AMERIGAS PARTNERS LP, 10-Q filed on 2/6/2018
Quarterly Report
Document and Entity Information
3 Months Ended
Dec. 31, 2017
Jan. 31, 2018
Document and Entity Information [Abstract]
 
 
Entity Registrant Name
AMERIGAS PARTNERS LP 
 
Entity Central Index Key
0000932628 
 
Document Type
10-Q 
 
Document Period End Date
Dec. 31, 2017 
 
Amendment Flag
false 
 
Document Fiscal Year Focus
2018 
 
Document Fiscal Period Focus
Q1 
 
Current Fiscal Year End Date
--09-30 
 
Entity Filer Category
Large Accelerated Filer 
 
Entity Common Stock, Shares Outstanding
 
92,975,954 
Condensed Consolidated Balance Sheets (unaudited) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Current assets:
 
 
 
Cash and cash equivalents
$ 7,197 
$ 7,316 
$ 9,253 
Accounts receivable (less allowances for doubtful accounts of $14,953, $11,820 and $13,014, respectively)
334,820 
197,776 
311,243 
Accounts receivable — related parties
3,041 
3,665 
3,085 
Inventories
135,849 
116,679 
98,931 
Derivative instruments
30,925 
30,483 
27,084 
Prepaid expenses and other current assets
69,409 
57,855 
55,979 
Total current assets
581,241 
413,774 
505,575 
Property, plant and equipment (less accumulated depreciation and amortization of $1,524,282, $1,511,890 and $1,527,769, respectively)
1,189,397 
1,206,710 
1,256,291 
Goodwill
2,002,010 
2,002,010 
1,979,146 
Intangible assets, net
380,433 
390,040 
402,188 
Derivative instruments
1,453 
1,320 
7,390 
Other assets
37,570 
45,407 
49,190 
Total assets
4,192,104 
4,059,261 
4,199,780 
Current liabilities:
 
 
 
Current maturities of long-term debt
8,447 
8,447 
7,570 
Short-term borrowings
263,500 
140,000 
77,500 
Accounts payable — trade
183,983 
119,686 
157,160 
Accounts payable — related parties
108 
304 
707 
Customer deposits and advances
89,544 
109,453 
103,762 
Other current liabilities
173,592 
203,642 
195,701 
Total current liabilities
719,174 
581,532 
542,400 
Long-term debt
2,563,441 
2,563,832 
2,519,950 
Other noncurrent liabilities
122,641 
130,826 
123,319 
Total liabilities
3,405,256 
3,276,190 
3,185,669 
Commitments and contingencies (Note 6)
   
   
   
AmeriGas Partners, L.P. partners’ capital:
 
 
 
Common unitholders (units issued — 92,963,340, 92,958,586 and 92,926,920, respectively)
736,966 
733,104 
960,510 
General partner
14,832 
14,795 
16,760 
Total AmeriGas Partners, L.P. partners’ capital
751,798 
747,899 
977,270 
Noncontrolling interest
35,050 
35,172 
36,841 
Total partners’ capital
786,848 
783,071 
1,014,111 
Total liabilities and partners’ capital
$ 4,192,104 
$ 4,059,261 
$ 4,199,780 
Condensed Consolidated Balance Sheets (unaudited) (Parenthetical) (USD $)
In Thousands, except Share data, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Statement of Financial Position [Abstract]
 
 
 
Accounts receivable, allowances for doubtful accounts
$ 14,953 
$ 11,820 
$ 13,014 
Property, plant and equipment, accumulated depreciation and amortization
$ 1,524,282 
$ 1,511,890 
$ 1,527,769 
Common unitholders, units issued (in shares)
92,963,340 
92,958,586 
92,926,920 
Condensed Consolidated Statements of Operations (unaudited) (USD $)
In Thousands, except Per Share data, unless otherwise specified
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Revenues:
 
 
Propane
$ 711,464 
$ 604,056 
Other
75,832 
73,110 
Total, revenues
787,296 
677,166 
Costs and expenses:
 
 
Cost of sales — propane (excluding depreciation shown below)
344,351 
214,405 
Cost of sales — other (excluding depreciation shown below)
20,994 
20,582 
Operating and administrative expenses
230,339 
226,802 
Depreciation
37,817 
33,989 
Amortization
9,607 
10,622 
Other operating (income) expense, net
(4,637)
3,135 
Total, costs and expenses
638,471 
509,535 
Operating income
148,825 
167,631 
Loss on extinguishments of debt
0 
(33,151)
Interest expense
(40,577)
(40,028)
Income before income taxes
108,248 
94,452 
Income tax expense
(2,378)
(837)
Net income including noncontrolling interest
105,870 
93,615 
Deduct net income attributable to noncontrolling interest
(1,449)
(1,661)
Net income attributable to AmeriGas Partners, L.P.
104,421 
91,954 
General partner’s interest in net income attributable to AmeriGas Partners, L.P.
12,372 
11,352 
Limited partners’ interest in net income attributable to AmeriGas Partners, L.P.
$ 92,049 
$ 80,602 
Income per limited partner unit:
 
 
Basic (in usd per share)
$ 0.97 
$ 0.87 
Diluted (in usd per share)
$ 0.97 
$ 0.87 
Weighted average limited partner units outstanding (thousands):
 
 
Basic (in shares)
93,016 
92,967 
Diluted (in shares)
93,080 
93,019 
Condensed Consolidated Statements of Cash Flows (unaudited) (USD $)
In Thousands, unless otherwise specified
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
 
 
Net income including noncontrolling interest
$ 105,870 
$ 93,615 
Adjustments to reconcile net income including noncontrolling interest to net cash provided by operating activities:
 
 
Depreciation and amortization
47,424 
44,611 
Provision for uncollectible accounts
4,878 
3,308 
Changes in unrealized losses (gains) on derivative instruments
(751)
(25,730)
Loss on extinguishments of debt
0 
33,151 
Other, net
2,026 
5,274 
Net change in:
 
 
Accounts receivable
(141,299)
(132,293)
Inventories
(19,170)
(20,068)
Accounts payable
64,101 
64,201 
Other current assets
(11,553)
(4,291)
Other current liabilities
(49,705)
(28,735)
Net cash provided by operating activities
1,821 
33,043 
CASH FLOWS FROM INVESTING ACTIVITIES
 
 
Expenditures for property, plant and equipment
(23,586)
(26,380)
Proceeds from disposals of assets
3,661 
2,826 
Acquisitions of businesses, net of cash acquired
0 
(835)
Net cash used by investing activities
(19,925)
(24,389)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
Distributions
(100,650)
(99,091)
Noncontrolling interest activity
(1,571)
192 
Increase (decrease) in short-term borrowings
123,500 
(75,700)
Issuances of long-term debt, net of issuance costs
0 
690,000 
Repayments of long-term debt, including redemption premiums
(1,255)
(530,629)
Other
(2,039)
0 
Net cash provided (used) by financing activities
17,985 
(15,228)
Cash and cash equivalents decrease
(119)
(6,574)
CASH AND CASH EQUIVALENTS
 
 
End of period
7,197 
9,253 
Beginning of period
7,316 
15,827 
Decrease
$ (119)
$ (6,574)
Condensed Consolidated Statements of Partners' Capital (unaudited) (USD $)
Total
Total AmeriGas Partners, L.P. partners’ capital
Common units
General partner
Noncontrolling interest
Beginning Balance at Sep. 30, 2016
$ 1,019,209,000 
$ 984,221,000 
$ 967,073,000 
$ 17,148,000 
$ 34,988,000 
Beginning Balance (in units) at Sep. 30, 2016
 
 
92,923,410 
 
 
Increase (Decrease) in Partners' Capital
 
 
 
 
 
Net income including noncontrolling interest
93,615,000 
91,954,000 
80,602,000 
11,352,000 
1,661,000 
Distributions
(100,501,000)
(99,091,000)
(87,351,000)
(11,740,000)
(1,410,000)
Unit-based compensation expense
239,000 
239,000 
239,000 
 
 
General Partner contribution to AmeriGas Propane, L.P.
1,602,000 
 
 
 
1,602,000 
Common Units issued in connection with employee and director plans, net of tax withheld (in units)
 
 
3,510 
 
 
Common Units issued in connection with employee and director plans, net of tax withheld
(53,000)
(53,000)
(53,000)
 
 
Ending Balance at Dec. 31, 2016
1,014,111,000 
977,270,000 
960,510,000 
16,760,000 
36,841,000 
Ending Balance (in units) at Dec. 31, 2016
 
 
92,926,920 
 
 
Beginning Balance at Sep. 30, 2017
783,071,000 
747,899,000 
733,104,000 
14,795,000 
35,172,000 
Beginning Balance (in units) at Sep. 30, 2017
 
 
92,958,586 
 
 
Increase (Decrease) in Partners' Capital
 
 
 
 
 
Net income including noncontrolling interest
105,870,000 
104,421,000 
92,049,000 
12,372,000 
1,449,000 
Distributions
(102,221,000)
(100,650,000)
(88,315,000)
(12,335,000)
(1,571,000)
Unit-based compensation expense
190,000 
190,000 
190,000 
 
 
General Partner contribution to AmeriGas Propane, L.P.
0 
 
 
 
 
Common Units issued in connection with employee and director plans, net of tax withheld (in units)
 
 
4,754 
 
 
Common Units issued in connection with employee and director plans, net of tax withheld
(62,000)
(62,000)
(62,000)
 
 
Ending Balance at Dec. 31, 2017
$ 786,848,000 
$ 751,798,000 
$ 736,966,000 
$ 14,832,000 
$ 35,050,000 
Ending Balance (in units) at Dec. 31, 2017
 
 
92,963,340 
 
 
Nature of Operations
Nature of Operations
Note 1 — Nature of Operations

AmeriGas Partners, L.P. (“AmeriGas Partners”) is a publicly traded limited partnership that conducts a national propane distribution business through its principal operating subsidiary AmeriGas Propane, L.P. (“AmeriGas OLP”). 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 December 31, 2017, 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 9).
Summary of Significant Accounting Policies
Summary of Significant Accounting Policies
Note 2 — Summary of Significant Accounting Policies
 
The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). They include all adjustments which we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consist only of normal recurring items unless otherwise disclosed. The September 30, 2017, condensed consolidated balance sheet data was derived from audited financial statements but does not include all disclosures required by accounting principles generally accepted in the United States of America (“GAAP”).

These financial statements should be read in conjunction with the financial statements and related notes included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2017 (“the Partnership’s 2017 Annual Report”). Weather significantly impacts demand for propane and profitability because many customers use propane for heating purposes. Due to the seasonal nature of the Partnership’s propane business, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

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.

Allocation of Net Income (Loss). Net income (loss) attributable to AmeriGas Partners, L.P. is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages after giving effect to amounts distributed to the General Partner in excess of its 1% general partner interest in AmeriGas Partners based on its incentive distribution rights (“IDRs”) under the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P., as amended (“Partnership Agreement”).

Net Income (Loss) Per Unit. Income (loss) per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income (loss) per unit for master limited partnerships (“MLPs”) when IDRs are present. The two-class method requires that income per limited partner unit be calculated as if all earnings for the period were distributed and requires a separate calculation for each quarter- and year-to-date period. In periods when our net income attributable to AmeriGas Partners exceeds our Available Cash, as defined in the Partnership Agreement, and is above certain levels, the calculation according to the two-class method results in an increased allocation of undistributed earnings to the General Partner. Generally, in periods when our Available Cash in respect of the quarter- or year-to-date periods exceeds our net income (loss) attributable to AmeriGas Partners, the calculation according to the two-class method results in an allocation of earnings to the General Partner greater than its relative ownership interest in the Partnership (or in the case of a net loss attributable to AmeriGas Partners, an allocation of such net loss to the Common Unitholders greater than their relative ownership interest in the Partnership).

The following table sets forth reconciliations of the numerators and denominators of the basic and diluted income per limited partner unit computations:
 
 
Three Months Ended
December 31,
 
 
2017
 
2016
Net income attributable to AmeriGas Partners, L.P.
 
$
104,421

 
$
91,954

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
 
(14,202
)
 
(11,352
)
Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs
 
$
90,219

 
$
80,602

 
 
 
 
 
Weighted average Common Units outstanding — basic (thousands)
 
93,016

 
92,967

Potentially dilutive Common Units (thousands)
 
64

 
52

Weighted average Common Units outstanding — diluted (thousands)
 
93,080

 
93,019



Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the three months ended December 31, 2017, 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 $0.02. There was no dilutive effect of theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the three months ended December 31, 2016.

Potentially dilutive Common Units included in the diluted limited partner units outstanding computation reflect the effects of restricted Common Unit awards granted under the General Partner’s incentive compensation plans.

Derivative Instruments. Derivative instruments are reported in the condensed consolidated balance sheets at their fair values, unless the derivative instruments qualify for the normal purchase and normal sale (“NPNS”) exception under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting. Changes in the fair values of these derivative instruments are reflected in “Cost of sales — propane” on the Condensed Consolidated Statements of Operations. Cash flows from derivative instruments are included in cash flows from operating activities.

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 8.

Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.

Reclassifications. Certain prior-period amounts have been reclassified to conform to the current-period presentation.
Accounting Changes
Accounting Standards Not Yet Adopted
Note 3 — Accounting Changes

Accounting Standards Not Yet Adopted

Derivatives and Hedging. In August 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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 interim and annual periods beginning after December 15, 2018 (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 amends existing guidance to require entities that lease assets to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. The new guidance also requires additional disclosures about the amount, timing and uncertainty of cash flows from leases. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2018 (Fiscal 2020). Early adoption is permitted. Lessees must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance but anticipates an increase in the recognition of right-of-use assets and lease liabilities.

Revenue Recognition. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). The guidance provided under ASU 2014-09, as amended, supersedes the revenue recognition requirements in 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. The new guidance is effective for the Partnership for interim and annual periods beginning after December 15, 2017 (Fiscal 2019) and allows for either full retrospective adoption or modified retrospective adoption.

The Partnership is in 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 Partnership has completed the assessment of a significant number of its contracts with customers under the new guidance to determine the effect of the adoption of the new guidance. Although the Partnership has not completed its assessment of the impact of the new guidance, the Partnership does not expect its adoption will have a material impact on its consolidated financial statements.

The Partnership currently anticipates that it will adopt the new standard using the modified retrospective transition method effective October 1, 2018. The ultimate decision with respect to the transition method that it will use will depend upon the completion of the Partnership’s analysis including confirming its preliminary conclusion that the adoption of the new guidance will not have a material impact on its consolidated financial statements.
Goodwill and Intangible Assets
Goodwill and Intangible Assets
Note 4 — Goodwill and Intangible Assets

The Partnership’s goodwill and intangible assets comprise the following:
 
 
December 31,
2017
 
September 30,
2017
 
December 31,
2016
Goodwill (not subject to amortization)
 
$
2,002,010

 
$
2,002,010

 
$
1,979,146

Intangible assets:
 
 
 
 
 
 
Customer relationships and noncompete agreements
 
$
496,905

 
$
497,385

 
$
520,480

Accumulated amortization
 
(199,416
)
 
(190,289
)
 
(201,236
)
Intangible assets, net (definite-lived)
 
297,489

 
307,096

 
319,244

Trademarks and tradenames (indefinite-lived)
 
82,944

 
82,944

 
82,944

Total intangible assets, net
 
$
380,433

 
$
390,040

 
$
402,188



Amortization expense of intangible assets was $9,607 and $9,431 for the three months ended December 31, 2017 and 2016, respectively. No amortization expense is included in cost of sales on the Condensed Consolidated Statements of Operations. The estimated aggregate amortization expense of intangible assets for the remainder of Fiscal 2018 and the next four fiscal years is as follows: remainder of Fiscal 2018 — $28,642; Fiscal 2019 — $37,024; Fiscal 2020 — $35,803; Fiscal 2021 — $33,968; Fiscal 2022 — $32,361.
Debt
Debt
Note 5 — Debt

In December 2017, AmeriGas OLP entered into the Second Amended and Restated Credit Agreement (“Second Amended Credit Agreement”) with a group of banks. The Second Amended Credit Agreement amends and restates a previous credit agreement. The Second Amended Credit Agreement provides for borrowings up to $600,000 (including a $150,000 sublimit for letters of credit) and expires in December 2022. The Second Amended 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 Second Amended Credit Agreement, plus a margin. Under the Second Amended Credit Agreement, the applicable margin on base rate borrowings ranges from 0.50% to 1.75%; the applicable margin on Eurodollar Rate borrowings ranges from 1.50% to 2.75%; and the facility fee ranges from 0.30% to 0.50%. The aforementioned margins and facility fees are dependent upon AmeriGas Partners’ ratio of debt to earnings before interest expense, income taxes, depreciation and amortization (each as defined in the Second Amended Credit Agreement).

In December 2016, the Partnership recognized a loss of $33,151 in connection with the early repayment of a portion of its 7.00% Senior Notes. This loss is reflected in “Loss on extinguishments of debt” on the Condensed Consolidated Statements of Income for the three months ended December 31, 2016.
Commitments and Contingencies
Commitments and Contingencies
Note 6 — Commitments and Contingencies

Contingencies

Saranac Lake Environmental Matter. By letter dated March 6, 2008, the New York State Department of Environmental Conservation (“DEC”) notified AmeriGas OLP that the DEC 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 DEC disclosed contamination related to a former manufactured gas plant (“MGP”). At that time, AmeriGas OLP reviewed the study and researched the history of the site, including the extent of AmeriGas OLP’s ownership. In its written response to the DEC in early 2009, AmeriGas OLP disputed DEC’s 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. The DEC did not respond to the 2009 communication. In March 2017, the DEC communicated to AmeriGas OLP that the DEC had previously issued three Records of Decision (“RODs”) related to the site and requested additional information regarding AmeriGas OLP’s purported ownership.  The selected remedies identified in the RODs total approximately $27,700. To AmeriGas OLP’s knowledge, the DEC has not yet commenced implementation of the remediation plan but remediation is currently expected to commence in 2018. AmeriGas OLP responded to the DEC’s March 2017 request for ownership information, renewing its challenge to designation as a PRP and identifying potential defenses. In October 2017, the DEC identified a third party PRP with respect to the site.  Based on our evaluation of the available information, during the third quarter of Fiscal 2017, the Partnership accrued an environmental remediation liability of $7,545 related to the site. 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, more than 35 purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers.  The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws.  The claims seek treble damages, injunctive relief, attorneys’ fees and costs on behalf of the putative classes. 

On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Division of the United States District Court for the Western District of Missouri (“District Court”).  In July 2015, the District Court dismissed all claims brought by direct customers. In June 2017, the United States Court of Appeals for the Eighth Circuit (“Eighth Circuit”) ruled en banc to reverse the dismissal by the District Court, which had previously been affirmed by a panel of the Eighth Circuit.  In September 2017, we filed a Petition for a Writ of Certiorari to the U.S. Supreme Court appealing the decision of the Eighth Circuit. The petition was denied in January 2018 and, as a result, the case was transferred back to the District Court for further proceedings.
  
In July 2015, the District Court also dismissed all claims brought by the indirect customers other than those for injunctive relief.  The indirect customers filed an amended complaint with the District Court claiming injunctive relief and state law claims under Wisconsin, Maine and Vermont law.  In September 2016, the District Court dismissed the amended complaint in its entirety.  The indirect customers appealed this decision to the Eighth Circuit; such appeal was subject to a stay pending the en banc review of the direct purchasers’ claims.  In light of the Eighth Circuit decision with respect to the direct purchaser claims, the briefing schedule in respect of the indirect purchaser appeal will now resume.  On July 21, 2016, several new indirect customer plaintiffs filed an antitrust class action lawsuit against the Partnership in the Western District of Missouri.  The new indirect customer class action lawsuit was dismissed in September 2016 and certain indirect customer plaintiffs appealed the decision, consolidating their appeal with the indirect customer appeal still pending in the Eighth Circuit. Now that the Eighth Circuit has ruled on the direct purchasers’ claims, the stay has been lifted for the indirect claims and the parties submitted briefs in October 2017 to the Eighth Circuit and are awaiting the court’s ruling.

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.
Fair Value Measurements
Fair Value Measurements
Note 7 — Fair Value Measurements

Derivative Instruments

The following table presents on a gross basis our derivative assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy, as of December 31, 2017, September 30, 2017 and December 31, 2016: 
 
 
Asset (Liability)
 
 
Level 1
 
Level 2
 
Level 3
 
Total
December 31, 2017:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
41,187

 
$
—

 
$
41,187

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(633
)
 
$
—

 
$
(633
)
September 30, 2017:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
40,714

 
$
—

 
$
40,714

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(920
)
 
$
—

 
$
(920
)
December 31, 2016:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
34,625

 
$
—

 
$
34,625

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(151
)
 
$
—

 
$
(151
)

 
The fair values of our non-exchange traded commodity derivative contracts included in Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. For commodity option contracts not traded on an exchange, we use a Black Scholes option pricing model that considers time value and volatility of the underlying commodity.

Other Financial Instruments

The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. 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 December 31, 2017, September 30, 2017 and December 31, 2016 were as follows:

 
December 31, 2017
 
September 30, 2017
 
December 31, 2016
Carrying amount
$
2,602,304

 
$
2,603,610

 
$
2,558,707

Estimated fair value
$
2,660,194

 
$
2,699,428

 
$
2,619,790



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 Hedging Activities
Derivative Instruments and Hedging Activities
Note 8 — 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. In addition, the Partnership uses over-the-counter price swap and option contracts to reduce propane price volatility associated with a portion of forecasted propane purchases. The Partnership, from time to time, enters into price swap and put option agreements to reduce the effects of short-term commodity price volatility. At December 31, 2017, September 30, 2017 and December 31, 2016, total volumes associated with propane commodity derivatives totaled 180.6 million gallons, 213.6 million gallons and 228.5 million gallons, respectively. At December 31, 2017, 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 December 31, 2017. 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 December 31, 2017, 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 condensed consolidated balance sheets if the right of offset exists. Our derivative instruments comprise over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter contracts contain contractual rights of offset through master netting arrangements and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency or other conditions.

In general, most of our over-the-counter transactions are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on the condensed consolidated balance sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements.

Fair Value of Derivative Instruments

The following table presents our derivative assets and liabilities by type, as well as the effects of offsetting, as of December 31, 2017, September 30, 2017 and December 31, 2016:

 
 
December 31,
2017
 
September 30,
2017
 
December 31,
2016
Derivative assets not designated as hedging instruments:
 
 
 
 
 
 
Commodity contracts
 
$
41,187

 
$
40,714

 
$
34,625

Total derivative assets — gross
 
41,187

 
40,714

 
34,625

Gross amounts offset in the balance sheet
 
(633
)
 
(920
)
 
(151
)
Cash collateral received
 
(8,176
)
 
(7,991
)
 
—

Total derivative assets — net
 
$
32,378

 
$
31,803

 
$
34,474

 
 
 
 
 
 
 
Derivative liabilities not designated as hedging instruments:
 
 
 
 
 
 
Commodity contracts
 
$
(633
)
 
$
(920
)
 
$
(151
)
Total derivative liabilities — gross
 
(633
)
 
(920
)
 
(151
)
Gross amounts offset in the balance sheet
 
633

 
920

 
151

Total derivative liabilities — net
 
$
—

 
$
—

 
$
—



Effect of Derivative Instruments

The following tables provide information on the effects of derivative instruments on the condensed consolidated statements of operations for the three months ended December 31, 2017 and 2016:
 
 
Gain
Recognized in Income
 
Location of Gain
Recognized in Income
Three Months Ended December 31,
 
2017
 
2016
 
Derivatives Not Designated as Hedging Instruments:
 
 
 
 
 
 
Commodity contracts
 
$
19,614

 
$
32,100

 
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.
Related Party Transactions
Related Party Transactions
Note 9 — Related Party Transactions

Pursuant to the Partnership Agreement and a management services agreement, the General Partner is entitled to reimbursement for all direct and indirect expenses incurred or payments it makes on behalf of the Partnership. These costs, which totaled $147,287 and $147,591 for the three months ended December 31, 2017 and 2016, respectively, include employee compensation and benefit expenses of employees of the General Partner and general and administrative expenses.

UGI provides certain financial and administrative services to the General Partner. UGI bills the General Partner monthly for all direct and indirect corporate expenses incurred in connection with providing these services and the General Partner is reimbursed by the Partnership for these expenses. The allocation of indirect UGI corporate expenses to the Partnership utilizes a weighted, three-component formula based on the relative percentage of the Partnership’s revenues, operating expenses and net assets employed to the total of such items for all UGI operating subsidiaries for which general and administrative services are provided. The General Partner believes that this allocation method is reasonable and equitable to the Partnership. Such corporate expenses totaled $3,713 and $3,684 for the three months ended December 31, 2017 and 2016, respectively. In addition, UGI and certain of its subsidiaries provide office space, stop loss medical coverage and automobile liability insurance to the Partnership. The costs incurred related to these items during the three months ended December 31, 2017 and 2016, were not material.

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 the market price at the time of purchase. There were no purchases of propane by AmeriGas OLP from Energy Services during the three months ended December 31, 2017 and 2016.

In addition, the AmeriGas OLP sells propane to affiliates of UGI. Sales of propane to affiliates of UGI during the three months ended December 31, 2017 and 2016 were not material.
UGI Standby Commitment to Purchase AmeriGas Partners Class B 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 AmeriGas Partners 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.
Summary of Significant Accounting Policies (Policies)
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.
Allocation of Net Income (Loss) 
Allocation of Net Income (Loss). Net income (loss) attributable to AmeriGas Partners, L.P. is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages after giving effect to amounts distributed to the General Partner in excess of its 1% general partner interest in AmeriGas Partners based on its incentive distribution rights (“IDRs”) under the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P., as amended (“Partnership Agreement”).
Net Income (Loss) Per Unit 
Net Income (Loss) Per Unit. Income (loss) per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income (loss) per unit for master limited partnerships (“MLPs”) when IDRs are present. The two-class method requires that income per limited partner unit be calculated as if all earnings for the period were distributed and requires a separate calculation for each quarter- and year-to-date period. In periods when our net income attributable to AmeriGas Partners exceeds our Available Cash, as defined in the Partnership Agreement, and is above certain levels, the calculation according to the two-class method results in an increased allocation of undistributed earnings to the General Partner. Generally, in periods when our Available Cash in respect of the quarter- or year-to-date periods exceeds our net income (loss) attributable to AmeriGas Partners, the calculation according to the two-class method results in an allocation of earnings to the General Partner greater than its relative ownership interest in the Partnership (or in the case of a net loss attributable to AmeriGas Partners, an allocation of such net loss to the Common Unitholders greater than their relative ownership interest in the Partnership).

Derivative Instruments 
Derivative Instruments. Derivative instruments are reported in the condensed consolidated balance sheets at their fair values, unless the derivative instruments qualify for the normal purchase and normal sale (“NPNS”) exception under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting. Changes in the fair values of these derivative instruments are reflected in “Cost of sales — propane” on the Condensed Consolidated Statements of Operations. Cash flows from derivative instruments are included in cash flows from operating activities.
Use of Estimates 
Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.
Reclassifications 
Reclassifications. Certain prior-period amounts have been reclassified to conform to the current-period presentation.
Accounting Standards Not Yet Updated 
Accounting Standards Not Yet Adopted

Derivatives and Hedging. In August 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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 interim and annual periods beginning after December 15, 2018 (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 amends existing guidance to require entities that lease assets to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. The new guidance also requires additional disclosures about the amount, timing and uncertainty of cash flows from leases. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2018 (Fiscal 2020). Early adoption is permitted. Lessees must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance but anticipates an increase in the recognition of right-of-use assets and lease liabilities.

Revenue Recognition. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). The guidance provided under ASU 2014-09, as amended, supersedes the revenue recognition requirements in 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. The new guidance is effective for the Partnership for interim and annual periods beginning after December 15, 2017 (Fiscal 2019) and allows for either full retrospective adoption or modified retrospective adoption.

The Partnership is in 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 Partnership has completed the assessment of a significant number of its contracts with customers under the new guidance to determine the effect of the adoption of the new guidance. Although the Partnership has not completed its assessment of the impact of the new guidance, the Partnership does not expect its adoption will have a material impact on its consolidated financial statements.

The Partnership currently anticipates that it will adopt the new standard using the modified retrospective transition method effective October 1, 2018. The ultimate decision with respect to the transition method that it will use will depend upon the completion of the Partnership’s analysis including confirming its preliminary conclusion that the adoption of the new guidance will not have a material impact on its consolidated financial statements.
Summary of Significant Accounting Policies (Tables)
Schedule of Income Per Limited Partner Unit
The following table sets forth reconciliations of the numerators and denominators of the basic and diluted income per limited partner unit computations:
 
 
Three Months Ended
December 31,
 
 
2017
 
2016
Net income attributable to AmeriGas Partners, L.P.
 
$
104,421

 
$
91,954

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
 
(14,202
)
 
(11,352
)
Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs
 
$
90,219

 
$
80,602

 
 
 
 
 
Weighted average Common Units outstanding — basic (thousands)
 
93,016

 
92,967

Potentially dilutive Common Units (thousands)
 
64

 
52

Weighted average Common Units outstanding — diluted (thousands)
 
93,080

 
93,019



Goodwill and Intangible Assets (Tables)
Components of Goodwill and Intangible Assets
The Partnership’s goodwill and intangible assets comprise the following:
 
 
December 31,
2017
 
September 30,
2017
 
December 31,
2016
Goodwill (not subject to amortization)
 
$
2,002,010

 
$
2,002,010

 
$
1,979,146

Intangible assets:
 
 
 
 
 
 
Customer relationships and noncompete agreements
 
$
496,905

 
$
497,385

 
$
520,480

Accumulated amortization
 
(199,416
)
 
(190,289
)
 
(201,236
)
Intangible assets, net (definite-lived)
 
297,489

 
307,096

 
319,244

Trademarks and tradenames (indefinite-lived)
 
82,944

 
82,944

 
82,944

Total intangible assets, net
 
$
380,433

 
$
390,040

 
$
402,188

Fair Value Measurements (Tables)
Financial Assets and Financial Liabilities at Fair Value on a Recurring Basis 
The following table presents on a gross basis our derivative assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy, as of December 31, 2017, September 30, 2017 and December 31, 2016: 
 
 
Asset (Liability)
 
 
Level 1
 
Level 2
 
Level 3
 
Total
December 31, 2017:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
41,187

 
$
—

 
$
41,187

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(633
)
 
$
—

 
$
(633
)
September 30, 2017:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
40,714

 
$
—

 
$
40,714

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(920
)
 
$
—

 
$
(920
)
December 31, 2016:
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
34,625

 
$
—

 
$
34,625

Liabilities:
 
 
 
 
 
 
 
 
Commodity contracts
 
$
—

 
$
(151
)
 
$
—

 
$
(151
)
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 December 31, 2017, September 30, 2017 and December 31, 2016 were as follows:

 
December 31, 2017
 
September 30, 2017
 
December 31, 2016
Carrying amount
$
2,602,304

 
$
2,603,610

 
$
2,558,707

Estimated fair value
$
2,660,194

 
$
2,699,428

 
$
2,619,790

Derivative Instruments and Hedging Activities (Tables)
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 December 31, 2017, September 30, 2017 and December 31, 2016:

 
 
December 31,
2017
 
September 30,
2017
 
December 31,
2016
Derivative assets not designated as hedging instruments:
 
 
 
 
 
 
Commodity contracts
 
$
41,187

 
$
40,714

 
$
34,625

Total derivative assets — gross
 
41,187

 
40,714

 
34,625

Gross amounts offset in the balance sheet
 
(633
)
 
(920
)
 
(151
)
Cash collateral received
 
(8,176
)
 
(7,991
)
 
—

Total derivative assets — net
 
$
32,378

 
$
31,803

 
$
34,474

 
 
 
 
 
 
 
Derivative liabilities not designated as hedging instruments:
 
 
 
 
 
 
Commodity contracts
 
$
(633
)
 
$
(920
)
 
$
(151
)
Total derivative liabilities — gross
 
(633
)
 
(920
)
 
(151
)
Gross amounts offset in the balance sheet
 
633

 
920

 
151

Total derivative liabilities — net
 
$
—

 
$
—

 
$
—



Components of Derivative Instruments Gain (Loss) In Statement of Operations 
The following tables provide information on the effects of derivative instruments on the condensed consolidated statements of operations for the three months ended December 31, 2017 and 2016:
 
 
Gain
Recognized in Income
 
Location of Gain
Recognized in Income
Three Months Ended December 31,
 
2017
 
2016
 
Derivatives Not Designated as Hedging Instruments:
 
 
 
 
 
 
Commodity contracts
 
$
19,614

 
$
32,100

 
Cost of sales — propane

Nature of Operations (Details)
3 Months Ended
Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
 
Number of states in which the company has market share
50 
General Partners Interest
 
Number of employees of the AmeriGas Partners and the Operating Partnership
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% 
Summary of Significant Accounting Policies - Principles of Consolidation (Details) (AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance LLC)
Dec. 31, 2017
AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance LLC
 
Investment
 
Ownership interest percentage
100.00% 
Summary of Significant Accounting Policies - Allocation of Net Income (Loss) (Details) (AmeriGas Propane Inc Partnership Interest in AmeriGas Partners)
3 Months Ended
Dec. 31, 2017
AmeriGas Propane Inc Partnership Interest in AmeriGas Partners
 
Investment
 
General partners ownership interest (as a percent)
1.00% 
Summary of Significant Accounting Policies - Schedule of Income Per Limited Partner Unit (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Accounting Policies [Abstract]
 
 
Net income attributable to AmeriGas Partners, L.P.
$ 104,421 
$ 91,954 
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
(14,202)
(11,352)
Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs
$ 90,219 
$ 80,602 
Weighted average Common Units outstanding—basic (in shares)
93,016 
92,967 
Potentially dilutive Common Units (in units)
64 
52 
Weighted average Common Units outstanding—diluted (in shares)
93,080 
93,019 
Summary of Significant Accounting Policies - Net Income (Loss) Per Unit (Details)
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Accounting Policies [Abstract]
 
 
Dilutive effect of theoretical distributions of net income on earnings (in usd per share)
$ 0.02 
$ 0 
Goodwill And Intangible Assets - Components of Goodwill and Intangible Assets (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
 
 
 
Goodwill (not subject to amortization)
$ 2,002,010 
$ 2,002,010 
$ 1,979,146 
Intangible assets:
 
 
 
Customer relationships and noncompete agreements
496,905 
497,385 
520,480 
Accumulated amortization
(199,416)
(190,289)
(201,236)
Intangible assets, net (definite-lived)
297,489 
307,096 
319,244 
Trademarks and tradenames (indefinite-lived)
82,944 
82,944 
82,944 
Total intangible assets, net
$ 380,433 
$ 390,040 
$ 402,188 
Goodwill and Intangible Assets - Narrative (Details) (USD $)
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Finite-Lived Intangible Assets
 
 
Amortization of intangible assets
$ 9,607,000 
$ 9,431,000 
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity
 
 
Remainder fiscal 2018
28,642,000 
 
Fiscal 2019
37,024,000 
 
Fiscal 2020
35,803,000 
 
Fiscal 2021
33,968,000 
 
Fiscal 2022
32,361,000 
 
Cost of Sales
 
 
Finite-Lived Intangible Assets
 
 
Amortization of intangible assets
$ 0 
$ 0 
Debt - Narrative (Details) (USD $)
3 Months Ended 1 Months Ended 3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Dec. 31, 2016
Senior Notes
7.00% Senior Notes
Dec. 31, 2017
Revolving Credit Facility
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Revolving Credit Facility
Federal Funds Rate
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Revolving Credit Facility
Minimum
Base Rate
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Revolving Credit Facility
Minimum
Eurodollar
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Revolving Credit Facility
Maximum
Base Rate
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Revolving Credit Facility
Maximum
Eurodollar
Line of Credit
Second Amended Credit Agreement
Dec. 31, 2017
Line of Credit
Minimum
Credit Agreement [Member]
Dec. 31, 2017
Line of Credit
Maximum
Credit Agreement [Member]
Dec. 31, 2017
Letter of Credit
Line of Credit
Second Amended Credit Agreement
Debt Instrument [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
Maximum borrowing capacity
 
 
 
$ 600,000,000 
 
 
 
 
 
 
 
$ 150,000,000 
Basis spread on variable rate
 
 
 
 
0.50% 
0.50% 
1.50% 
1.75% 
2.75% 
 
 
 
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage
 
 
 
 
 
 
 
 
 
0.30% 
0.50% 
 
Loss on extinguishments of debt
$ 0 
$ 33,151,000 
$ 33,151,000 
 
 
 
 
 
 
 
 
 
Stated interest rate
 
 
7.00% 
 
 
 
 
 
 
 
 
 
Commitments and Contingencies (Details) (USD $)
In Thousands, unless otherwise specified
6 Months Ended
Oct. 31, 2014
lawsuit
Oct. 31, 2014
FTC Cylinder Investigation
lb
Dec. 31, 2017
AmeriGas OLP
DEC Remediation Plan
Saranac Lake, New York
Mar. 31, 2017
AmeriGas OLP
DEC Remediation Plan
Saranac Lake, New York
Loss Contingencies
 
 
 
 
Estimated remediation plan cost
 
 
 
$ 27,700 
Liability accrued for potential remediation costs
 
 
$ 7,545 
 
Class action lawsuits (more than)
35 
 
 
 
Amount of propane in cylinders before reduction (in pounds)
 
17 
 
 
Amount of propane in cylinders after reduction (in pounds)
 
15 
 
 
Fair Value Measurements - Financial Assets and Financial Liabilities at Fair Value On a Recurring Basis (Details) (Fair Value, Measurements, Recurring, Propane Contracts, USD $)
In Thousands, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Assets:
 
 
 
Derivative Assets
$ 41,187 
$ 40,714 
$ 34,625 
Liabilities:
 
 
 
Derivative Liabilities
(633)
(920)
(151)
Level 1
 
 
 
Assets:
 
 
 
Derivative Assets
0 
0 
0 
Liabilities:
 
 
 
Derivative Liabilities
0 
0 
0 
Level 2
 
 
 
Assets:
 
 
 
Derivative Assets
41,187 
40,714 
34,625 
Liabilities:
 
 
 
Derivative Liabilities
(633)
(920)
(151)
Level 3
 
 
 
Assets:
 
 
 
Derivative Assets
0 
0 
0 
Liabilities:
 
 
 
Derivative Liabilities
$ 0 
$ 0 
$ 0 
Fair Value Measurements - Other Financial Instruments (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Carrying amount
 
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
 
Long-term debt
$ 2,602,304 
$ 2,603,610 
$ 2,558,707 
Estimated fair value
 
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
 
Long-term debt
$ 2,660,194 
$ 2,699,428 
$ 2,619,790 
Derivative Instruments and Hedging Activities - Narrative (Details)
3 Months Ended
Dec. 31, 2017
gal
Sep. 30, 2017
gal
Dec. 31, 2016
gal
Derivative Instruments and Hedging Activities Disclosure [Abstract]
 
 
 
Volume of commodity derivative (gallons)
180,600,000 
213,600,000 
228,500,000 
Maximum period of price risk cash flow hedging (in months)
24 months 
 
 
Derivative Instruments and Hedging Activities - Components of Fair Value of Derivative Assets and Liabilities (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2017
Sep. 30, 2017
Dec. 31, 2016
Derivative assets not designated as hedging instruments:
 
 
 
Total derivative assets — gross
$ 41,187 
$ 40,714 
$ 34,625 
Gross amounts offset in the balance sheet
(633)
(920)
(151)
Cash collateral received
(8,176)
(7,991)
0 
Total derivative assets — net
32,378 
31,803 
34,474 
Derivative liabilities not designated as hedging instruments:
 
 
 
Total derivative liabilities — gross
(633)
(920)
(151)
Gross amounts offset in the balance sheet
633 
920 
151 
Total derivative liabilities — net
0 
0 
0 
Not Designated as Hedging Instrument |
Propane contracts
 
 
 
Derivative assets not designated as hedging instruments:
 
 
 
Total derivative assets — gross
41,187 
40,714 
34,625 
Derivative liabilities not designated as hedging instruments:
 
 
 
Total derivative liabilities — gross
$ (633)
$ (920)
$ (151)
Derivative Instruments and Hedging Activities - Components of Derivative Instruments Gain Loss in Statement of Operations (Details) (Not Designated as Hedging Instrument, Propane contracts, Cost of sales — propane, USD $)
In Thousands, unless otherwise specified
3 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Not Designated as Hedging Instrument |
Propane contracts |
Cost of sales — propane
 
 
Derivative Instruments, Gain (Loss)
 
 
Gain (Loss) Recognized in Income
$ 19,614 
$ 32,100 
Related Party Transactions (Details) (USD $)
3 Months Ended 20 Months Ended 0 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Dec. 31, 2017
General Partner
Reimbursed Expenses or Payments
Dec. 31, 2016
General Partner
Reimbursed Expenses or Payments
Dec. 31, 2017
General Partner
UGI Corp
General and Administrative Services
Dec. 31, 2016
General Partner
UGI Corp
General and Administrative Services
Dec. 31, 2017
Affiliated Entity
Energy Services
Propane Purchases
Dec. 31, 2016
Affiliated Entity
Energy Services
Propane Purchases
Jul. 1, 2019
Forecast
Nov. 7, 2017
Capital Unit, Class B
Related Party Transaction
 
 
 
 
 
 
 
 
 
 
Related party costs and expenses
 
 
$ 147,287,000 
$ 147,591,000 
$ 3,713,000 
$ 3,684,000 
$ 0 
$ 0 
 
 
General Partner contribution to AmeriGas Propane, L.P.
$ 0 
$ 1,602,000 
 
 
 
 
 
 
$ 225,000,000 
 
Number of volume days of weighted average price of Partnership's common units
 
 
 
 
 
 
 
 
 
20 days 
Basis points on annualized yield
 
 
 
 
 
 
 
 
 
130.00% 
Period from initial issuance, holders may elect to convert units
 
 
 
 
 
 
 
 
 
5 years 
Conversion ratio
 
 
 
 
 
 
 
 
 
1 
Trading price (as a percent)
 
 
 
 
 
 
 
 
 
110.00%