners' Capital and Equity _2

Partners' Capital and Equity Compensation Plans (Tables)	12 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Weighted-Average Assumptions Used to Determine Fair Value of AmeriGas Performance Unit Awards and Related Compensation Costs	The following table summarizes the weighted-average assumptions used to determine the fair value of AmeriGas Performance Unit awards subject to market-based conditions and related compensation costs: Grants Awarded in Fiscal Year 2018 2017 2016 Risk-free rate 2.0% 1.5% 1.3% Expected life 3 years 3 years 3 years Expected volatility 21.1% 21.7% 20.6% Dividend Yield 8.2% 7.8% 10.7%
AmeriGas Common Unit-Based Award Activity	The following table summarizes AmeriGas Common Unit-based award activity for Fiscal 2018 : Common Units Weighted-Average Grant-Date Fair Value (per Unit) Total Units at September 30, 2017 (a) 218,224 $ 50.03 AmeriGas Performance Units: Granted 55,550 $ 52.14 Forfeited (1,900 ) $ 56.70 Awards paid (18,874 ) $ 86.53 Performance criteria not met (37,099 ) $ 51.93 AmeriGas Stock Units: Granted 29,261 $ 46.09 Forfeited (400 ) $ 45.66 Awards paid (8,000 ) $ 45.62 Total Units at September 30, 2018 (a) 236,762 $ 47.12 (a) Total units includes AmeriGas Stock Units issued to non-employee directors, which vest on the grant date, and AmeriGas Performance Units and AmeriGas Stock Units issued to retirement-eligible employees that vest on an accelerated basis. Total vested restricted units at September 30, 2018 and September 30, 2017 were 71,148 and 65,989 , respectively.
Partnership Paid AmeriGas Common Unit-Based Awards in Common Units and Cash	During Fiscal 2018 , Fiscal 2017 and Fiscal 2016 , the Partnership paid AmeriGas Performance Unit and AmeriGas Stock Unit awards in Common Units and cash as follows: 2018 2017 2016 AmeriGas Performance Unit awards: Number of Common Units subject to original Awards granted, net of forfeitures 65,525 53,800 44,800 Performance periods beginning in fiscal years: 2015 2014 2013 Payment of awards: AmeriGas Partners Common Units issued, net of units withheld for taxes 13,164 29,489 23,017 Cash paid $ 1,227 $ 2,928 $ 1,718 AmeriGas Stock Unit awards: Number of Common Units subject to original Awards granted, net of forfeitures 14,811 32,658 20,336 Payment of awards: AmeriGas Partners Common Units issued, net of units withheld for taxes 5,322 3,932 9,272 Cash paid $ 131 $ 95 $ 370

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Minimum Future Payments Under Noncancellable Operating Leases	Minimum future payments under noncancelable operating leases are as follows: Year Ending September 30, 2019 $ 74,748 2020 68,350 2021 60,713 2022 52,771 2023 45,816 Thereafter 105,502 Total minimum operating lease payments $ 407,900

Other Current Liabilities (Tabl

Other Current Liabilities (Tables)	12 Months Ended
	Sep. 30, 2018
Payables and Accruals [Abstract]
Other Current Liabilities	Other current liabilities comprise the following at September 30: 2018 2017 Litigation, property and casualty liabilities $ 56,860 $ 65,071 Taxes other than income taxes 11,945 12,207 Deferred tank rent revenue 16,336 16,533 Other 20,769 19,770 Total other current liabilities $ 105,910 $ 113,581

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Sep. 30, 2018
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 described in Note 2 , as of September 30, 2018 and 2017 : Asset (Liability) Level 1 Level 2 Level 3 Total September 30, 2018: Derivative instruments: Assets: Commodity contracts $ — $ 52,529 $ — $ 52,529 Liabilities: Commodity contracts $ — $ (251 ) $ — $ (251 ) September 30, 2017: Derivative instruments: Assets: Commodity contracts $ — $ 40,714 $ — $ 40,714 Liabilities: Commodity contracts $ — $ (920 ) $ — $ (920 )
Carrying Amount and Estimated Fair Value of Long-term Debt	The carrying amount and estimated fair value of our long-term debt (including current maturities but excluding unamortized debt issuance costs) at September 30, 2018 and September 30, 2017 were as follows: 2018 2017 Carrying amount $ 2,597,131 $ 2,603,610 Estimated fair value $ 2,562,206 $ 2,699,428

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Sep. 30, 2018
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 by type, as well as the effects of offsetting, as of September 30, 2018 and 2017 : 2018 2017 Derivative assets: Derivatives not designated as hedging instruments: Commodity contracts $ 52,529 $ 40,714 Total derivative assets — gross 52,529 40,714 Gross amounts offset in the balance sheet (251 ) (920 ) Cash collateral received (7,270 ) (7,991 ) Total derivative assets — net $ 45,008 $ 31,803 Derivative liabilities: Derivatives not designated as hedging instruments: Commodity contracts $ (251 ) $ (920 ) Total derivative liabilities — gross (251 ) (920 ) Gross amounts offset in the balance sheet 251 920 Total derivative liabilities — net $ — $ —
Components of Derivative Instruments Gain Loss in Statement of Operations	The following table provides information on the effects of derivative instruments on the Consolidated Statements of Operations for Fiscal 2018 , Fiscal 2017 and Fiscal 2016 : Gain Location of Gain Recognized in Income Recognized in Income 2018 2017 2016 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ 62,316 $ 65,644 $ 2,567 Cost of sales — propane

Other Operating Income, Net (Ta

Other Operating Income, Net (Tables)	12 Months Ended
	Sep. 30, 2018
Other Income and Expenses [Abstract]
Schedule of Other Operating Income, Net	Other operating income, net, comprises the following: 2018 2017 2016 Finance charges $ 16,379 $ 11,805 $ 15,201 Gains (losses) on sales of fixed assets (a) 5,236 (2,197 ) 8,062 Other 2,758 2,265 4,989 Total other operating income, net $ 24,373 $ 11,873 $ 28,252 (a) Fiscal 2017 amount includes a loss of $8,847 from correction of error (see Note 2).

Quarterly Data (Unaudited) (Tab

Quarterly Data (Unaudited) (Tables)	12 Months Ended
	Sep. 30, 2018
Quarterly Financial Information Disclosure [Abstract]
Unaudited Quarterly Data Including Adjustments	The following unaudited quarterly data includes all adjustments (consisting only of normal recurring adjustments with the exception of those indicated below) which we consider necessary for a fair presentation unless otherwise indicated. Our quarterly results fluctuate primarily because of the seasonal nature of our propane business and the effects of unrealized gains and losses on commodity derivative instruments used to economically hedge commodity price risk (see Note 16). December 31, March 31, June 30, September 30, 2017 2016 (c) 2018 2017 (c) 2018 (a) 2017 (b) (c) 2018 2017 Revenues $ 787,296 $ 677,166 $ 1,040,332 $ 863,660 $ 528,403 $ 467,496 $ 466,947 $ 445,173 Operating income (loss) $ 148,825 $ 167,631 $ 235,817 $ 199,864 $ (33,699 ) $ (1,137 ) $ 10,399 $ 21,500 Net income (loss) including noncontrolling interest $ 105,870 $ 93,615 $ 194,166 $ 137,083 $ (74,772 ) $ (46,794 ) $ (31,262 ) $ (18,035 ) Net income (loss) attributable to AmeriGas Partners, L.P. $ 104,421 $ 91,954 $ 191,824 $ 135,088 $ (74,396 ) $ (46,752 ) $ (31,327 ) $ (18,231 ) Income (loss) per limited partner unit (d): Basic $ 0.97 $ 0.87 $ 1.44 $ 1.14 $ (0.91 ) $ (0.62 ) $ (0.46 ) $ (0.32 ) Diluted $ 0.97 $ 0.87 $ 1.44 $ 1.14 $ (0.91 ) $ (0.62 ) $ (0.46 ) $ (0.32 ) (a) The quarter ended June 30, 2018, includes the impact of the impairment of Heritage tradenames and trademarks of $75,000 ( $74,242 after noncontrolling interest) (See Note 10). (b) Includes an environmental accrual associated with the site of a former MGP obtained in a prior-year acquisition of $7,545 ( $7,469 after noncontrolling interest) (See Note 12 ). (c) The quarters ended December 31, 2016, March 31, 2017 and June 30, 2017 include loss on extinguishments of debt of $33,151 , $22,144 and $4,434 , respectively (see Note 6). (d) Theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. in accordance with accounting guidance regarding the application of the two-class method for determining earnings per share (see Note 2 ) resulted in a different allocation of net income attributable to AmeriGas Partners, L.P. to the General Partner and the limited partners in the computation of income per limited partner unit which had the effect of decreasing quarterly earnings per limited partner unit for the quarters ended December 31 and March 31 as follows: December 31, March 31, Quarter ended: 2017 2016 2018 2017 Decrease in income per limited partner unit $ (0.02 ) $ — $ (0.48 ) $ (0.19 )

Nature of Operations (Details)

Nature of Operations (Details)	12 Months Ended
	Sep. 30, 2018stateemployee	Sep. 30, 2017	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of states in which the company has market share (in states) | state	50
General Partners Interest
General partners ownership interest (as a percent)	2.00%	2.00%	2.00%
Number of employees of the AmeriGas Partners and the Operating Partnership | employee	0
AmeriGas Propane Inc Partnership Interest In AmeriGas Partners
General Partners Interest
General partners ownership interest (as a percent)	1.00%
AmeriGas OLP
General Partners Interest
General partners ownership interest (as a percent)	1.01%
Limited partner interest held by AmeriGas Partners in AmeriGas OLP (as a percent)	98.99%

- Finance Corps. (Details)

- Finance Corps. (Details)	Sep. 30, 2018
AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance LLC
Related Party Transaction [Line Items]
Ownership percentage of finance subsidiaries	100.00%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Estimated Useful Lives by Type (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Depreciation	$ 145,826	$ 152,511	$ 151,575
Buildings and improvements | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	15 years
Buildings and improvements | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	40 years
Storage, customer tanks and cylinders and related assets | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	6 years
Storage, customer tanks and cylinders and related assets | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	30 years
Vehicles, equipment and office furniture and fixtures | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	3 years
Vehicles, equipment and office furniture and fixtures | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	10 years
Computer software | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	3 years
Computer software | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	10 years

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Goodwill and Intangible Assets (Details) - USD ($)	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Finite-Lived Intangible Assets [Line Items]
Accumulated impairment losses	$ 0	$ 0
Goodwill impairment	0	0	$ 0
Asset impairment charges	$ 0	$ 0	$ 0
Customer Relationships and Noncompete Agreements
Finite-Lived Intangible Assets [Line Items]
Estimated useful life of intangible assets (in years) does not exceed	15 years

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Allocation of Net Income (Loss) (Details) - $ / shares	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Dilutive effect of theoretical distributions of net income on earnings (in dollars per unit)	$ 0	$ 0.01	$ 0.02
AmeriGas Propane Inc Partnership Interest in AmeriGas Partners [Member]
Incentive Distribution Made to Managing Member or General Partner [Line Items]
General Partners' ownership interest (as a percent)	1.00%

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Income Per Limited Partner Unit (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Income per limited partner unit
Net income attributable to AmeriGas Partners, L.P.	$ (31,327)	$ (74,396)	$ 191,824	$ 104,421	$ (18,231)	$ (46,752)	$ 135,088	$ 91,954	$ 190,522	$ 162,059	$ 206,984
Adjust for general partner share and theoretical distributions of net income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs									(47,233)	(46,054)	(42,024)
Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs									$ 143,289	$ 116,005	$ 164,960
Weighted average Common Units outstanding — basic (in units)									93,034	92,996	92,949
Potentially dilutive Common Units (in units)									52	54	74
Weighted average Common Units outstanding — diluted (in units)									93,086	93,050	93,023

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Correction of Prior Period Errors (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Decrease in other operating income, net	$ (5,236)	$ 2,197	$ (8,062)
Increase (decrease) in depreciation	$ 145,826	152,511	$ 151,575
Correction of Error in Accounting for Gains on Sales of Certain Property, Plant and Equipment | Restatement Adjustment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Decrease in other operating income, net		8,847
Increase (decrease) in depreciation		(1,162)
Correction Of Error In Accounting For Depreciation Expense Relating To Certain Assets Acquired | Restatement Adjustment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Increase (decrease) in depreciation		$ 7,350

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2015
Business Combinations [Abstract]
Total net cash consideration	$ 10,090	$ 36,824	$ 37,560
Liabilities incurred	2,695	10,848	11,819
Business Acquisition
Goodwill	2,003,671	2,002,010	$ 1,978,981
Other Acquisitions
Business Acquisition
Net current assets	926	1,176
Net current (liabilities)				$ (162)
Property, plant and equipment	2,987	6,712		9,322
Goodwill	4,528	23,029		24,213
Customer relationships and noncompete agreements (estimated useful life of 10 and 5 years, respectively)	4,344	16,714		16,006
Other assets	0	41
Other (liabilities)				0
Total	$ 12,785	$ 47,672		$ 49,379
Other Acquisitions | Customer Relationships
Business Acquisition
Estimated useful life of intangible assets (in years)	10 years	10 years	10 years
Other Acquisitions | Noncompete Agreements
Business Acquisition
Estimated useful life of intangible assets (in years)	5 years	5 years	5 years

Quarterly Distributions of Av_3

Quarterly Distributions of Available Cash - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Distributions Made to Members or Limited Partners [Abstract]
Approximate time after end of each fiscal quarter quarterly distributions are made	45 days
Distribution of available cash to limited partners (as a percent)	98.00%
Distribution of available cash to general partners (as a percent)	2.00%
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Interest of general partner in distributions of available cash (as a percent)	2.00%	2.00%	2.00%
Minimum quarterly distribution (in dollars per unit)	$ 0.55
First target distribution (in dollars per unit)	0.055
Total of minimum target distribution and first target distribution (in dollars per unit)	$ 0.605	$ 0.605	$ 0.605
Aggregate amount of distributions received by the General Partner	$ 54,938	$ 52,742	$ 47,432
Incentive distributions received by the General Partner	$ 45,321	$ 43,525	$ 38,157
AmeriGas OLP
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Interest of general partner in distributions of available cash (as a percent)	1.01%

Quarterly Distributions of Av_4

Quarterly Distributions of Available Cash - Quarterly Distributions of Available Cash Per Limited Partner Unit (Details) - $ / shares	3 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015
Distributions Made to Members or Limited Partners [Abstract]
Quarterly distributions of available cash per limited partner unit (in dollars per unit)	$ 0.95	$ 0.95	$ 0.95	$ 0.95	$ 0.95	$ 0.95	$ 0.94	$ 0.94	$ 0.94	$ 0.94	$ 0.92	$ 0.92

Debt - Schedule of Long Term De

Debt - Schedule of Long Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Debt Instrument [Line Items]
Other	$ 14,615	$ 17,262
Total long-term debt	2,597,131	2,603,610
Less: unamortized debt issuance costs	(27,498)	(31,331)
Less: current maturities	(8,626)	(8,447)
Total long-term debt due after one year	2,561,007	2,563,832
Heritage Operating, L.P. (“HOLP”) Senior Secured Notes
Debt Instrument [Line Items]
Heritage Operating, L.P. (“HOLP”) Senior Secured Notes	7,516	11,348
Senior Notes | 5.50% due May 2025
Debt Instrument [Line Items]
AmeriGas Partners Senior Notes	$ 700,000	$ 700,000
Stated interest rate	5.50%	5.50%
Senior Notes | 5.875% due August 2026
Debt Instrument [Line Items]
AmeriGas Partners Senior Notes	$ 675,000	$ 675,000
Stated interest rate	5.875%		5.875%
Senior Notes | 5.75% due May 2027
Debt Instrument [Line Items]
AmeriGas Partners Senior Notes	$ 525,000	$ 525,000
Stated interest rate	5.75%	5.75%
Senior Notes | 5.625% due May 2024
Debt Instrument [Line Items]
AmeriGas Partners Senior Notes	$ 675,000	$ 675,000
Stated interest rate	5.625%		5.625%

Debt - Narrative (Details)

Debt - Narrative (Details) $ in Thousands	Sep. 30, 2018USD ($)
Debt Disclosure [Abstract]
Principal repayments of long-term debt due in 2019	$ 8,758
Principal repayments of long-term debt due in 2020	7,950
Principal repayments of long-term debt due in 2021	3,559
Principal repayments of long-term debt due in 2022	1,598
Principal repayments of long-term debt due in 2023	$ 266

Debt - AmeriGas Partners Senior

Debt - AmeriGas Partners Senior Notes (Details) - Senior Notes - USD ($)	12 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2018
Debt Instrument [Line Items]
Aggregate principal balance redeemed		$ 1,270,001,000
5.50% due May 2025
Debt Instrument [Line Items]
Debt instrument principal amount	$ 700,000,000
Stated interest rate	5.50%		5.50%
5.75% due May 2027
Debt Instrument [Line Items]
Debt instrument principal amount	$ 525,000,000
Stated interest rate	5.75%		5.75%
7.00%, due May 2022
Debt Instrument [Line Items]
Stated interest rate	7.00%
Aggregate principal balance repaid	$ 980,844,000
5.625% due May 2024
Debt Instrument [Line Items]
Debt instrument principal amount		$ 675,000,000
Stated interest rate		5.625%	5.625%
5.875% due August 2026
Debt Instrument [Line Items]
Debt instrument principal amount		$ 675,000,000
Stated interest rate		5.875%	5.875%
6.50% Senior Notes
Debt Instrument [Line Items]
Stated interest rate		6.50%
6.75% Senior Notes
Debt Instrument [Line Items]
Stated interest rate		6.75%
6.25% Senior Notes
Debt Instrument [Line Items]
Stated interest rate		6.25%

Debt - Losses on Extinguishment

Debt - Losses on Extinguishments of Debt (Details) - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Extinguishment of Debt [Line Items]
Loss on extinguishments of debt	$ 4,434	$ 22,144	$ 33,151	$ 0	$ 59,729	$ 48,889
Senior Notes | 7.00%, due May 2022
Extinguishment of Debt [Line Items]
Early redemption premiums					51,253	39,569
Write-off of unamortized debt issuance costs					8,476	9,320
Loss on extinguishments of debt					$ 59,729	$ 48,889

Debt - HOLP Senior Secured Note

Debt - HOLP Senior Secured Notes (Details) - HOLP Senior Secured Notes - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Debt Instrument [Line Items]
Total long-term debt	$ 7,516	$ 11,348
Unamortized premium	$ 244	$ 439
Effective interest rate	6.75%	6.75%

Debt - AmeriGas OLP Credit Agre

Debt - AmeriGas OLP Credit Agreement (Details) - USD ($)	1 Months Ended
	Dec. 31, 2017	Sep. 30, 2018	Sep. 30, 2017
Debt Instrument [Line Items]
Short-term bank loans and notes payable		$ 232,000,000	$ 140,000,000
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity under revolving credit facility	$ 600,000,000
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Spread on variable interest rate	0.50%
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility | Base Rate | Minimum
Debt Instrument [Line Items]
Spread on variable interest rate	0.50%
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility | Base Rate | Maximum
Debt Instrument [Line Items]
Spread on variable interest rate	1.75%
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility | Eurodollar | Minimum
Debt Instrument [Line Items]
Spread on variable interest rate	1.50%
Line of Credit | Second Amended Credit Agreement | Revolving Credit Facility | Eurodollar | Maximum
Debt Instrument [Line Items]
Spread on variable interest rate	2.75%
Line of Credit | Second Amended Credit Agreement | Letter of Credit
Debt Instrument [Line Items]
Maximum borrowing capacity under revolving credit facility	$ 150,000,000
Line of Credit | Credit Agreement | AmeriGas OLP
Debt Instrument [Line Items]
Short-term bank loans and notes payable		$ 232,000,000	$ 140,000,000
Interest rate at period end		4.58%	3.74%
Letters of credit issued and outstanding		$ 63,497,000	$ 67,211,000

Debt - Restrictive Covenants (D

Debt - Restrictive Covenants (Details)	12 Months Ended
	Sep. 30, 2018USD ($)
Debt Instrument [Line Items]
Amount of net assets	$ 2,800,000,000
Senior Notes
Debt Instrument [Line Items]
Fixed charge coverage ratio	1.75
Cash distributions in a total amount	$ 300,000,000

Employee Retirement Plans (Deta

Employee Retirement Plans (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Retirement Benefits [Abstract]
Employee contribution on retirement plans, dollar-for-dollar percentage match	100.00%
Percentage of eligible compensation	5.00%
Cost of benefits under savings plan	$ 11,412	$ 10,775	$ 10,335

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Inventory Disclosure [Abstract]
Propane gas	$ 114,005	$ 99,035
Materials, supplies and other	10,546	11,899
Appliances for sale	5,976	5,745
Total inventories	$ 130,527	$ 116,679
Minimum
Inventory [Line Items]
Inventory contract period (in years)	1 year
Maximum
Inventory [Line Items]
Inventory contract period (in years)	3 years

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	$ 2,300,109	$ 2,718,600
Less accumulated depreciation	(1,151,726)	(1,511,890)
Net property, plant and equipment	1,148,383	1,206,710
Land
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	135,809	135,965
Buildings and improvements
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	197,148	196,798
Transportation equipment
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	214,526	250,493
Storage facilities
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	212,686	268,415
Equipment, primarily cylinders and tanks
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	1,330,049	1,612,375
Work in process
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	27,859	19,517
Other
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment	$ 182,032	$ 235,037

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets - Changes in the Carrying Amount of Goodwill (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Goodwill [Roll Forward]
Beginning balance	$ 2,002,010	$ 1,978,981
Acquisitions	4,528	23,029
Dispositions	(2,867)
Ending balance	$ 2,003,671	$ 2,002,010

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Components of Intangible Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Customer relationships and noncompete agreements (subject to amortization)	$ 497,373		$ 497,385
Trademarks and tradenames (subject to amortization)	7,944	$ 7,944	0
Trademarks and tradenames (not subject to amortization)	0		82,944
Gross carrying amount	505,317		580,329
Accumulated amortization	(225,709)		(190,289)
Intangible assets, net	$ 279,608		$ 390,040

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Jun. 30, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization of intangible assets		$ 39,927	$ 37,994	$ 38,405
Fiscal 2,019		40,389
Fiscal 2,020		39,152
Fiscal 2,021		35,914
Fiscal 2,022		32,963
Fiscal 2,023		31,627
Trademarks and tradenames (subject to amortization)	$ 7,944	$ 7,944	$ 0
Non cash impairment charge	$ 75,000

Partners' Capital and Equity _3

Partners' Capital and Equity Compensation Plans - Partners' Capital (Details) - USD ($)	Nov. 07, 2017	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016	Jul. 01, 2019
Share-based Compensation Arrangement by Share-based Payment Award
Capital contribution commitment		$ 0	$ 1,602,000	$ 39,000
Class B Units
Share-based Compensation Arrangement by Share-based Payment Award
Number of volume days of weighted average price of Partnership's common units	20 days
Basis points on annualized yield (as a percent)	1.30%
Period from initial issuance, holders may elect to convert units	5 years
Conversion ratio	1
Period from initial issuance, holders may elect to convert subject to certain conditions	6 years
Trading price, greater than (as a percent)	110.00%
Scenario, Forecast
Share-based Compensation Arrangement by Share-based Payment Award
Capital contribution commitment					$ 225,000,000

Partners' Capital and Equity _4

Partners' Capital and Equity Compensation Plans - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award
Equity based compensation expenses	$ 3,432	$ 3,920	$ 4,025
Fair value of common unit based awards that vested during period	2,156	2,056	$ 1,968
Total liabilities associated with common unit based awards reflected in the Consolidated Balance Sheet	$ 2,297	$ 2,501
2010 Plan
Share-based Compensation Arrangement by Share-based Payment Award
Common units available for future award grants (in units)	2,800,000
Expiration period (in years)	10 years
Common units granted by General Partner in period (in units)	84,811	67,563	73,080
Weighted-average grant date fair value per Common Unit subject to award during period (in dollars per unit)	$ 50.05	$ 52.37	$ 37.93
Common Units available for future award grants (in units)	2,242,468
AmeriGas Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Term of the AmeriGas performance unit awards	3 years
Expected volatility measurement period (in years)	3 years
Common units granted by General Partner in period (in units)	55,550
Weighted-average grant date fair value per Common Unit subject to award during period (in dollars per unit)	$ 52.14
AmeriGas Performance Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	0.00%
AmeriGas Performance Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	200.00%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 25th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	25.00%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 40th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	70.00%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 50th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	100.00%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 60th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	125.00%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 75th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	162.50%
AmeriGas Performance Units | Grants Issued on or After January 1, 2013 | Total Unitholder Return vs Alerian MLP Group at 90th Percentile
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	200.00%
AmeriGas Performance Units | Grants Issued in January 1, 2015 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	0.00%
Modification range	70.00%
AmeriGas Performance Units | Grants Issued in January 1, 2015 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	200.00%
Modification range	130.00%
AmeriGas Performance Units | Certain Grants Issued on or After January 2014 | Total Unitholder Return Highest of Propane MLP Group
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	150.00%
AmeriGas Performance Units | Grants Issued In January 2016 | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	0.00%
AmeriGas Performance Units | Grants Issued In January 2016 | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted	200.00%
UGI Stock Option
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized equity-based compensation expense related to non-vested UGI stock options	$ 1,162
Weighted average period of recognition	1 year 9 months 18 days
Common Unit Awards
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized equity-based compensation expense related to non-vested UGI stock options	$ 1,922
Weighted average period of recognition	1 year 8 months 12 days
Common units subject to award (in units)	236,762

Partners' Capital and Equity _5

Partners' Capital and Equity Compensation Plans - Weighted-Average Assumptions Used to Determine Fair Value of AmeriGas Performance Unit Awards and Related Compensation Costs (Details)	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Fair value of AmeriGas Performance Unit awards and related compensation costs
Risk-free rate	2.00%	1.50%	1.30%
Expected life	3 years	3 years	3 years
Expected volatility	21.10%	21.70%	20.60%
Dividend Yield	8.20%	7.80%	10.70%

Partners' Capital and Equity _6

Partners' Capital and Equity Compensation Plans - Amerigas Common Unit-Based Award Activity (Details)	12 Months Ended
	Sep. 30, 2018$ / sharesshares
Common Units
Beginning balance (in units)	218,224
Ending balance (in units)	236,762
Weighted-Average Grant-Date Fair Value (per Unit)
Beginning balance (in dollars per unit) | $ / shares	$ 50.03
Ending balance (in dollars per unit) | $ / shares	$ 47.12
AmeriGas Performance Units
Common Units
Granted (in units)	55,550
Forfeited (in units)	(1,900)
Awards paid (in units)	(18,874)
Performance criteria not met (in units)	(37,099)
Weighted-Average Grant-Date Fair Value (per Unit)
Granted (in dollars per unit) | $ / shares	$ 52.14
Forfeited (in dollars per unit) | $ / shares	56.70
Awards paid (in dollars per unit) | $ / shares	86.53
Performance criteria not met (in dollars per unit) | $ / shares	$ 51.93
AmeriGas Stock Units
Common Units
Granted (in units)	29,261
Forfeited (in units)	(400)
Awards paid (in units)	(8,000)
Weighted-Average Grant-Date Fair Value (per Unit)
Granted (in dollars per unit) | $ / shares	$ 46.09
Forfeited (in dollars per unit) | $ / shares	45.66
Awards paid (in dollars per unit) | $ / shares	$ 45.62
Vested
Common Units
Beginning balance (in units)	65,989
Ending balance (in units)	71,148

Partners' Capital and Equity _7

Partners' Capital and Equity Compensation Plans - Partnership Paid AmeriGas Common Unit-Based Awards in Common Units and Cash (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
AmeriGas Performance Unit awards
Share-based Compensation Arrangement by Share-based Payment Award
Number of Common Units subject to original Awards granted (in units)	65,525	53,800	44,800
Performance periods beginning in fiscal years:	2,015	2,014	2,013
Payment of awards:
AmeriGas Partners Common Units issued, net of units withheld for taxes (in units)	13,164,000	29,489,000	23,017,000
Cash paid	$ 1,227	$ 2,928	$ 1,718
AmeriGas Stock Unit awards
Share-based Compensation Arrangement by Share-based Payment Award
Number of Common Units subject to original Awards granted (in units)	14,811	32,658	20,336
Payment of awards:
AmeriGas Partners Common Units issued, net of units withheld for taxes (in units)	5,322	3,932	9,272
Cash paid	$ 131	$ 95	$ 370

Commitments and Contingencies -

Commitments and Contingencies - Commitments (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Aggregate rental expense for leases	$ 83,418	$ 78,880	$ 73,043
Operating Leased Assets [Line Items]
Residual value guarantee of operating lease arrangement	$ 55,000
Minimum
Operating Leased Assets [Line Items]
Remaining lease terms	1 year
Maximum
Operating Leased Assets [Line Items]
Remaining lease terms	10 years

Commitments and Contingencies_2

Commitments and Contingencies - Minimum Future Payments Under Noncancellable Operating Leases (Details) $ in Thousands	Sep. 30, 2018USD ($)
Year Ending September 30,
2,019	$ 74,748
2,020	68,350
2,021	60,713
2,022	52,771
2,023	45,816
Thereafter	105,502
Total minimum operating lease payments	$ 407,900

Commitments and Contingencies_3

Commitments and Contingencies - Contingencies (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2018lb	Sep. 30, 2017USD ($)record_of_decision	Jun. 30, 2017USD ($)
FTC Cylinder Investigation
Loss Contingencies [Line Items]
Amount of propane in cylinders before reduction (in pounds) | lb	17
Amount of propane in cylinders after reduction (in pounds) | lb	15
Saranac Lake, New York | DEC | AmeriGas OLP
Loss Contingencies [Line Items]
Number of RODs | record_of_decision		3
Estimated cost of selected remediation plan | $		$ 27,700
Environmental remediation liability | $			$ 7,545

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($)	11 Months Ended	12 Months Ended			20 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016	Jul. 01, 2019
Related Party Transaction [Line Items]
Capital contribution commitment	$ 0		$ 1,602,000	$ 39,000
Scenario, Forecast
Related Party Transaction [Line Items]
Capital contribution commitment					$ 225,000,000
General Partner | Reimbursed Expenses or Payments
Related Party Transaction [Line Items]
Related party costs and expenses		$ 575,699,000	561,574,000	556,964,000
General Partner | General and Administrative Services | UGI Corp
Related Party Transaction [Line Items]
Related party costs and expenses		17,225,000	16,862,000	18,680,000
General Partner | UGI Corp Office Insurance Reimbursement | UGI Corp
Related Party Transaction [Line Items]
Related party costs and expenses		3,391,000	3,283,000	2,323,000
Affiliated Entity | Propane Purchases | Energy Services
Related Party Transaction [Line Items]
Related party costs and expenses		0	0	0
Affiliated Entity | Sales to UGI Affiliates
Related Party Transaction [Line Items]
Revenue from related parties		$ 0	$ 0	$ 0

Other Current Liabilities (Deta

Other Current Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Payables and Accruals [Abstract]
Litigation, property and casualty liabilities	$ 56,860	$ 65,071
Taxes other than income taxes	11,945	12,207
Deferred tank rent revenue	16,336	16,533
Other	20,769	19,770
Total other current liabilities	$ 105,910	$ 113,581

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Financial Liabilities at Fair Value (Details) - Fair Value, Measurements, Recurring - Commodity contracts - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Assets:
Commodity contracts	$ 52,529	$ 40,714
Liabilities:
Commodity contracts	(251)	(920)
Level 1
Assets:
Commodity contracts	0	0
Liabilities:
Commodity contracts	0	0
Level 2
Assets:
Commodity contracts	52,529	40,714
Liabilities:
Commodity contracts	(251)	(920)
Level 3
Assets:
Commodity contracts	0	0
Liabilities:
Commodity contracts	$ 0	$ 0

Fair Value Measurements - Nonre

Fair Value Measurements - Nonrecurring Fair Value Measurements (Details) $ in Thousands	Apr. 30, 2018USD ($)
Trademarks and Trade Names
Finite-Lived Intangible Assets [Line Items]
Trademarks and tradenames (subject to amortization)	$ 7,944

Fair Value Measurements - Other

Fair Value Measurements - Other Financial Instruments (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 2,597,131	$ 2,603,610
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 2,562,206	$ 2,699,428

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Commodity Price Risk (Details) - gal gal in Millions	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Underlying derivative (in gallons)	244.8	213.6
Maximum period of economically hedging propane market price risk	24 months

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Components of Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Derivative assets
Derivative assets:
Total derivative assets — gross	$ 52,529	$ 40,714
Gross amounts offset in the balance sheet	(251)	(920)
Cash collateral received	(7,270)	(7,991)
Total derivative assets — net	45,008	31,803
Derivative assets | Derivatives not designated as hedging instruments | Commodity contracts
Derivative assets:
Total derivative assets — gross	52,529	40,714
Derivative liabilities
Derivative liabilities:
Total derivative liabilities — gross	(251)	(920)
Gross amounts offset in the balance sheet	251	920
Total derivative liabilities	0	0
Derivative liabilities | Derivatives not designated as hedging instruments | Commodity contracts
Derivative liabilities:
Total derivative liabilities — gross	$ (251)	$ (920)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Components of Derivative Instruments Gain Loss In Statement Of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Cost of sales — propane
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 62,316	$ 65,644	$ 2,567

Other Operating Income, Net - C

Other Operating Income, Net - Component (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Other Income and Expenses [Abstract]
Finance charges	$ 16,379	$ 11,805	$ 15,201
(Losses) gains on sales of fixed assets	5,236	(2,197)	8,062
Other	2,758	2,265	4,989
Total other operating income, net	$ 24,373	$ 11,873	$ 28,252

Other Operating Income, Net - F

Other Operating Income, Net - Footnote (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Loss on sales of fixed assets	$ (5,236)	$ 2,197	$ (8,062)
Restatement Adjustment | Correction of Error in Accounting for Gains on Sales of Certain Property, Plant and Equipment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Loss on sales of fixed assets		$ 8,847

Quarterly Data (Unaudited) - Un

Quarterly Data (Unaudited) - Unaudited Quarterly Data Including Adjustments (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 466,947	$ 528,403	$ 1,040,332	$ 787,296	$ 445,173	$ 467,496	$ 863,660	$ 677,166	$ 2,822,978	$ 2,453,495	$ 2,311,817
Operating income (loss)	10,399	(33,699)	235,817	148,825	21,500	(1,137)	199,864	167,631	361,342	387,858	422,604
Net income (loss) including noncontrolling interest	(31,262)	(74,772)	194,166	105,870	(18,035)	(46,794)	137,083	93,615	194,002	165,869	211,193
Net income (loss) attributable to AmeriGas Partners, L.P.	$ (31,327)	$ (74,396)	$ 191,824	$ 104,421	$ (18,231)	$ (46,752)	$ 135,088	$ 91,954	$ 190,522	$ 162,059	$ 206,984
Income (loss) per limited partner unit:
Basic (in dollars per unit)	$ (0.46)	$ (0.91)	$ 1.44	$ 0.97	$ (0.32)	$ (0.62)	$ 1.14	$ 0.87	$ 1.54	$ 1.25	$ 1.77
Diluted (in dollars per unit)	$ (0.46)	$ (0.91)	$ 1.44	$ 0.97	$ (0.32)	$ (0.62)	$ 1.14	$ 0.87	$ 1.54	$ 1.25	$ 1.77

Quarterly Data (Unaudited) - _2

Quarterly Data (Unaudited) - Unaudited Quarterly Data Including Adjustments (Footnotes) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended						12 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Effect of Fourth Quarter Events [Line Items]
Impairment	$ 75,000
Loss on extinguishments of debt				$ 4,434	$ 22,144	$ 33,151	$ 0	$ 59,729	$ 48,889
Decrease in income per limited partner unit (in dollars per unit)		$ (0.48)	$ (0.02)		$ (0.19)	$ 0
Net Income (Loss) Attributable to AmeriGas Partners, L.P.
Effect of Fourth Quarter Events [Line Items]
Environmental accrual				7,545
Operating Loss
Effect of Fourth Quarter Events [Line Items]
Environmental accrual				$ 7,469
Trademarks and Trade Names | Net Income (Loss) Attributable to AmeriGas Partners, L.P.
Effect of Fourth Quarter Events [Line Items]
Impairment	74,242
Trademarks and Trade Names | Operating Loss
Effect of Fourth Quarter Events [Line Items]
Impairment	$ 75,000

Schedule I - Condensed Financ_2

Schedule I - Condensed Financial Information of Registrant (Parent Company) - Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Sep. 30, 2017
Current assets:
Total current assets	$ 451,891	$ 413,774
Other assets	35,918	45,407
Total assets	3,925,818	4,059,261
Current liabilities:
Accounts payable and other liabilities	105,910	113,581
Total current liabilities	678,028	581,532
Long-term debt	2,561,007	2,563,832
Commitments and contingencies
Partners’ capital:
Common unitholders	523,925	733,104
General partner	12,682	14,795
Total AmeriGas Partners, L.P. partners’ capital	536,607	747,899
Total liabilities and partners’ capital	3,925,818	4,059,261
Parent Company
Current assets:
Cash	1,105	1,529
Total current assets	1,105	1,529
Investment in AmeriGas Propane, L.P.	3,128,927	3,335,902
Other assets	56	56
Total assets	3,130,088	3,337,487
Current liabilities:
Accounts payable and other liabilities	2,879	2,820
Accrued interest	42,921	42,921
Total current liabilities	45,800	45,741
Long-term debt	2,547,681	2,543,847
Commitments and contingencies
Partners’ capital:
Common unitholders	523,925	733,104
General partner	12,682	14,795
Total AmeriGas Partners, L.P. partners’ capital	536,607	747,899
Total liabilities and partners’ capital	$ 3,130,088	$ 3,337,487

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information of Registrant (Parent Company) - Statements of Operations (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Condensed Income Statements
Operating expenses, net	$ 10,399	$ (33,699)	$ 235,817	$ 148,825	$ 21,500	$ (1,137)	$ 199,864	$ 167,631	$ 361,342	$ 387,858	$ 422,604
Loss on extinguishments of debt						(4,434)	(22,144)	(33,151)	0	(59,729)	(48,889)
Interest expense (including related party interest expense)									(163,125)	(160,226)	(164,095)
Net income including noncontrolling interest	(31,262)	(74,772)	194,166	105,870	(18,035)	(46,794)	137,083	93,615	194,002	165,869	211,193
Equity in income of AmeriGas Propane, L.P.									(3,480)	(3,810)	(4,209)
Net income attributable to AmeriGas Partners, L.P.	$ (31,327)	$ (74,396)	$ 191,824	$ 104,421	$ (18,231)	$ (46,752)	$ 135,088	$ 91,954	190,522	162,059	206,984
General partner’s interest in net income attributable to AmeriGas Partners									47,226	45,146	40,227
Limited partners’ interest in net income attributable to AmeriGas Partners									$ 143,296	$ 116,913	$ 166,757
Weighted average limited partner units outstanding — basic (in units)									93,034	92,996	92,949
Weighted average limited partner units outstanding — diluted (in units)									93,086	93,050	93,023
Parent Company
Condensed Income Statements
Operating expenses, net									$ (258)	$ (300)	$ (255)
Loss on extinguishments of debt									0	(59,729)	(48,889)
Interest expense (including related party interest expense)									(150,204)	(151,294)	(156,350)
Net income including noncontrolling interest									(150,462)	(211,323)	(205,494)
Equity in income of AmeriGas Propane, L.P.									340,984	373,382	412,478
Net income attributable to AmeriGas Partners, L.P.									190,522	162,059	206,984
General partner’s interest in net income attributable to AmeriGas Partners									47,226	45,146	40,227
Limited partners’ interest in net income attributable to AmeriGas Partners									$ 143,296	$ 116,913	$ 166,757
Income per limited partner unit — basic and diluted (in dollars per unit)									$ 1.54	$ 1.25	$ 1.77
Weighted average limited partner units outstanding — basic (in units)									93,034	92,996	92,949
Weighted average limited partner units outstanding — diluted (in units)									93,086	93,050	93,023

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information of Registrant (Parent Company) - Statements of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Condensed Cash Flow Statements
NET CASH PROVIDED BY OPERATING ACTIVITIES	$ 410,269	$ 356,782	$ 422,943
CASH FLOWS FROM INVESTING ACTIVITIES
Net cash used by investing activities	(84,187)	(115,053)	(124,617)
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions	(402,645)	(398,877)	(387,659)
Issuance of long-term debt, net of issuance costs	0	1,207,727	1,331,293
Repayment of long-term debt, including redemption premiums	(9,054)	(1,043,744)	(1,321,750)
Capital contributions from General Partner	8	15	11
Net cash used by financing activities	(326,520)	(250,240)	(297,256)
Cash and cash equivalents (decrease) increase	(438)	(8,511)	1,070
CASH AND CASH EQUIVALENTS
End of year	6,878	7,316	15,827
Beginning of year	7,316	15,827	14,757
Cash and cash equivalents (decrease) increase	(438)	(8,511)	1,070
Parent Company
Condensed Cash Flow Statements
NET CASH PROVIDED BY OPERATING ACTIVITIES	401,412	368,634	371,536
CASH FLOWS FROM INVESTING ACTIVITIES
Contributions to AmeriGas Propane, L.P.	0	(157,000)	(3,900)
Net cash used by investing activities	0	(157,000)	(3,900)
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions	(402,645)	(398,877)	(387,659)
Issuance of long-term debt, net of issuance costs	0	1,207,727	1,331,293
Repayment of long-term debt, including redemption premiums	0	(1,032,097)	(1,309,588)
Proceeds associated with equity based compensation plans, net of tax withheld	801	1,465	1,127
Capital contributions from General Partner	8	15	11
Net cash used by financing activities	(401,836)	(221,767)	(364,816)
Cash and cash equivalents (decrease) increase	(424)	(10,133)	2,820
CASH AND CASH EQUIVALENTS
End of year	1,105	1,529	11,662
Beginning of year	1,529	11,662	8,842
Cash and cash equivalents (decrease) increase	(424)	(10,133)	2,820
Distributions received from AmeriGas Propane, L.P	$ 547,958	$ 512,326	$ 530,912

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - Allowance for doubtful accounts - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2016
Valuation And Qualifying Accounts
Balance at beginning of year	$ 11,820	$ 11,436	$ 12,257
Charged to costs and expenses	14,016	17,693	11,215
Other	(13,011)	(17,309)	(12,036)
Balance at end of year	$ 12,825	$ 11,820	$ 11,436