Attached files
| file | filename |
|---|---|
| EX-32 - EXHIBIT 32 - AMERIGAS PARTNERS LP | apuq233117ex32.htm |
| EX-31.2 - EXHIBIT 31.2 - AMERIGAS PARTNERS LP | apuq233117ex312.htm |
| EX-31.1 - EXHIBIT 31.1 - AMERIGAS PARTNERS LP | apuq233117ex311.htm |
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
ý | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended March 31, 2017
OR
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from ________ to ________
Commission file number 1-13692
AMERIGAS PARTNERS, L.P.
(Exact name of registrant as specified in its charters)
Delaware | 23-2787918 | |
(State or Other Jurisdiction of | (I.R.S. Employer | |
Incorporation or Organization) | Identification No.) | |
460 North Gulph Road, King of Prussia, PA 19406
(Address of Principal Executive Offices) (Zip Code)
(610) 337-7000
(Registrant’s Telephone Number, Including Area Code)
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer | ý | Accelerated filer | ¨ | Non-accelerated filer | ¨ | ||
Smaller reporting company | ¨ | Emerging growth company | ¨ | ||||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No ý
At April 30, 2017, there were 92,958,063 Common Units of AmeriGas Partners, L.P. outstanding.
TABLE OF CONTENTS
Page | |
- i -
AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
PART I FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited)
(Thousands of dollars)
March 31, 2017 | September 30, 2016 | March 31, 2016 | ||||||||||
ASSETS | ||||||||||||
Current assets: | ||||||||||||
Cash and cash equivalents | $ | 94,535 | $ | 15,827 | $ | 15,740 | ||||||
Accounts receivable (less allowances for doubtful accounts of $13,777, $11,436 and $12,858, respectively) | 299,203 | 182,665 | 257,110 | |||||||||
Accounts receivable — related parties | 4,083 | 2,643 | 3,475 | |||||||||
Inventories | 104,549 | 78,823 | 94,959 | |||||||||
Derivative instruments | 5,081 | 7,994 | — | |||||||||
Prepaid expenses and other current assets | 48,433 | 56,496 | 60,444 | |||||||||
Total current assets | 555,884 | 344,448 | 431,728 | |||||||||
Property, plant and equipment (less accumulated depreciation and amortization of $1,552,790, $1,499,396 and $1,435,097, respectively) | 1,245,390 | 1,274,557 | 1,303,281 | |||||||||
Goodwill | 1,981,842 | 1,978,981 | 1,971,999 | |||||||||
Intangible assets, net | 395,010 | 411,319 | 424,062 | |||||||||
Derivative instruments | 944 | 1,166 | — | |||||||||
Other assets | 49,189 | 47,299 | 37,116 | |||||||||
Total assets | $ | 4,228,259 | $ | 4,057,770 | $ | 4,168,186 | ||||||
LIABILITIES AND PARTNERS’ CAPITAL | ||||||||||||
Current liabilities: | ||||||||||||
Current maturities of long-term debt | $ | 109,512 | $ | 8,475 | $ | 7,441 | ||||||
Short-term borrowings | — | 153,200 | 65,300 | |||||||||
Accounts payable — trade | 127,280 | 94,007 | 107,549 | |||||||||
Accounts payable — related parties | 603 | 2,759 | 381 | |||||||||
Customer deposits and advances | 66,136 | 119,319 | 74,145 | |||||||||
Derivative instruments | 16 | 381 | 16,920 | |||||||||
Other current liabilities | 188,180 | 210,314 | 186,687 | |||||||||
Total current liabilities | 491,727 | 588,455 | 458,423 | |||||||||
Long-term debt | 2,562,376 | 2,325,334 | 2,255,253 | |||||||||
Derivative instruments | 156 | 36 | 6,595 | |||||||||
Other noncurrent liabilities | 122,665 | 124,736 | 109,142 | |||||||||
Total liabilities | 3,176,924 | 3,038,561 | 2,829,413 | |||||||||
Commitments and contingencies (Note 6) | ||||||||||||
Partners’ capital: | ||||||||||||
AmeriGas Partners, L.P. partners’ capital: | ||||||||||||
Common unitholders (units issued — 92,958,063, 92,923,410 and 92,922,445, respectively) | 996,264 | 967,073 | 1,280,915 | |||||||||
General partner | 17,445 | 17,148 | 20,324 | |||||||||
Total AmeriGas Partners, L.P. partners’ capital | 1,013,709 | 984,221 | 1,301,239 | |||||||||
Noncontrolling interest | 37,626 | 34,988 | 37,534 | |||||||||
Total partners’ capital | 1,051,335 | 1,019,209 | 1,338,773 | |||||||||
Total liabilities and partners’ capital | $ | 4,228,259 | $ | 4,057,770 | $ | 4,168,186 | ||||||
See accompanying notes to condensed consolidated financial statements.
- 1 -
AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
(Thousands of dollars, except per unit amounts)
Three Months Ended March 31, | Six Months Ended March 31, | |||||||||||||||
2017 | 2016 | 2017 | 2016 | |||||||||||||
Revenues: | ||||||||||||||||
Propane | $ | 795,806 | $ | 759,278 | $ | 1,399,862 | $ | 1,333,182 | ||||||||
Other | 67,854 | 68,209 | 140,964 | 138,403 | ||||||||||||
863,660 | 827,487 | 1,540,826 | 1,471,585 | |||||||||||||
Costs and expenses: | ||||||||||||||||
Cost of sales — propane (excluding depreciation shown below) | 367,079 | 241,621 | 581,484 | 469,543 | ||||||||||||
Cost of sales — other (excluding depreciation shown below) | 17,327 | 17,161 | 37,909 | 38,028 | ||||||||||||
Operating and administrative expenses | 240,006 | 238,535 | 466,808 | 469,424 | ||||||||||||
Depreciation | 34,420 | 36,533 | 68,409 | 75,139 | ||||||||||||
Amortization | 10,592 | 10,886 | 21,214 | 21,486 | ||||||||||||
Other operating income, net | (5,628 | ) | (7,131 | ) | (2,493 | ) | (16,038 | ) | ||||||||
663,796 | 537,605 | 1,173,331 | 1,057,582 | |||||||||||||
Operating income | 199,864 | 289,882 | 367,495 | 414,003 | ||||||||||||
Loss on extinguishments of debt | (22,144 | ) | — | (55,295 | ) | — | ||||||||||
Interest expense | (39,991 | ) | (40,806 | ) | (80,019 | ) | (81,831 | ) | ||||||||
Income before income taxes | 137,729 | 249,076 | 232,181 | 332,172 | ||||||||||||
Income tax expense | (646 | ) | (290 | ) | (1,483 | ) | (1,200 | ) | ||||||||
Net income including noncontrolling interest | 137,083 | 248,786 | 230,698 | 330,972 | ||||||||||||
Deduct net income attributable to noncontrolling interest | (1,995 | ) | (2,878 | ) | (3,656 | ) | (4,091 | ) | ||||||||
Net income attributable to AmeriGas Partners, L.P. | $ | 135,088 | $ | 245,908 | $ | 227,042 | $ | 326,881 | ||||||||
General partner’s interest in net income attributable to AmeriGas Partners, L.P. | $ | 11,786 | $ | 11,107 | $ | 23,138 | $ | 20,562 | ||||||||
Limited partners’ interest in net income attributable to AmeriGas Partners, L.P. | $ | 123,302 | $ | 234,801 | $ | 203,904 | $ | 306,319 | ||||||||
Income per limited partner unit — basic and diluted: | ||||||||||||||||
Basic | $ | 1.14 | $ | 1.74 | $ | 2.04 | $ | 2.58 | ||||||||
Diluted | $ | 1.14 | $ | 1.74 | $ | 2.04 | $ | 2.58 | ||||||||
Weighted average limited partner units outstanding (thousands): | ||||||||||||||||
Basic | 93,003 | 92,954 | 92,987 | 92,939 | ||||||||||||
Diluted | 93,045 | 93,020 | 93,039 | 93,014 | ||||||||||||
See accompanying notes to condensed consolidated financial statements.
- 2 -
AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
(Thousands of dollars)
Six Months Ended March 31, | ||||||||
2017 | 2016 | |||||||
CASH FLOWS FROM OPERATING ACTIVITIES | ||||||||
Net income including noncontrolling interest | $ | 230,698 | $ | 330,972 | ||||
Adjustments to reconcile net income including noncontrolling interest to net cash provided by operating activities: | ||||||||
Depreciation and amortization | 89,623 | 96,625 | ||||||
Provision for uncollectible accounts | 7,464 | 7,207 | ||||||
Change in unrealized losses (gains) on derivative instruments | 2,887 | (33,821 | ) | |||||
Loss on extinguishments of debt | 55,295 | — | ||||||
Other, net | 6,803 | (1,078 | ) | |||||
Net change in: | ||||||||
Accounts receivable | (127,268 | ) | (67,457 | ) | ||||
Inventories | (25,620 | ) | (861 | ) | ||||
Accounts payable | 34,217 | 5,896 | ||||||
Other current assets | 3,255 | (4,201 | ) | |||||
Other current liabilities | (75,166 | ) | (59,195 | ) | ||||
Net cash provided by operating activities | 202,188 | 274,087 | ||||||
CASH FLOWS FROM INVESTING ACTIVITIES | ||||||||
Expenditures for property, plant and equipment | (53,616 | ) | (55,787 | ) | ||||
Proceeds from disposals of assets | 8,161 | 8,780 | ||||||
Acquisitions of businesses, net of cash acquired | (7,257 | ) | (25,761 | ) | ||||
Net cash used by investing activities | (52,712 | ) | (72,768 | ) | ||||
CASH FLOWS FROM FINANCING ACTIVITIES | ||||||||
Distributions | (197,587 | ) | (190,123 | ) | ||||
Noncontrolling interest activity | (1,018 | ) | (2,714 | ) | ||||
Decrease in short-term borrowings | (153,200 | ) | (2,800 | ) | ||||
Issuances of long-term debt, net of issuance costs | 1,207,658 | — | ||||||
Repayments of long-term debt, including redemption premiums | (928,114 | ) | (5,837 | ) | ||||
Proceeds associated with equity-based compensation plans, net of tax withheld | 1,478 | 1,127 | ||||||
Capital contributions from General Partner | 15 | 11 | ||||||
Net cash used by financing activities | (70,768 | ) | (200,336 | ) | ||||
Cash and cash equivalents increase | $ | 78,708 | $ | 983 | ||||
CASH AND CASH EQUIVALENTS | ||||||||
End of period | $ | 94,535 | $ | 15,740 | ||||
Beginning of period | 15,827 | 14,757 | ||||||
Increase | $ | 78,708 | $ | 983 | ||||
See accompanying notes to condensed consolidated financial statements.
- 3 -
AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL
(unaudited)
(Thousands of dollars, except unit amounts)
For the six months ended March 31, 2017: | Number of Common Units | Common unitholders | General partner | Total AmeriGas Partners, L.P. partners’ capital | Noncontrolling interest | Total partners’ capital | |||||||||||||||||
Balance September 30, 2016 | 92,923,410 | $ | 967,073 | $ | 17,148 | $ | 984,221 | $ | 34,988 | $ | 1,019,209 | ||||||||||||
Net income including noncontrolling interest | 203,904 | 23,138 | 227,042 | 3,656 | 230,698 | ||||||||||||||||||
Distributions | (174,731 | ) | (22,856 | ) | (197,587 | ) | (2,620 | ) | (200,207 | ) | |||||||||||||
Unit-based compensation expense | 774 | 774 | 774 | ||||||||||||||||||||
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 | 34,653 | (756 | ) | 15 | (741 | ) | (741 | ) | |||||||||||||||
Balance March 31, 2017 | 92,958,063 | $ | 996,264 | $ | 17,445 | $ | 1,013,709 | $ | 37,626 | $ | 1,051,335 | ||||||||||||
For the six months ended March 31, 2016: | Number of Common Units | Common unitholders | General partner | Total AmeriGas Partners, L.P. partners’ capital | Noncontrolling interest | Total partners’ capital | |||||||||||||||||
Balance September 30, 2015 | 92,889,980 | $ | 1,145,291 | $ | 18,925 | $ | 1,164,216 | $ | 36,157 | $ | 1,200,373 | ||||||||||||
Net income including noncontrolling interest | 306,319 | 20,562 | 326,881 | 4,091 | 330,972 | ||||||||||||||||||
Distributions | (170,949 | ) | (19,174 | ) | (190,123 | ) | (2,714 | ) | (192,837 | ) | |||||||||||||
Unit-based compensation expense | 827 | 827 | 827 | ||||||||||||||||||||
Common Units issued in connection with employee and director plans, net of tax withheld | 32,465 | (573 | ) | 11 | (562 | ) | (562 | ) | |||||||||||||||
Balance March 31, 2016 | 92,922,445 | $ | 1,280,915 | $ | 20,324 | $ | 1,301,239 | $ | 37,534 | $ | 1,338,773 | ||||||||||||
See accompanying notes to condensed consolidated financial statements.
- 4 -
AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 March 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 and, prior to its merger with and into the General Partner effective October 1, 2016, Petrolane Incorporated (a predecessor company of the Partnership), also owns AmeriGas Partners Common Units (“Common Units”). The remaining Common Units outstanding represents publicly held Common Units. Common Units represent limited partner interests in AmeriGas Partners. AmeriGas Partners holds a 98.99% limited partner interest in AmeriGas OLP.
AmeriGas Partners and 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).
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, 2016, 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, 2016 (“the Partnership’s 2016 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. Net income attributable to AmeriGas Partners, L.P. for partners’ capital and statement of operations presentation purposes is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages after giving effect to amounts distributed to the General Partner in excess of its 1% general partner interest in AmeriGas Partners based on its incentive distribution rights (“IDRs”) under the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P., as amended (“Partnership Agreement”).
Net Income (Loss) Per Unit. Income (loss) per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income (loss) per unit for master limited partnerships (“MLPs”) when IDRs are present. The two-class method requires that income per limited partner unit be calculated as if all earnings for the period were distributed and requires a separate calculation for each quarter and year-to-date period. In periods when our net income attributable to AmeriGas
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 March 31, | Six Months Ended March 31, | |||||||||||||||
2017 | 2016 | 2017 | 2016 | |||||||||||||
Net income attributable to AmeriGas Partners, L.P. | $ | 135,088 | $ | 245,908 | $ | 227,042 | $ | 326,881 | ||||||||
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 | (29,381 | ) | (84,240 | ) | (37,427 | ) | (86,865 | ) | ||||||||
Common Unitholders’ interest in net income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs | $ | 105,707 | $ | 161,668 | $ | 189,615 | $ | 240,016 | ||||||||
Weighted average Common Units outstanding — basic (thousands) | 93,003 | 92,954 | 92,987 | 92,939 | ||||||||||||
Potentially dilutive Common Units (thousands) | 42 | 66 | 52 | 75 | ||||||||||||
Weighted average Common Units outstanding — diluted (thousands) | 93,045 | 93,020 | 93,039 | 93,014 | ||||||||||||
Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the three months ended March 31, 2017 and 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 $0.19 and $0.79, respectively. Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the six months ended March 31, 2017 and 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 $0.15 and $0.71, respectively.
Potentially dilutive Common Units included in the diluted limited partner units outstanding computation reflect the effects of restricted Common Unit awards granted under the General Partner’s incentive compensation plans.
Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the derivative instruments qualify for the normal purchase and normal sale (“NPNS”) exception under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting. For the six months ended March 31, 2017 and 2016, none of our derivative instruments were designated as hedges under GAAP.
Changes in the fair values of commodity derivative instruments for all periods presented are reflected in “Cost of sales — propane” on the Condensed Consolidated Statements of Operations. Cash flows from derivative instruments are included in cash flows from operating activities.
For additional information on the accounting for our derivative instruments, see Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s 2016 Annual Report.
Deferred Debt Issuance Costs. During the fourth quarter of Fiscal 2016, we adopted new accounting guidance regarding the classification of deferred debt issuance costs. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issuance costs associated with line of credit facilities continue to be classified as “Other assets” on our Condensed Consolidated Balance Sheets. As a result of the retrospective application of the new accounting guidance, the Partnership has reflected $19,535 of such costs as a reduction to long-term debt, including current
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
maturities, on the accompanying March 31, 2016, Condensed Consolidated Balance Sheet. Previously, these costs were presented within “Other assets.”
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.
Correction of Prior Period Error. During the first quarter of Fiscal 2017, the Partnership determined that it had not properly recorded gains on sales of fixed assets relating to certain assets acquired in the acquisition of Heritage Propane in Fiscal 2012. The Partnership evaluated the impact of the error on prior periods and determined that the effect was not material to the financial statements for the six months ended March 31, 2017, or any prior period financial statements, and recorded the cumulative effect of the error in accounting for certain property, plant and equipment disposals as of October 1, 2016. The correction of the error decreased “Other operating income, net” by $8,847 and decreased depreciation expense by $1,162 which is reflected in the Condensed Consolidated Statements of Operations for the six months ended March 31, 2017.
Reclassifications. Certain prior period amounts have been reclassified to conform to the current-period presentation.
Note 3 — Accounting Changes
Adoption of New Accounting Standards
Consolidation. Effective October 1, 2016, the Partnership adopted Accounting Standards Update (“ASU”) No. 2015-02, “Amendments to Consolidation Analysis” and ASU No. 2016-17, “Interest Held through Related Parties That Are under Common Control.” These ASUs provide new accounting guidance regarding whether a reporting entity should consolidate certain types of legal entities including variable interest entities (“VIEs”). Among other things, the new guidance affects the consolidation analysis of reporting entities that are involved with VIEs and requires that, under ASU 2015-02, if a single decision maker and its related parties are under common control, the single decision maker consider indirect interests in the entity held through these related parties to be the equivalent of direct interests, in their entirety. ASU 2016-07 amended the guidance in ASU 2015-02 to provide that such indirect interests be considered the equivalent of direct interests, on a proportionate basis. The adoption of this new guidance did not impact our consolidated financial statements.
Accounting Standards Not Yet Adopted
Goodwill Impairment. In January 2017, the Financial Accounting Standards Board (“FASB”) issued ASU 2017-04, “Simplifying the Test for Goodwill Impairment.” Under the new accounting guidance, an entity will no longer determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if that reporting unit had been acquired in a business combination. Instead, an entity will perform its goodwill impairment tests by comparing the fair value of a reporting unit with its carrying amount. An entity will recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value but not to exceed the total amount of the goodwill of the reporting unit. The provisions of the new accounting guidance are required to be applied prospectively. The new accounting guidance is effective for the Partnership for goodwill impairment tests performed in fiscal years beginning after December 15, 2019 (Fiscal 2021). Early adoption is permitted for goodwill impairment tests performed after January 1, 2017. 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.
Cash Flow Classification. In August 2016, the FASB issued ASU No. 2016-15, “Classification of Certain Cash Receipts and Cash Payments.” This ASU provides guidance on the classification of certain cash receipts and payments in the statement of cash flows. The amendments in this ASU are effective for interim and annual periods beginning after December 15, 2017 (Fiscal 2019). Early adoption is permitted. The amendments in the ASU should generally be adopted on a retrospective basis. 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.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 and determining the period in which the new guidance will be adopted 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.” 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. The standard requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new guidance is effective for the Partnership for interim and annual periods beginning after December 15, 2017 (Fiscal 2019) and allows for either full retrospective adoption or modified retrospective adoption. The Partnership has not yet selected a transition method and is in the process of assessing the impact on its financial statements from the adoption of the new guidance.
Note 4 — Goodwill and Intangible Assets
The Partnership’s goodwill and intangible assets comprise the following:
March 31, 2017 | September 30, 2016 | March 31, 2016 | ||||||||||
Goodwill (not subject to amortization) | $ | 1,981,842 | $ | 1,978,981 | $ | 1,971,999 | ||||||
Intangible assets: | ||||||||||||
Customer relationships and noncompete agreements | $ | 522,700 | $ | 520,180 | $ | 523,783 | ||||||
Accumulated amortization | (210,634 | ) | (191,805 | ) | (182,665 | ) | ||||||
Intangible assets, net (definite-lived) | 312,066 | 328,375 | 341,118 | |||||||||
Trademarks and tradenames (indefinite-lived) | 82,944 | 82,944 | 82,944 | |||||||||
Total intangible assets, net | $ | 395,010 | $ | 411,319 | $ | 424,062 | ||||||
Amortization expense of intangible assets was $9,398 and $9,693 for the three months ended March 31, 2017 and 2016, respectively. Amortization expense of intangible assets was $18,829 and $19,101 for the six months ended March 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 2017 and the next four fiscal years is as follows: remainder of Fiscal 2017 — $18,604; Fiscal 2018 — $36,226; Fiscal 2019 — $35,029; Fiscal 2020 — $33,847; Fiscal 2021 — $32,012.
Note 5 — Debt
In December 2016, AmeriGas Partners and AmeriGas Finance Corp., a 100% wholly owned finance subsidiary of AmeriGas Partners, issued $700,000 of 5.50% Senior Notes due May 2025 (the “5.50% Senior Notes”). The 5.50% Senior Notes rank equally with AmeriGas Partners’ existing outstanding senior notes. The net proceeds from the issuance of the 5.50% Senior Notes were used in December 2016 for (1) the early repayment, pursuant to a tender offer, of a portion of AmeriGas Partners’ 7.00% Senior Notes (the “7.00% Senior Notes”) having an aggregate principal balance of $499,970 plus accrued and unpaid interest and early redemption premiums; (2) the reduction of short-term borrowings; and (3) general corporate purposes.
In February 2017, AmeriGas Partners and AmeriGas Finance Corp. issued $525,000 of 5.75% Senior Notes due May 2027 (the “5.75% Senior Notes”). The 5.75% Senior Notes rank equally with AmeriGas Partners’ existing outstanding senior notes. The net proceeds from the issuance of the 5.75% Senior Notes were used in February 2017 for (1) the early repayment, pursuant to a tender offer, of a portion of the 7.00% Senior Notes having an aggregate principal balance of $378,340 plus accrued and unpaid interest and early redemption premiums; (2) the repayment of short-term borrowings; and (3) general corporate purposes.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
In connection with these early repayments of the 7.00% Senior Notes, during the three and six months ended March 31, 2017, the Partnership recognized losses of $22,144 and $55,295, comprising $18,917 and $47,665 of early redemption premiums and the write-off of $3,227 and $7,630 of unamortized debt issuance costs, respectively. The losses are reflected in “Loss on extinguishments of debt” on the Condensed Consolidated Statements of Operations.
In March 2017, AmeriGas Partners issued a notice of early redemption for the remaining 7.00% Senior Notes not previously tendered, having an aggregate principal balance of $102,512, plus early redemption premiums and accrued and unpaid interest. These 7.00% Senior Notes, which have a redemption date of May 20, 2017, are included in “Current maturities of long-term debt” on the March 31, 2017, Condensed Consolidated Balance Sheet. The Partnership expects to recognize a loss on extinguishment of debt of approximately $5,000 during the third quarter of Fiscal 2017 associated with this redemption.
Note 6 — Commitments and Contingencies
Contingencies
Class Action Judgment. In connection with the Partnership’s 2012 acquisition of the subsidiaries of Energy Transfer Partners, L.P. (“ETP”) that operated ETP’s propane distribution business (“Heritage Propane”), the Partnership became party to a class action lawsuit that was filed against Heritage Operating, L.P. in 2005 by Alfred L. Williams, II, on behalf of himself and all others similarly situated. The class action lawsuit alleged, among other things, wrongful collection of tank rental payments from legacy customers of People’s Gas, which was acquired by Heritage Propane in 2000. In 2010, the Florida District Court certified the class and in January 2015, the Florida District Court awarded the class approximately $18,000. In April 2016, the Partnership appealed the verdict to the Florida Second District Court of Appeals (the “Second DCA”) and, in September 2016, the Second DCA affirmed the verdict without opinion. Prior to the Second DCA’s action in the case, we believed that the likelihood of the Second DCA affirming the Florida District Court’s decision was remote. As a result of the Second DCA’s actions, in September 2016, the Partnership recorded a $14,950 adjustment to its litigation accrual to reflect the full amount of the judgment plus associated interest. In October 2016, the Partnership filed a Motion for Written Opinion and for Rehearing En Banc with the Second DCA. Following denial of such motion, the Partnership satisfied such judgment.
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 and all claims other than those for injunctive relief brought by indirect customers. The direct customers filed an appeal with the United States Court of Appeals for the Eighth Circuit (“Eighth Circuit”) and, in August 2016, the Eighth Circuit affirmed the District Court’s dismissal of the direct customer’s claims against the Partnership/UGI. The direct customers filed a petition requesting an en banc review of the Eighth Circuit decision, which was granted. The rehearing occurred in April 2017. 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; this appeal has been stayed pending the en banc review of the direct purchasers’ claims. 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. 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.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 March 31, 2017, September 30, 2016 and March 31, 2016:
Asset (Liability) | ||||||||||||||||
Level 1 | Level 2 | Level 3 | Total | |||||||||||||
March 31, 2017: | ||||||||||||||||
Assets: | ||||||||||||||||
Propane contracts | $ | — | $ | 9,911 | $ | — | $ | 9,911 | ||||||||
Liabilities: | ||||||||||||||||
Propane contracts | $ | — | $ | (4,058 | ) | $ | — | $ | (4,058 | ) | ||||||
September 30, 2016: | ||||||||||||||||
Assets: | ||||||||||||||||
Propane contracts | $ | — | $ | 13,522 | $ | — | $ | 13,522 | ||||||||
Liabilities: | ||||||||||||||||
Propane contracts | $ | — | $ | (4,779 | ) | $ | — | $ | (4,779 | ) | ||||||
March 31, 2016: | ||||||||||||||||
Assets: | ||||||||||||||||
Propane contracts | $ | — | $ | 2,691 | $ | — | $ | 2,691 | ||||||||
Liabilities: | ||||||||||||||||
Propane contracts | $ | — | $ | (26,206 | ) | $ | — | $ | (26,206 | ) | ||||||
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 prices 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 March 31, 2017, September 30, 2016 and March 31, 2016 were as follows:
March 31, 2017 | September 30, 2016 | March 31, 2016 | |||||||||
Carrying amount | $ | 2,705,277 | $ | 2,360,434 | $ | 2,282,229 | |||||
Estimated fair value | $ | 2,694,848 | $ | 2,483,565 | $ | 2,329,842 | |||||
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.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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. In addition, the Partnership from time to time enters into price swap and put option agreements to reduce the effects of short-term commodity price volatility. At March 31, 2017, September 30, 2016 and March 31, 2016, total volumes associated with propane commodity derivatives totaled 199.8 million gallons, 245.4 million gallons and 267.8 million gallons, respectively. At March 31, 2017, the maximum period over which we are economically hedging propane market price risk is 30 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 we would incur if these counterparties failed to perform according to the terms of their contracts, based upon the gross fair values of the derivative instruments, was not material at March 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 March 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 (and cash collateral received and pledged) are presented net by counterparty on our Condensed Consolidated Balance Sheets if the right of offset exists. Our derivative instruments comprise over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter contracts contain contractual rights of offset through master netting arrangements and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency or other conditions.
In general, most of our over-the-counter transactions are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on our Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 March 31, 2017, September 30, 2016 and March 31, 2016:
March 31, 2017 | September 30, 2016 | March 31, 2016 | ||||||||||
Derivative assets not designated as hedging instruments: | ||||||||||||
Propane contracts | $ | 9,911 | $ | 13,522 | $ | 2,691 | ||||||
Total derivative assets — gross | 9,911 | 13,522 | 2,691 | |||||||||
Gross amounts offset in the balance sheet | (3,886 | ) | (4,362 | ) | (2,691 | ) | ||||||
Total derivative assets — net | $ | 6,025 | $ | 9,160 | $ | — | ||||||
Derivative liabilities not designated as hedging instruments: | ||||||||||||
Propane contracts | $ | (4,058 | ) | $ | (4,779 | ) | $ | (26,206 | ) | |||
Total derivative liabilities — gross | (4,058 | ) | (4,779 | ) | (26,206 | ) | ||||||
Gross amounts offset in the balance sheet | 3,886 | 4,362 | 2,691 | |||||||||
Total derivative liabilities — net | $ | (172 | ) | $ | (417 | ) | $ | (23,515 | ) | |||
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 and six months ended March 31, 2017 and 2016:
Gain (Loss) Recognized in Income | Location of Gain (Loss) Recognized in Income | |||||||||
Three Months Ended March 31, | 2017 | 2016 | ||||||||
Derivatives Not Designated as Hedging Instruments: | ||||||||||
Propane contracts | $ | (10,706 | ) | $ | 11,877 | Cost of sales — propane | ||||
Gain (Loss) Recognized in Income | Location of Gain (Loss) Recognized in Income | |||||||||
Six Months Ended March 31, | 2017 | 2016 | ||||||||
Derivatives Not Designated as Hedging Instruments: | ||||||||||
Propane contracts | $ | 21,394 | $ | (15,380 | ) | 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.
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 $149,827 and $151,487 for the three months ended March 31, 2017 and 2016, respectively, and $297,418 and $301,541 for the six months ended March 31, 2017 and 2016, respectively, include employee compensation and benefit expenses of employees of the General Partner and general and administrative expenses.
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AMERIGAS PARTNERS, L.P. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Thousands of dollars, except per unit amounts)
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 $5,697 and $6,032 for the three months ended March 31, 2017 and 2016, respectively, and $9,381 and $9,392 for the six months ended March 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 and six months ended March 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 and six months ended March 31, 2017 and 2016.
In addition, the Partnership sells propane to affiliates of UGI. Sales of propane to affiliates of UGI during the three and six months ended March 31, 2017 and 2016 were not material.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Forward-Looking Statements
Information contained in this Quarterly Report on Form 10-Q may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Such statements use forward-looking words such as “believe,” “plan,” “anticipate,” “continue,” “estimate,” “expect,” “may,” or other similar words. These statements discuss plans, strategies, events or developments that we expect or anticipate will or may occur in the future.
A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you that actual results almost always vary from assumed facts or bases, and the differences between actual results and assumed facts or bases can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind the following important factors that could affect our future results and could cause those results to differ materially from those expressed in our forward-looking statements: (1) adverse weather conditions resulting in reduced demand; (2) cost volatility and availability of propane, and the capacity to transport propane to our customers; (3) the availability of, and our ability to consummate, acquisition or combination opportunities; (4) successful integration and future performance of acquired assets or businesses and achievement of anticipated synergies; (5) changes in laws and regulations, including safety, tax, consumer protection, environmental, and accounting matters; (6) competitive pressures from the same and alternative energy sources; (7) failure to acquire new customers and retain current customers thereby reducing or limiting any increase in revenues; (8) liability for environmental claims; (9) increased customer conservation measures due to high energy prices and improvements in energy efficiency and technology resulting in reduced demand; (10) adverse labor relations; (11) customer, counterparty, supplier, or vendor defaults; (12) liability for uninsured claims and for claims in excess of insurance coverage, including those for personal injury and property damage arising from explosions, terrorism, and other catastrophic events that may result from operating hazards and risks incidental to transporting, storing and distributing propane, butane and ammonia; (13) political, regulatory and economic conditions in the United States and foreign countries; (14) capital market conditions, including reduced access to capital markets and interest rate fluctuations; (15) changes in commodity market prices resulting in significantly higher cash collateral requirements; (16) the impact of pending and future legal proceedings; (17) the availability, timing, and success of our acquisitions and investments to grow our business; and (18) the interruption, disruption, failure, malfunction, or breach of our information technology systems, including due to cyber attack.
These factors, and those factors set forth in Item 1A. Risk Factors in the Partnership’s 2016 Annual Report, are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. We undertake no obligation to update publicly any forward-looking statement whether as a result of new information or future events except as required by the federal securities laws.
ANALYSIS OF RESULTS OF OPERATIONS
The following analyses compare the Partnership’s results of operations for the three months ended March 31, 2017 (“2017 three-month period”) with the three months ended March 31, 2016 (“2016 three-month period”) and the six months ended March 31, 2017 (“2017 six-month period”) with the six months ended March 31, 2016 (“2016 six-month period”).
Our results are significantly influenced by temperatures in our service territories particularly during the heating season months of October through March. As a result, our earnings, after adjusting for the effects of gains and losses on commodity derivative instruments not associated with current period transactions as further discussed below, are significantly higher in our first and second fiscal quarters.
AmeriGas Partners does not designate its propane commodity derivative instruments as hedges under U.S. generally accepted accounting principles (“GAAP”). As a result, volatility in net income attributable to AmeriGas Partners as determined in accordance with GAAP can occur as gains and losses on commodity derivative instruments not associated with current-period transactions, principally comprising non-cash changes in unrealized gains and losses, are reflected in cost of sales.
AmeriGas Partners’ management presents the non-GAAP measures “Adjusted EBITDA,” “adjusted net income attributable to AmeriGas Partners,” “adjusted total margin,” and “adjusted operating income” (in addition to “net income attributable to AmeriGas Partners” determined in accordance with GAAP) in order to assist in the evaluation of the Partnership’s overall performance. Management believes that these non-GAAP measures provide meaningful information to investors about AmeriGas Partners’
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performance because they eliminate the impact of (1) changes in unrealized gains and losses, and certain realized gains and losses, on commodity derivative instruments not associated with current-period transactions and (2) certain other gains and losses that competitors do not necessarily have, to provide additional insight into the comparison of year-over-year profitability to that of other master limited partnerships. For additional information on these non-GAAP measures as well as the non-GAAP measure, “EBITDA,” including reconciliations of these non-GAAP measures to the most closely associated GAAP measures, see “Non-GAAP Financial Measures” below.
Executive Overview
Three Months Ended March 31, 2017
We recorded GAAP net income attributable to AmeriGas Partners for the 2017 three-month period of $135.1 million compared to GAAP net income attributable to AmeriGas Partners for the 2016 three-month period of $245.9 million. GAAP net income in the 2017 three-month period reflects the effects of (1) $28.6 million of unrealized losses on commodity derivative instruments not associated with current-period transactions and (2) a $22.1 million loss on an early extinguishment of debt. GAAP net income in the 2016 three-month period reflects the effects of $39.5 million of unrealized gains on commodity derivative instruments not associated with current-period transactions.
Adjusted net income attributable to AmeriGas Partners for the 2017 three-month period was $185.6 million compared with adjusted net income attributable to AmeriGas Partners for the 2016 three-month period of $206.9 million. The $21.3 million decrease principally reflects a $21.3 million decrease in adjusted total margin reflecting 6% lower retail volumes sold due to temperatures based upon heating degree days that were 13.3% warmer than normal and nearly 3% warmer than in the prior-year three-month period. In particular, the critical heating season months of January and February were more than 9% warmer than in the same period of the prior year and, during the 2017 three-month period, average temperatures east of the Rocky Mountains, where the Partnership has a greater proportion of temperature-sensitive volumes, were substantially warmer than during the 2016 three-month period.
Six Months Ended March 31, 2017
We recorded GAAP net income attributable to AmeriGas Partners for the 2017 six-month period of $227.0 million compared to GAAP net income attributable to AmeriGas Partners for the 2016 six-month period of $326.9 million. GAAP net income in the 2017 six-month period reflects the effects of (1) $2.9 million of unrealized losses on commodity derivative instruments not associated with current-period transactions and (2) a $55.3 million loss on early extinguishments of debt. Net income attributable to AmeriGas Propane for the 2017 six-month period was also reduced by the impact of net adjustments of $7.7 million to correct previously recorded gains on sales of fixed assets ($8.8 million) and to decrease associated depreciation expense ($1.1 million) relating to certain assets acquired in the Heritage acquisition in 2012 (see Note 2 to condensed consolidated financial statements). GAAP net income in the 2016 six-month period reflects the effects of $33.8 million of unrealized gains on commodity derivative instruments not associated with current-period transactions.
Adjusted net income attributable to AmeriGas Partners for the 2017 six-month period was $285.2 million compared with adjusted net income attributable to AmeriGas Partners for the 2016 six-month period of $293.4 million. The $8.2 million decrease includes a $5.9 million decrease in adjusted total margin and the impact of $7.7 million of net adjustments to correct previously recorded gains on sales of fixed assets and depreciation relating to certain fixed assets acquired in the Heritage acquisition in 2012 (see Note 2 to condensed consolidated financial statements). The decrease in adjusted total margin in the 2017 six-month period reflects slightly lower retail volumes sold. Average temperatures across the United States based upon heating degree days were nearly 14% warmer than normal but slightly colder than the prior year. Although average temperatures during the 2017 six-month period were slightly colder than the prior year, the critical heating season months of January and February were more than 9% warmer than during the same period of the prior year. The negative effects of the slightly lower adjusted total margin and the adjustments to correct the previously recorded gains on sales of fixed assets were partially offset by lower depreciation expense and slightly lower operating and administrative expenses.
Non-GAAP Financial Measures
The Partnership’s management uses certain non-GAAP financial measures, including adjusted total margin, EBITDA, Adjusted EBITDA, adjusted operating income, and adjusted net income attributable to AmeriGas Partners, when evaluating the Partnership’s overall performance. These financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measures.
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Management believes earnings before interest, income taxes, depreciation and amortization (“EBITDA”), as adjusted for the effects of gains and losses on commodity derivative instruments not associated with current-period transactions and other gains and losses that competitors do not necessarily have (“Adjusted EBITDA”), is a meaningful non-GAAP financial measure used by investors to (1) compare the Partnership’s operating performance with that of other companies within the propane industry and (2) assess the Partnership’s ability to meet loan covenants. The Partnership’s definition of Adjusted EBITDA may be different from those used by other companies. Management uses Adjusted EBITDA to compare year-over-year profitability of the business without regard to capital structure as well as to compare the relative performance of the Partnership to that of other master limited partnerships without regard to their financing methods, capital structure, income taxes, the effects of gains and losses on commodity derivative instruments not associated with current-period transactions or historical cost basis. In view of the omission of interest, income taxes, depreciation and amortization, gains and losses on commodity derivative instruments not associated with current-period transactions and other gains and losses that competitors do not necessarily have from Adjusted EBITDA, management also assesses the profitability of the business by comparing net income attributable to AmeriGas Partners for the relevant periods. Management also uses Adjusted EBITDA to assess the Partnership’s profitability because its parent, UGI Corporation, uses the Partnership’s Adjusted EBITDA to assess the profitability of the Partnership which is one of UGI Corporation’s reportable segments. UGI Corporation discloses the Partnership’s Adjusted EBITDA in its disclosure about reportable segments as the profitability measure for its domestic propane segment.
Our other non-GAAP financial measures comprise adjusted total margin, adjusted operating income and adjusted net income attributable to AmeriGas Partners. Management believes the presentations of these non-GAAP financial measures provide useful information to investors to more effectively evaluate the period-over-period results of operations of the Partnership. Management uses these non-GAAP financial measures because they eliminate the impact of (1) gains and losses on commodity derivative instruments not associated with current-period transactions and (2) other gains and losses that competitors do not necessarily have to provide insight into the comparison of period-over-period profitability to that of other master limited partnerships.
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The following table includes reconciliations of adjusted total margin, adjusted operating income, adjusted net income attributable to AmeriGas Partners, EBITDA and Adjusted EBITDA to the most directly comparable financial measures calculated and presented in accordance with GAAP for the periods presented:
(Dollars in millions) | Three Months Ended March 31, | Six Months Ended March 31, | ||||||||||||||
2017 | 2016 | 2017 | 2016 | |||||||||||||
Adjusted total margin: | ||||||||||||||||
Total revenues | $ | 863.7 | $ | 827.5 | $ | 1,540.8 | $ | 1,471.6 | ||||||||
Cost of sales — propane | (367.1 | ) | (241.6 | ) | (581.5 | ) | (469.5 | ) | ||||||||
Cost of sales — other (a) | (17.3 | ) | (17.2 | ) | (37.9 | ) | (38.1 | ) | ||||||||
Total margin | 479.3 | 568.7 | 921.4 | 964.0 | ||||||||||||
Add net losses (subtract net gains) on commodity derivative instruments not associated with current-period transactions | 28.6 | (39.5 | ) | 2.9 | (33.8 | ) | ||||||||||
Adjusted total margin | $ | 507.9 | $ | 529.2 | $ | 924.3 | $ | 930.2 | ||||||||
Adjusted operating income: | ||||||||||||||||
Operating income | $ | 199.9 | $ | 289.9 | $ | 367.5 | $ | 414.0 | ||||||||
Add net losses (subtract net gains) on commodity derivative instruments not associated with current-period transactions | 28.6 | (39.5 | ) | 2.9 | (33.8 | ) | ||||||||||
Adjusted operating income | $ | 228.5 | $ | 250.4 | $ | 370.4 | $ | 380.2 | ||||||||
Adjusted net income attributable to AmeriGas Partners: | ||||||||||||||||
Net income attributable to AmeriGas Partners | $ | 135.1 | $ | 245.9 | $ | 227.0 | $ | 326.9 | ||||||||
Add net losses (subtract net gains) on commodity derivative instruments not associated with current-period transactions | 28.6 | (39.5 | ) | 2.9 | (33.8 | ) | ||||||||||
Loss on extinguishments of debt | 22.1 | — | 55.3 | — | ||||||||||||
Noncontrolling interest in net (losses) gains on commodity derivative instruments not associated with current-period transactions (a) | (0.2 | ) | 0.5 | — | 0.3 | |||||||||||
Adjusted net income attributable to AmeriGas Partners | $ | 185.6 | $ | 206.9 | $ | 285.2 | $ | 293.4 | ||||||||
EBITDA and Adjusted EBITDA: | ||||||||||||||||
Net income attributable to AmeriGas Partners | $ | 135.1 | $ | 245.9 | $ | 227.0 | $ | 326.9 | ||||||||
Income tax expense (a) | 0.6 | 0.3 | 1.6 | 1.2 | ||||||||||||
Interest expense | 40.0 | 40.8 | 80.0 | 81.8 | ||||||||||||
Depreciation | 34.4 | 36.5 | 68.4 | 75.1 | ||||||||||||
Amortization | 10.6 | 10.9 | 21.2 | 21.5 | ||||||||||||
EBITDA | 220.7 | 334.4 | 398.2 | 506.5 | ||||||||||||
Add net losses (subtract net gains) on commodity derivative instruments not associated with current-period transactions | 28.6 | (39.5 | ) | 2.9 | (33.8 | ) | ||||||||||
Loss on extinguishments of debt | 22.1 | — | 55.3 | — | ||||||||||||
Noncontrolling interest in net (losses) gains on commodity derivative instruments not associated with current-period transactions (a) | (0.2 | ) | 0.5 | (0.1 | ) | 0.4 | ||||||||||
Adjusted EBITDA | $ | 271.2 | $ | 295.4 | $ | 456.3 | $ | 473.1 | ||||||||
(a) | Includes the impact of rounding. |
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RESULTS OF OPERATIONS
2017 three-month period compared with 2016 three-month period
Three Months Ended March 31, | 2017 | 2016 | Increase (Decrease) | ||||||||||||
(Dollars in millions) | |||||||||||||||
Gallons sold (millions): | |||||||||||||||
Retail | 362.7 | 385.8 | (23.1 | ) | (6.0 | )% | |||||||||
Wholesale | 15.9 | 16.4 | (0.5 | ) | (3.0 | )% | |||||||||
378.6 | 402.2 | (23.6 | ) | (5.9 | )% | ||||||||||
Revenues: | |||||||||||||||
Retail propane | $ | 781.8 | $ | 750.0 | $ | 31.8 | 4.2 | % | |||||||
Wholesale propane | 14.1 | 9.3 | 4.8 | 51.6 | % | ||||||||||
Other | 67.8 | 68.2 | (0.4 | ) | (0.6 | )% | |||||||||
$ | 863.7 | $ | 827.5 | $ | 36.2 | 4.4 | % | ||||||||
Total margin (a)(b) | $ | 479.3 | $ | 568.7 | $ | (89.4 | ) | (15.7 | )% | ||||||
Operating and administrative expenses | $ | 240.0 | $ | 238.5 | $ | 1.5 | 0.6 | % | |||||||
Operating income (b) | $ | 199.9 | $ | 289.9 | $ | (90.0 | ) | (31.0 | )% | ||||||
Net income attributable to AmeriGas Partners (b)(d) | $ | 135.1 | $ | 245.9 | $ | (110.8 | ) | (45.1 | )% | ||||||
Non-GAAP financial measures (c): | |||||||||||||||
Adjusted total margin | $ | 507.9 | $ | 529.2 | $ | (21.3 | ) | (4.0 | )% | ||||||
EBITDA (b) | $ | 220.7 | $ | 334.4 | $ | (113.7 | ) | (34.0 | )% | ||||||
Adjusted EBITDA | $ | 271.2 | $ | 295.4 | $ | (24.2 | ) | (8.2 | )% | ||||||
Adjusted operating income | $ | 228.5 | $ | 250.4 | $ | (21.9 | ) | (8.7 | )% | ||||||
Adjusted net income attributable to AmeriGas Partners | $ | 185.6 | $ | 206.9 | $ | (21.3 | ) | (10.3 | )% | ||||||
Heating degree days — % (warmer) than normal (e) | (13.3 | )% | (11.7 | )% | — | — | |||||||||
(a) | Total margin represents “total revenues” less “cost of sales — propane” and “cost of sales — other.” |
(b) | Total margin, EBITDA, operating income and net income attributable to AmeriGas Partners for the 2017 and 2016 three-month periods include the impact of net unrealized (losses) gains of $(28.6) million and $39.5 million, respectively, on commodity derivative instruments not associated with current-period transactions. |
(c) | These financial measures are non-GAAP financial measures and are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not a substitute for, the comparable GAAP measures. See section “Non-GAAP Financial Measures” above. |
(d) | The three months ended March 31, 2017 includes the impact of a $22.1 million loss on extinguishment of debt (see Note 5 to condensed consolidated financial statements). |
(e) | Deviation from average heating degree days for the 30-year period 1981-2010 based upon national weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) for 344 Geo Regions in the United States, excluding Alaska and Hawaii. |
The Partnership’s retail gallons sold during the 2017 three-month period decreased 6.0% compared with the prior-year period. The decrease in retail gallons sold reflects average temperatures based upon heating degree days that were 13.3% warmer than normal and 2.9% warmer than the prior-year period. Temperatures during the critical heating season months of January and February were more than 9% warmer than in the same period of the prior year and, during the 2017 three-month period, average temperatures east of the Rocky Mountains, where the Partnership has a greater proportion of temperature-sensitive volumes, were substantially warmer than during the 2016 three-month period.
Retail propane revenues increased $31.8 million during the 2017 three-month period reflecting the effects of higher average retail selling prices ($76.7 million) partially offset by the lower retail volumes sold ($44.9 million). Wholesale propane revenues increased $4.8 million during the 2017 three-month period reflecting the effects of higher average wholesale selling prices ($5.1 million) partially offset by lower wholesale volumes sold ($0.3 million). Average daily wholesale propane commodity prices during the 2017 three-month period at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 85% higher than such prices in the 2016 three-month period during which period prices were at recent historic lows. Other revenues in the 2017 three-month period were about equal to the prior-year period.
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Total cost of sales during the 2017 three-month period decreased $125.6 million from the prior-year period. Cost of sales in the 2017 and 2016 three-month periods includes $(28.6) million and $39.5 million of (losses) gains on commodity derivative instruments not associated with current-period transactions, respectively. Excluding the effects on cost of sales of the net gains and (losses) on derivative commodity instruments, total cost of sales increased $57.5 million principally reflecting the effects of higher Partnership average propane product costs ($74.1 million) partially offset by the effects of the lower volumes sold ($16.6 million).
Total margin (which includes $(28.6) million and $39.5 million of (losses) gains on commodity derivative instruments not associated with current-period transactions in the 2017 and 2016 three-month periods, respectively) decreased $89.4 million. Adjusted total margin decreased $21.3 million in the 2017 three-month period principally reflecting lower retail propane total margin ($20.7 million). The decrease in retail propane total margin principally reflects the lower retail volumes sold partially offset by slightly higher average retail unit margin.
EBITDA and operating income (including the effects of the previously mentioned unrealized (losses) and gains on commodity derivative instruments and, with respect to EBITDA in the 2017 three-month period, the $22.1 million loss on extinguishment of debt), decreased $113.7 million and $90.0 million, respectively. Adjusted EBITDA decreased $24.2 million in the 2017 three-month period principally reflecting the effects of the lower adjusted total margin ($21.3 million) and slightly higher operating and administrative expenses ($1.5 million). Operating and administrative expenses increased reflecting, among other things, higher vehicle expenses ($4.0 million) including higher vehicle fuel expenses, and higher general insurance and self-insured casualty and liability expenses ($2.3 million) partially offset by lower employee group insurance expenses ($4.3 million). Adjusted operating income decreased $21.9 million in the 2017 three-month period reflecting the $24.2 million decrease in Adjusted EBITDA partially offset by lower depreciation and amortization expense ($2.4 million). The $21.3 million decrease in adjusted net income attributable to AmeriGas Partners principally reflects the $21.9 million decrease in adjusted operating income and a $0.8 million decrease in interest expense. The lower interest expense principally reflects lower average interest rates on long-term debt as a result of debt refinancings that occurred during Fiscal 2016 and Fiscal 2017, and lower Credit Agreement borrowings.
2017 six-month period compared with the 2016 six-month period
Six Months Ended March 31, | 2017 | 2016 | Increase (Decrease) | ||||||||||||
(Dollars in millions) | |||||||||||||||
Gallons sold (millions): | |||||||||||||||
Retail | 668.4 | 680.9 | (12.5 | ) | (1.8 | )% | |||||||||
Wholesale | 29.5 | 31.3 | (1.8 | ) | (5.8 | )% | |||||||||
697.9 | 712.2 | (14.3 | ) | (2.0 | )% | ||||||||||
Revenues: | |||||||||||||||
Retail propane | $ | 1,375.4 | $ | 1,315.1 | $ | 60.3 | 4.6 | % | |||||||
Wholesale propane | 24.5 | 18.1 | 6.4 | 35.4 | % | ||||||||||
Other | 140.9 | 138.4 | 2.5 | 1.8 | % | ||||||||||
$ | 1,540.8 | $ | 1,471.6 | $ | 69.2 | 4.7 | % | ||||||||
Total margin (a)(b) | $ | 921.4 | $ | 964.0 | $ | (42.6 | ) | (4.4 | )% | ||||||
Operating and administrative expenses | $ | 466.8 | $ | 469.4 | $ | (2.6 | ) | (0.6 | )% | ||||||
Operating income (b)(d) | $ | 367.5 | $ | 414.0 | $ | (46.5 | ) | (11.2 | )% | ||||||
Net income attributable to AmeriGas Partners (b)(d)(e) | $ | 227.0 | $ | 326.9 | $ | (99.9 | ) | (30.6 | )% | ||||||
Non-GAAP financial measures (c): | |||||||||||||||
Adjusted total margin | $ | 924.3 | $ | 930.2 | $ | (5.9 | ) | (0.6 | )% | ||||||
EBITDA (b)(d) | $ | 398.2 | $ | 506.5 | $ | (108.3 | ) | (21.4 | )% | ||||||
Adjusted EBITDA (d) | $ | 456.3 | $ | 473.1 | $ | (16.8 | ) | (3.6 | )% | ||||||
Adjusted operating income (d) | $ | 370.4 | $ | 380.2 | $ | (9.8 | ) | (2.6 | )% | ||||||
Adjusted net income attributable to AmeriGas Partners (d) | $ | 285.2 | $ | 293.4 | $ | (8.2 | ) | (2.8 | )% | ||||||
Heating degree days — % (warmer) than normal (f) | (13.6 | )% | (15.2 | )% | — | — | |||||||||
(a) | Total margin represents “total revenues” less “cost of sales — propane” and “cost of sales — other.” |
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(b) | Total margin, EBITDA, operating income and net income attributable to AmeriGas Partners for the 2017 and 2016 six-month periods include the impact of net unrealized (losses) gains of ($2.9) million and $33.8 million, respectively, on commodity derivative instruments not associated with current-period transactions. |
(c) | These financial measures are non-GAAP financial measures and are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not a substitute for, the comparable GAAP measures. See section “Non-GAAP Financial Measures” above. |
(d) | Amounts for the six months ended March 31, 2017 reflect adjustments to correct previously recorded gains on sales of fixed assets ($8.8 million) and decrease depreciation expense ($1.1 million) relating to certain assets acquired in the Heritage acquisition in 2012, which reduced operating income, adjusted operating income, net income attributable to AmeriGas Partners and adjusted net income attributable to AmeriGas Partners by $7.7 million; and reduced EBITDA and Adjusted EBITDA by $8.8 million. See Note 2 to condensed consolidated financial statements. |
(e) | The six months ended March 31, 2017 includes the impact of a $55.3 million loss on extinguishments of debt (see Note 5 to condensed consolidated financial statements). |
(f) | Deviation from average heating degree days for the 30-year period 1981-2010 based upon national weather statistics provided by NOAA for 344 Geo Regions in the United States, excluding Alaska and Hawaii. |
The Partnership’s retail gallons sold during the 2017 six-month period decreased 1.8% compared with the prior-year period. The Average temperatures based upon heating degree days during the 2017 six-month period were 1.3% colder than the prior-year period but significantly warmer than normal. Although average temperatures during the 2017 six-month period were slightly colder than the prior year, the critical heating season months of January and February averaged more than 9% warmer than during the same period of the prior year.
Retail propane revenues increased $60.3 million during the 2017 six-month period reflecting the effects of higher average retail selling prices ($84.4 million) partially offset by the lower retail volumes sold ($24.1 million). Wholesale propane revenues increased $6.4 million during the 2017 six-month period reflecting the effects of higher average wholesale selling prices ($7.4 million) partially offset by lower wholesale volumes sold ($1.0 million). Average daily wholesale propane commodity prices during the 2017 six-month period at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 60% higher than such prices during the 2016 six-month period. Other revenues in the 2017 six-month period were slightly higher than in the prior-year period.
Total cost of sales during the 2017 six-month period increased $111.8 million from the prior-year period. Cost of sales in the 2017 and 2016 six-month periods includes $(2.9) million and $33.8 million of (losses) gains on commodity derivative instruments not associated with current-period transactions, respectively. Excluding the effects on cost of sales of the net (losses) and gains on derivative commodity instruments, total cost of sales increased $75.1 million principally reflecting the effects of higher Partnership average propane product costs ($85.2 million) reduced by the effects of the lower propane volumes sold ($9.9 million).
Total margin (which includes ($2.9) million and $33.8 million of (losses) gains on commodity derivative instruments not associated with current-period transactions in the 2017 and 2016 six-month periods, respectively) decreased $42.6 million. Adjusted total margin decreased $5.9 million in the 2017 six-month period principally reflecting lower retail propane total margin ($8.1 million) partially offset by higher non-propane total margin. The decrease in retail propane total margin principally reflects the decrease in retail volumes sold partially offset by slightly higher average retail unit margin.
EBITDA and operating income (including the effects of the previously mentioned unrealized (losses) and gains on commodity derivative instruments and, with respect to EBITDA in the 2017 six-month period, the $55.3 million loss on extinguishments of debt), decreased $108.3 million and $46.5 million, respectively. Adjusted EBITDA decreased $16.8 million in the 2017 six-month period principally reflecting the effects of the lower adjusted total margin ($5.9 million) and the impact of lower other operating income ($13.5 million) principally lower gains on assets sales including an $8.8 million adjustment recorded during the first quarter of Fiscal 2017 to correct previously recorded gains on sales of fixed assets acquired with the Heritage acquisition in 2012 (see Note 2 to condensed consolidated financial statements). Operating and administrative expenses decreased reflecting, among other things, lower employee group insurance expenses ($8.5 million) partially offset by higher general insurance and self-insured casualty and liability expenses ($4.0 million) and higher vehicle expenses ($4.0 million). Adjusted operating income decreased $9.8 million in the 2017 six-month period reflecting the $16.8 million decrease in adjusted EBITDA partially offset by a decrease in depreciation and amortization expense ($7.0 million), which includes the previously mentioned $1.1 million adjustment to depreciation relating to certain assets acquired in the Heritage acquisition in 2012. The $8.2 million decrease in adjusted net income attributable to AmeriGas Partners principally reflects the $9.8 million decrease in adjusted operating income and a $1.8 million decrease in interest expense. The lower interest expense principally reflects lower average interest rates on long-term debt as a result of debt refinancings that occurred during Fiscal 2016 and Fiscal 2017, and lower Credit Agreement borrowings.
FINANCIAL CONDITION AND LIQUIDITY
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The Partnership’s cash and cash equivalents at March 31, 2017, were $94.5 million compared to cash and cash equivalents at September 30, 2016, of $15.8 million. The Partnership’s debt outstanding at March 31, 2017, totaled $2,671.9 million (including current maturities of long-term debt of $109.5 million). There were no borrowings under AmeriGas OLP’s Amended and Restated Credit Agreement (“Credit Agreement”) at March 31, 2017. The Partnership’s debt outstanding at September 30, 2016, totaled $2,487.0 million (including current maturities of long-term debt of $8.5 million and borrowings of $153.2 million under the Credit Agreement). Total long-term debt outstanding at March 31, 2017, including current maturities, comprises $2,677.5 million of AmeriGas Partners’ Senior Notes, $15.1 million of HOLP Senior Notes and $13.5 million of other long-term debt, and is net of $34.2 million of unamortized debt issuance costs.
In December 2016, AmeriGas Partners and AmeriGas Finance Corp., a 100% wholly owned finance subsidiary of AmeriGas Partners, issued $700.0 million of 5.50% Senior Notes due May 2025 (the “5.50% Senior Notes”). The net proceeds from the issuance of the 5.50% Senior Notes were used in December 2016 for (1) the early repayment, pursuant to a tender offer, of a portion of AmeriGas Partners’ 7.00% Senior Notes (the “7.00% Senior Notes”) having an aggregate principal balance of $500.0 million plus accrued and unpaid interest and early redemption premiums; (2) reduction of short-term borrowings; and (3) general corporate purposes.
In February 2017, AmeriGas Partners and AmeriGas Finance Corp. issued $525.0 million of 5.75% Senior Notes due May 2027 (the “5.75% Senior Notes”). The net proceeds from the issuance of the 5.75% Senior Notes were used in February 2017 for (1) the early repayment, pursuant to a tender offer, of a portion of the 7.00% Senior Notes having an aggregate principal balance of $378.3 million plus accrued and unpaid interest and early redemption premiums; (2) repayment of short-term borrowings; and (3) general corporate purposes.
In March 2017, AmeriGas Partners issued a notice of early redemption for the remaining 7.00% Senior Notes not previously tendered, having an aggregate principal balance of $102.5 million, plus early redemption premiums and accrued and unpaid interest. These 7.00% Senior Notes have a redemption date of May 20, 2017. The Partnership expects to repay these 7.00% Senior Notes and redemption premiums from cash on hand and borrowings under the Credit Agreement.
At March 31, 2017, there were no borrowings outstanding under the Credit Agreement. The Credit Agreement provides for borrowings up to $525 million (including a $125 million sublimit for letters of credit) and expires in June 2019. Issued and outstanding letters of credit under the Credit Agreement, which reduce the amounts available for borrowings, totaled $67.2 million at March 31, 2017. The average daily and peak short-term borrowings outstanding under the Credit Agreement during the 2017 six-month period were $105.0 million and $292.5 million, respectively. The average daily and peak short-term borrowings outstanding under the Credit Agreement during the 2016 six-month period were $131.5 million and $249.0 million, respectively. At March 31, 2017, the Partnership’s available borrowing capacity under the Credit Agreement was $457.8 million.
The Partnership’s management believes that the Partnership has sufficient liquidity in the forms of cash and cash equivalents on hand, cash expected to be generated from operations, and short-term borrowings available under the Credit Agreement to meet its anticipated contractual and projected cash commitments.
On April 24, 2017, the General Partner’s Board of Directors approved a quarterly distribution of $0.95 per Common Unit, equal to an annual rate of $3.80. The distribution reflects a 1.1% increase from the previous quarterly rate of $0.94 per Common Unit. The new quarterly rate is effective with the distribution payable on May 18, 2017, to unitholders of record on May 10, 2017. During the six months ended March 31, 2017, the General Partner’s Board of Directors declared and the Partnership paid a quarterly distribution on all limited partner units at a rate of $0.94 per Common Unit for each of the quarters ended December 31, 2016, and September 30, 2016.
The ability of the Partnership to declare and pay the quarterly distribution on its Common Units in the future depends upon a number of factors. These factors include (1) the level of Partnership earnings; (2) the cash needs of the Partnership's operations (including cash needed for maintaining and increasing operating capacity); (3) changes in operating working capital; and (4) the Partnership’s ability to borrow under its Credit Agreement, refinance maturing debt, and increase its long-term debt. Some of these factors are affected by conditions beyond the Partnership’s control including weather, competition in markets we serve, the cost of propane and changes in capital market conditions.
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Cash Flows
Operating activities. Due to the seasonal nature of the Partnership’s business, cash flows from operating activities are generally greatest during the second and third fiscal quarters when customers pay for propane consumed during the heating season months. Conversely, operating cash flows are generally at their lowest levels during the first and fourth fiscal quarters when the Partnership’s investment in working capital, principally accounts receivable and inventories, is generally greatest. The Partnership may use its Credit Agreement to satisfy its seasonal operating cash flow needs.
Cash flow provided by operating activities was $202.2 million in the 2017 six-month period compared to $274.1 million in the 2016 six-month period. Cash flow from operating activities before changes in operating working capital was $392.8 million in the 2017 six-month period compared with $399.9 million in the prior-year period. The slightly lower cash flow from operating activities before changes in operating working capital in the current-year period reflects, in large part, the effects on cash flow of the lower net income (after adjusting net income for the noncash effects on net income of unrealized gains and losses on derivative instruments and the loss on extinguishments of debt, which is reflected in cash flow from financing activities) and the impact of lower noncash charges for depreciation and amortization. Cash used to fund changes in operating working capital was $190.6 million in the 2017 six-month period compared to $125.8 million in the 2016 six-month period. The higher cash required to fund changes in accounts receivable and inventory partially offset by the higher cash provided from changes in accounts payable reflects, in large part, the impact of higher and rising LPG costs during the current-year period and the impact on these working capital accounts of colder weather late in the 2017 six-month period.
Investing activities. Investing activity cash flow principally comprises expenditures for property, plant and equipment, cash paid for acquisitions of businesses and proceeds from disposals of assets. Cash flow used in investing activities was $52.7 million in the 2017 six-month period compared with $72.8 million in the prior-year period. The Partnership spent $53.6 million for property, plant and equipment (comprising $29.4 million of maintenance capital expenditures and $24.2 million of growth capital expenditures) in the 2017 six-month period compared with $55.8 million (comprising $26.3 million of maintenance capital expenditures and $29.5 million of growth capital expenditures) in the 2016 six-month period. Cash flow used in investing activities in the 2017 six-month period includes $7.3 million of net cash used for acquisitions compared to $25.8 million in the prior-year period.
Financing activities. Financing activity cash flow principally comprises distributions on AmeriGas Partners Common Units, issuances and repayments of long-term debt, short-term borrowings, and issuances of AmeriGas Partners Common Units. Cash used in financing activities was $70.8 million in the 2017 six-month period compared with $200.3 million in the prior-year period. In February 2017, AmeriGas Partners and AmeriGas Finance Corp. issued $525 million of 5.75% Senior Notes due May 2027. The net proceeds from the issuance of the 5.75% Senior Notes were used for (1) the early repayment, pursuant to a tender offer, of a portion of AmeriGas Partners’ 7.00% Senior Notes having an aggregate principal balance of $378.3 million plus accrued and unpaid interest and early redemption premiums, (2) the repayment of short-term borrowings and (3) general corporate purposes. In December 2016, AmeriGas Partners and AmeriGas Finance Corp. issued $700.0 million of 5.50% Senior Notes due May 2025. The net proceeds from the issuance of the 5.50% Senior Notes were used for the early repayment of a portion of AmeriGas Partners’ 7.00% Senior Notes having an aggregate principal balance of $500 million plus accrued and unpaid interest and early redemption premiums (see Note 5 to condensed consolidated financial statements). Distributions in the 2017 six-month period totaled $197.6 million compared with $190.1 million in the prior-year period principally reflecting the impact of higher quarterly per-unit distribution rates. Cash used to repay short-term borrowings under the Credit Agreement in the 2017 six-month period totaled $153.2 million compared with $2.8 million in the prior-year period.
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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our primary financial market risks include commodity prices for propane. Although we use derivative financial and commodity instruments to reduce market price risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes.
Commodity Price Risk
The risk associated with fluctuations in the prices the Partnership pays for propane is principally a result of market forces reflecting changes in supply and demand for propane and other energy commodities. The Partnership’s profitability is sensitive to changes in propane supply costs and the Partnership generally passes on increases in such costs to customers. The Partnership may not, however, always be able to pass through product cost increases fully or on a timely basis, particularly when product costs rise rapidly. In order to reduce the volatility of the Partnership’s propane market price risk, we use contracts for the forward purchase or sale of propane, propane fixed-price supply agreements, and over-the-counter derivative commodity instruments including price swap and option contracts. Over-the-counter derivative commodity instruments utilized by the Partnership to economically hedge forecasted purchases of propane are generally settled at expiration of the contract. These derivative financial instruments contain collateral provisions. The fair value of unsettled commodity price risk sensitive instruments at March 31, 2017, was a gain of $5.9 million. A hypothetical 10% adverse change in the market price of propane would result in a decrease in such fair value of approximately $12.0 million.
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 March 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 March 31, 2017, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.
ITEM 4. CONTROLS AND PROCEDURES
(a)Evaluation of Disclosure Controls and Procedures
The General Partner’s disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Partnership in reports filed or submitted under the Securities Exchange Act of 1934, as amended, is (i) recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and (ii) accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. The General Partner’s management, with the participation of the General Partner’s Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Partnership’s disclosure controls and procedures as of the end of the period covered by this Report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Partnership’s disclosure controls and procedures, as of the end of the period covered by this Report, were effective at the reasonable assurance level.
(b)Change in Internal Control over Financial Reporting
No change in the Partnership’s internal control over financial reporting occurred during the Partnership’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Partnership’s internal control over financial reporting.
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PART II OTHER INFORMATION
ITEM 1A. RISK FACTORS
In addition to the information presented in this report, you should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2016, which could materially affect our business, financial condition or future results. The risks described in our Annual Report on Form 10-K are not the only risks facing the Company. Other unknown or unpredictable factors could also have material adverse effects on future results.
ITEM 6. EXHIBITS
The exhibits filed as part of this report are as follows (exhibits incorporated by reference are set forth with the name of the registrant, the type of report and last date of the period for which it was filed, and the exhibit number in such filing):
Exhibit No. | Exhibit | Registrant | Filing | Exhibit | ||
4.1 | Third Supplemental Indenture, dated as of February 13, 2017, among AmeriGas Partners, L.P., AmeriGas Finance Corp., and U.S. Bank National Association, as trustee (including form of global note) | AmeriGas Partners, L.P. | Form 8-K (2/13/17) | 4.1 | ||
10.1 | Amendment to Contingent Residual Support Agreement dated February 6, 2017, among Energy Transfer Partners, L.P., AmeriGas Finance LLC, AmeriGas Finance Corp., AmeriGas Partners, L.P., and for certain limited purposes only, UGI Corporation. | AmeriGas Partners, L.P. | Form 8-K (2/6/17) | 10.1 | ||
31.1 | Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |||||
31.2 | Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |||||
32 | Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | |||||
101.INS | XBRL Instance | |||||
101.SCH | XBRL Taxonomy Extension Schema | |||||
101.CAL | XBRL Taxonomy Extension Calculation Linkbase | |||||
101.DEF | XBRL Taxonomy Extension Definition Linkbase | |||||
101.LAB | XBRL Taxonomy Extension Labels Linkbase | |||||
101.PRE | XBRL Taxonomy Extension Presentation Linkbase | |||||
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
AMERIGAS PARTNERS, L.P. | |||
(Registrant) | |||
By: | AmeriGas Propane, Inc. | ||
as General Partner | |||
Date: | May 5, 2017 | By: | /s/ Hugh J. Gallagher |
Hugh J. Gallagher | |||
Vice President - Finance and Chief Financial Officer | |||
Date: | May 5, 2017 | By: | /s/ Laurie A. Bergman |
Laurie A. Bergman | |||
Controller and Chief Accounting Officer | |||
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EXHIBIT INDEX
31.1 | Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
31.2 | Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
32 | Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2017, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | |
101.INS | XBRL Instance | |
101.SCH | XBRL Taxonomy Extension Schema | |
101.CAL | XBRL Taxonomy Extension Calculation Linkbase | |
101.DEF | XBRL Taxonomy Extension Definition Linkbase | |
101.LAB | XBRL Taxonomy Extension Labels Linkbase | |
101.PRE | XBRL Taxonomy Extension Presentation Linkbase | |