GLOBAL PARTNERS LP - Quarter Report: 2015 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

 

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FORM 10-Q

 

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Commission file number 001-32593

 

Global Partners LP

(Exact name of registrant as specified in its charter)

 

 

P.O. Box 9161
800 South Street
Waltham, Massachusetts 02454-9161
(Address of principal executive offices, including zip code)

 

(781) 894-8800
(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 ☒ 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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files.Yes ☒ No ☐

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 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 ☒

 

The issuer had 33,995,563 common units outstanding as of August 4, 2015.

 

 

 

 

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TABLE OF CONTENTS

 

 

 

 

 

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Item 1.Financial Statements

 

GLOBAL PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)

(Unaudited)

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

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GLOBAL PARTNERS LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per unit data)

(Unaudited)

 

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

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GLOBAL PARTNERS LP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

(Unaudited)

 

 

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

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GLOBAL PARTNERS LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

 

 

6

 

The accompanying notes are an integral part of these consolidated financial statements.

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GLOBAL PARTNERS LP

CONSOLIDATED STATEMENTS OF PARTNERS’ EQUITY

(In thousands)

(Unaudited)

 

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

 

 

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Note 1. Organization and Basis of Presentation

 

Organization

 

Global Partners LP (the “Partnership”) is a midstream logistics and marketing master limited partnership formed in March 2005 engaged in the purchasing, selling and logistics of transporting petroleum and related products, including domestic and Canadian crude oil, gasoline and gasoline blendstocks (such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, natural gas and propane.  The Partnership also receives revenue from convenience store sales and gasoline station rental income.  The Partnership owns, controls or has access to one of the largest terminal networks of refined petroleum products and renewable fuels in Massachusetts, Maine, Connecticut, Vermont, New Hampshire, Rhode Island, New York, New Jersey and Pennsylvania (collectively, the “Northeast”).  The Partnership owns transload and storage terminals in North Dakota and Oregon that extend its origin-to-destination capabilities from the mid-continent region of the United States and Canada to the East and West Coasts.  The Partnership is one of the largest distributors of gasoline, distillates, residual oil and renewable fuels to wholesalers, retailers and commercial customers in the New England states and New York.  As of June 30, 2015, the Partnership had a portfolio of 1,537 owned, leased and/or supplied gasoline stations, including 286 convenience stores, in the Northeast, Maryland and Virginia.

 

On January 7, 2015, the Partnership acquired, through one of its wholly owned subsidiaries, Global Montello Group Corp. (“GMG”), 100% of the equity interests in Warren Equities, Inc. (“Warren”) from The Warren Alpert Foundation.  On January 14, 2015, through the Partnership's wholly owned subsidiary, Global Companies LLC (“Global Companies”), the Partnership acquired the Revere terminal (the “Revere Terminal”) located in Boston Harbor in Revere, Massachusetts from Global Petroleum Corp. (“GPC”) and related entities.  On June 1, 2015, the Partnership acquired retail gasoline stations and dealer supply contracts from Capitol Petroleum Group (defined below) (“Capitol”).  See Note 2.

 

Global GP LLC, the Partnership’s general partner (the “General Partner”), manages the Partnership’s operations and activities and employs its officers and substantially all of its personnel, except for most of its gasoline station and convenience store employees and certain union personnel who are employed by GMG or Drake Petroleum Company, Inc. (“Drake Petroleum”), both of which are wholly owned subsidiaries of the Partnership.

 

The General Partner, which holds a 0.67% general partner interest in the Partnership (reduced from 0.74% following the Partnership’s public offering of common units discussed in Note 9), is owned by affiliates of the Slifka family.  As of June 30, 2015, affiliates of the General Partner, including its directors and executive officers and their affiliates, owned 8,262,582 common units, representing a 24.3% limited partner interest.

 

Ownership by affiliates of the General Partner decreased by approximately 3,477,715 common units (from 37.9% at December 31, 2014 to  24.3% at June 30, 2015) primarily as a result of the liquidation and dissolution of AE Holdings Corp.  (“AE Holdings”).  Immediately prior to such liquidation and dissolution, the directors and executive officers of the General Partner were deemed to beneficially own the entire 5,850,000 common units that were then owned by AE Holdings.  Upon the liquidation and dissolution of AE Holdings, the 5,850,000 common units were distributed to the stockholders of AE Holdings.  An aggregate 1,956,234 common units were sold by the stockholders of AE Holdings to cover their respective tax liabilities resulting from their receipt of the common units.  Approximately 2,306,960 common units of the original 5,850,000 common units are held by the directors and executive officers of the General Partner, and the remaining 1,586,806 common units are held by unaffiliated members of the Slifka family.

 

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Basis of Presentation

 

The financial results of Capitol for the one month ended June 30, 2015 are included in the accompanying statements of operations for the three and six months ended June 30, 2015.  The financial results of Warren and the Revere Terminal for the three and six months ended June 30, 2015 are included in the accompanying statements of operations for the three and six months ended June 30, 2015.  The accompanying consolidated financial statements as of June 30, 2015 and December 31, 2014 and for the three and six months ended June 30, 2015 and 2014 reflect the accounts of the Partnership.  Upon consolidation, all intercompany balances and transactions have been eliminated.

 

The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and reflect all adjustments (consisting of normal recurring adjustments) which are, in the opinion of management, necessary for a fair presentation of the financial condition and operating results for the interim periods.  The interim financial information, which has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”), should be read in conjunction with the consolidated financial statements for the year ended December 31, 2014 and notes thereto contained in the Partnership’s Annual Report on Form 10-K.  The significant accounting policies described in Note 2, “Summary of Significant Accounting Policies,” of such Annual Report on Form 10-K are the same used in preparing the accompanying consolidated financial statements.

 

The results of operations for the three and six months ended June 30, 2015 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2015.  The consolidated balance sheet at December 31, 2014 has been derived from the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014.

 

Due to the nature of the Partnership’s business and its reliance, in part, on consumer travel and spending patterns, the Partnership may experience more demand for gasoline and gasoline blendstocks during the late spring and summer months than during the fall and winter.  Travel and recreational activities are typically higher in these months in the geographic areas in which the Partnership operates, increasing the demand for gasoline and gasoline blendstocks that the Partnership distributes.  Therefore, the Partnership’s volumes in gasoline and gasoline blendstocks are typically higher in the second and third quarters of the calendar year.  As demand for some of the Partnership’s refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally greater during the winter months, heating oil and residual oil volumes are generally higher during the first and fourth quarters of the calendar year. These factors may result in fluctuations in the Partnership’s quarterly operating results.

 

Reclassification

 

Certain prior year amounts in the consolidated financial statements have been reclassified to conform to the current year presentation.

 

Noncontrolling Interest

 

These financial statements reflect the application of ASC 810, “Consolidations” (“ASC 810”) which establishes accounting and reporting standards that require: (i) the ownership interest in subsidiaries held by parties other than the parent to be clearly identified and presented in the consolidated balance sheet within shareholder’s equity, but separate from the parent’s equity; (ii) the amount of consolidated net income attributable to the parent and the noncontrolling interest to be clearly identified and presented on the face of the consolidated statement of operations and (iii) changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary to be accounted for consistently.

 

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The Partnership acquired a 60% interest in Basin Transload, LLC (“Basin Transload”) on February 1, 2013.  After evaluating ASC 810, the Partnership concluded it is appropriate to consolidate the balance sheet and statement of operations of Basin Transload based on an evaluation of the outstanding voting interests.  Amounts pertaining to the noncontrolling ownership interest held by third parties in the financial position and operating results of the Partnership are reported as a noncontrolling interest in the accompanying consolidated balance sheets and statements of operations.

 

Concentration of Risk

 

The following table presents the Partnership’s sales, logistics revenue and rental income as a percentage of the consolidated sales for the periods presented:

 

 

None of the Partnership’s customers accounted for greater than 10% of total sales for the three and six months ended June 30, 2015.   The Partnership had one customer, ExxonMobil Corporation (“ExxonMobil”) that accounted for approximately 17% and 16%, respectively, of total sales for the three and six months ended June 30, 2014, respectively. 

 

Note 2. Business Combinations

 

Acquisition of Warren Equities, Inc.

 

On January 7, 2015, the Partnership acquired, through GMG, 100% of the equity interests in Warren, one of the largest independent marketers of petroleum products in the Northeast, from The Warren Alpert Foundation.  The acquisition included 147 company-owned Xtra Mart convenience stores and related fuel operations, 53 commission agent locations and fuel supply rights for approximately 320 dealers.  The acquired properties are located in the Northeast, Maryland and Virginia.  The purchase price, inclusive of post-closing adjustments, was approximately $381.8 million, including working capital.  The acquisition was funded with borrowings under the Partnership's credit facility and with proceeds from its December 2014 public offering of 3,565,000 common units.

 

The acquisition was accounted for using the purchase method of accounting in accordance with the Financial Accounting Standards Board’s (“FASB”) guidance regarding business combinations.  The Partnership’s financial statements include the results of operations of Warren subsequent to the acquisition date.

 

The purchase price allocation is considered preliminary, and additional adjustments may be recorded during the allocation period in accordance with the FASB’s guidance regarding business combinations.  The purchase price allocation will be finalized as the Partnership receives additional information relevant to the acquisition, including a final valuation of the assets purchased, including tangible and intangible assets, and liabilities assumed.

 

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The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition (in thousands):

 

 

 

During the quarter ended June 30, 2015, the Partnership recorded certain changes to the preliminary purchase accounting, specifically related to the values assigned to property and equipment, long-term deferred taxes and certain working capital assets and liabilities.  The impact of these changes increased goodwill from $147.9 million at March 31, 2015 to $195.0 million at June 30, 2015.

 

The following represents the change in goodwill from the period ended March 31, 2015 to June 30, 2015 (in thousands):

 

 

Management is currently in the process of evaluating the purchase price accounting.  The Partnership engaged a third-party valuation firm to assist in the valuation of Warren’s property and equipment, intangible assets consisting of supply contracts and favorable leasehold interests, and unfavorable leasehold interests.  This valuation continues to be in progress and, at June 30, 2015, the estimated fair values of property and equipment of $253.1 million, intangibles assets of $36.6 million ($35.8 million of supply contracts and $0.8 million of favorable leasehold interests), and unfavorable leasehold interests of $2.5 million, which are included in other non-current liabilities, were developed by management based on their estimates, assumptions and acquisition history including preliminary reports from the third-party valuation firm.  The estimated fair values of the property and equipment, intangible assets and unfavorable leasehold interests will be supported by the valuations performed by the third-party valuation firm.

 

The fair value of $36.1 million assigned to the assumption of environmental liabilities was developed by management based on their estimates, assumptions and acquisition history, including preliminary reports from third-

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party environmental engineers (see Note 12).  The fair value of the environmental liabilities will be supported by the assessment performed by the third-party environmental engineers.

 

The long-term deferred tax liabilities of $74.2 million and short-term deferred tax assets of $2.1 million included in other current assets are primarily related to temporary differences associated with the fair value allocations of property and equipment and intangible assets, which are not deductible for tax purposes, net of acquired environmental liabilities and other deductible accrued liabilities.

 

The fair value of loan receivables purchased of $25.0 million was estimated by management based on the receivable’s payment terms,  assumptions of current interest rates and collectability and is included in other current assets and other non-current assets. The gross contractual amount for these loan receivables is $29.1 million, of which the Partnership estimates $2.4 million is not collectible. 

 

The fair values of the remaining Warren assets and liabilities noted above approximate their carrying values at January 7, 2015.  It is possible that once the Partnership receives the completed valuations on the property and equipment and intangible assets, the final purchase price accounting may be different than what is presented above.

 

The preliminary purchase price for the acquisition was allocated to assets acquired and liabilities assumed based on their estimated fair values.  The Partnership then allocated the purchase price in excess of net tangible assets acquired to identifiable intangible assets, based upon on its estimates and assumptions.  Any excess purchase price over the fair value of the net tangible and intangible assets acquired was allocated to goodwill.

 

The Partnership utilized accounting guidance related to intangible assets which lists the pertinent factors to be considered when estimating the useful life of an intangible asset.  These factors include, in part, a review of the expected use by the Partnership of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets and legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset.  The Partnership amortizes these intangible assets over their estimated useful lives which is consistent with the estimated undiscounted future cash flows of these assets.

 

As part of the purchase price allocation, identifiable intangible assets include supply contracts and favorable leasehold interests that are being amortized over seven to ten years and five years, respectively.  The weighted average life over which these acquired intangibles are being amortized is approximately ten and five years, respectively.  The supply contracts are subject to renewals, and assumptions related to the renewals have been included in the determination of the value of the supply contracts at the date of acquisition.  The Partnership determines the renewal assumptions used based on management’s assumptions of future events, including customer demand, customer attrition rates, contract renewal length and market overall conditions.  The supply contracts had a weighted average term of approximately five years prior to their next renewal.  As the purchase price accounting is preliminary, the final assumptions related to the likelihood of renewals remains in process.  Amortization expense related to the supply contracts amounted to $1.1 million and $1.9 million for the three and six months ended June 30, 2015, respectively. 

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The estimated remaining amortization expense for the supply contracts acquired in connection with the acquisition for each of the five succeeding years and thereafter is as follows (in thousands):

 

 

 

Amortization related to the favorable leasehold interests was immaterial for the three and six months ended June 30, 2015.  The estimated remaining amortization for favorable leasehold interests acquired in connection with the acquisition for each of the five succeeding years is as follows (in thousands):

 

 

The $195.0 million of goodwill was assigned to the Gasoline Distribution and Station Operations (“GDSO”) reporting unit.  The goodwill recognized is attributable primarily to expected synergies and growth opportunities for the Partnership.  For federal income tax purposes, the acquisition of Warren was deemed to be a stock purchase and, therefore, any recorded goodwill is not expected to be tax deductible.  In accordance with the stock purchase agreement between the Partnership and Warren, the Partnership is ultimately not responsible for federal income tax obligations for the interim period, June 1, 2014 to January 6, 2015 (Warren’s fiscal year end was May 31).  Any tax obligations will be funded by the selling shareholders.  Any tax refund will be remitted to the selling shareholders. 

 

In connection with the acquisition of Warren, the Partnership incurred acquisition costs totaling approximately $7.1 million, of which $1.0 million and $5.4 million were recorded for the three and six months ended June 30, 2015, respectively, and included in selling, general and administrative expenses in the accompanying consolidated statements of operations.  The remaining acquisition costs were incurred in 2014.  Additionally, in January 2015 and subsequent to the acquisition date, the Partnership recorded a restructuring charge of approximately $2.3 million, which is included in selling, general and administrative expenses in the accompanying consolidated statement of operations for the six months ended June 30, 2015.  This charge, which is principally for redundant and/or eliminated positions as a result of the acquisition, was not part of the purchase price allocation.  Approximately $0 and $0.5 million of the restructuring charge was paid during the three and six months ended June 30, 2015, respectively, and the remaining balance of $1.8 million is expected to be paid in full by December 31, 2015.

 

The acquisition of Warren complements the Partnership’s existing retail presence in the Northeast and expands its footprint into the adjacent Mid-Atlantic region.  The Warren operations have been integrated into the Partnership’s GDSO reporting segment.

 

Acquisition of Revere Terminal

 

On January 14, 2015, through the Partnership’s wholly owned subsidiary, Global Companies, the Partnership acquired the Revere Terminal located in Boston Harbor in Revere, Massachusetts from GPC, a privately held affiliate of

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the Partnership, and related entities for a purchase price of $23.7 million.  The acquisition includes contingent consideration which would be payable under specific circumstances involving a subsequent sale of the property, and the purchase price may be adjusted in connection with any value assigned to the contingent consideration as the purchase price accounting is finalized.  The Partnership financed the transaction with available capacity under its revolving credit facility.  In connection with the Revere Terminal transaction, the pre-existing terminal storage rental and throughput agreement between the Partnership and GPC has terminated.

 

The acquisition was accounted for using the purchase method of accounting in accordance with the FASB’s guidance regarding business combinations.  As the acquisition transitioned the Revere Terminal from a formerly leased facility to an owned facility, the transaction did not have a material impact on the Partnership’s consolidated financial statements.

 

The purchase price allocation is considered preliminary, and additional adjustments may be recorded during the allocation period in accordance with the FASB’s guidance regarding business combinations.  The purchase price allocation will be finalized as the Partnership receives additional information relevant to the acquisition, including a final valuation of the assets acquired, including tangible assets, and liabilities assumed, including liability for contingent consideration.

 

The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition (in thousands):

 

 

During the quarter ended June 30, 2015, the Partnership recorded certain changes to the preliminary purchase accounting, primarily related to the values assigned to property and equipment and the assumption of environmental liabilities.  The impact of these changes in the period did not change the net identifiable assets acquired. 

 

Management is currently in the process of evaluating the purchase price accounting.  The Partnership engaged a third-party valuation firm to assist in the valuation of the Revere Terminal’s property and equipment.  This valuation continues to be in progress and, during the quarter ended June 30, 2015, the Partnership received preliminary fair values of these assets which are shown in the table above.  The estimated fair value of property and equipment of $28.5 million was developed by management based on their estimates, assumptions and acquisition history including preliminary reports from the third-party valuation firm.  The estimated fair value of the property and equipment will be supported by valuations performed by the third-party valuation firm.  It is possible that once the Partnership receives the completed valuations on the property and equipment, the final purchase price accounting may be different than what is presented above. 

 

The fair value of $3.1 million assigned to the assumption of environmental liabilities was estimated by management based on their estimates, assumptions and acquisition history, including preliminary reports from third-party environmental engineers (see Note 12). 

 

The Partnership is continuing its review of the estimated fair value of the assets acquired and liabilities assumed.  Accordingly, the purchase price allocation, including any value attributable to contingent consideration, will be finalized

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as the Partnership receives additional information relevant to the acquisition and the assets acquired and liabilities assumed. 

 

The fair values of the remaining Revere Terminal liabilities noted above approximate their carrying values at January 14, 2015. 

 

Acquisition of Capitol Petroleum Group

 

On June 1, 2015, the Partnership acquired 97 primarily Mobil and Exxon branded owned or leased retail gasoline stations and seven dealer supply contracts in New York City and Prince George’s County, Maryland, along with certain related supply and franchise agreements, and third-party leases and other assets associated with the operations from Liberty Petroleum Realty, LLC, East River Petroleum Realty, LLC, Big Apple Petroleum Realty, LLC, White Oak Petroleum, LLC, Anacostia Realty, LLC, Mount Vernon Petroleum Realty, LLC and DAG Realty, LLC (collectively, “Capitol Petroleum Group”).  The purchase price was approximately $156.3 million.  The acquisition was financed with borrowings under the Partnership’s revolving credit facility.

 

The acquisition was accounted for using the purchase method of accounting in accordance with the FASB’s guidance regarding business combinations.  The Partnership’s financial statements include the results of operations of Capitol subsequent to the acquisition date.

 

The purchase price allocation is considered preliminary, and additional adjustments may be recorded during the allocation period in accordance with the FASB’s guidance regarding business combinations.  The purchase price allocation will be finalized as the Partnership receives additional information relevant to the acquisition, including a final valuation of the assets purchased, including tangible and intangible assets, and liabilities assumed.

 

The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition (in thousands):

 

 

Management is currently in the process of evaluating the purchase price accounting.  The Partnership engaged a third-party valuation firm to assist in the valuation of Capitol’s property and equipment,  intangible assets consisting of supply contracts and favorable leasehold interests, and unfavorable leasehold interests.  This valuation continues to be in process and, during the quarter ended June 30, 2015, the Partnership received preliminary fair values of these assets.  The estimated fair value of property and equipment of $149.5 million, including $59.9 million of owned property and equipment and $89.6 million of property and equipment for certain properties previously sold by Capitol within two sale-leaseback transactions that did not meet the criteria for sale accounting, and intangibles assets of $3.0 million

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($2.2 million of favorable leasehold interests and $0.8 million of supply contracts) were developed by management based on their estimates, assumptions and acquisition history including preliminary reports from the third-party valuation firm.  The estimated fair value of unfavorable leasehold interests was immaterial.  The estimated fair values of the property and equipment, intangible assets and unfavorable leasehold interests will be supported by the valuations performed by the third-party valuation firm.  It is possible that once the Partnership receives the completed valuations on the property and equipment and intangible assets, the final purchase price accounting may be different than what is presented above.

 

The estimated fair value of property and equipment of $149.5 million includes $59.9 million of owned property and equipment and $89.6 million of certain properties previously sold by Capitol within two sale-leaseback transactions that did not meet the criteria for sale accounting.  As a result of not meeting the criteria for sale accounting, the property and equipment sold and leased back by Capitol has not been derecognized and, in purchase accounting, the estimated fair value of property and equipment associated with these sites of $89.6 million has been recognized within property and equipment.  Depreciation expense associated with these sale-leaseback properties amounted to $0.3 million for the three and six months ended June 30, 2015. 

 

The financing obligation of $89.6 million recognized is attributable to the two sale-leaseback transactions discussed above that did not meet the criteria for sale accounting and, as a result, were accounted for as financing arrangements.  These lease agreements mature on varying dates through 2029,  and the fair value of $89.6 million assigned to the financing obligation was estimated by management based on the remaining payments attributable to the lease agreements over their terms and is equal to the estimated fair value of property and equipment associated with these sites.  Over the course of the lease agreements, the lease rental payments will be classified as interest expense on the financing obligation and the pay-down of the financing obligation as opposed to operating expense.  Interest expense associated with the financing obligation as for these sale-leaseback properties amounted to $0.8 million for the three and six months ended June 30, 2015.  The financing obligation balance outstanding at June 30, 2015 was $89.6 million. The Partnership is in the process of completing its review over the valuation of the financing obligation recognized. 

 

The fair value of $0.2 million assigned to the assumption of environmental liabilities was developed by management based on their estimates, assumptions and acquisition history (see Note 12). 

 

The fair values of the remaining Capitol assets and liabilities noted above approximate their carrying values at June 1, 2015.    

 

The preliminary purchase price for the acquisition was allocated to assets acquired and liabilities assumed based on their estimated fair values.  The Partnership then allocated the purchase price in excess of net tangible assets acquired to identifiable intangible assets, based upon on their estimates and assumptions.  Any excess purchase price over the fair value of the net tangible and intangible assets acquired was allocated to goodwill.

 

The Partnership utilized accounting guidance related to intangible assets which lists the pertinent factors to be considered when estimating the useful life of an intangible asset.  These factors include, in part, a review of the expected use by the Partnership of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets and legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset.  The Partnership amortizes these intangible assets over their estimated useful lives which is consistent with the estimated undiscounted future cash flows of these assets.

 

As part of the purchase price allocation, identifiable intangible assets include supply contracts and favorable leasehold interests that are being amortized over seven and two years, respectively.  The weighted average life over which these acquired intangibles are being amortized is approximately seven and two years, respectively.  The supply contracts are subject to renewals, and assumptions related to the renewals have been included in the determination of the value of the supply contracts at the date of acquisition.  The Partnership determines the renewal assumptions used based

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on management’s assumptions of future events, including customer demand, customer attrition rates, contract renewal length and market overall conditions.  The supply contracts had a weighted average term of approximately one year prior to their next renewal.  As the purchase price accounting is preliminary, the final assumptions related to the likelihood of renewals remains in process.  Amortization expense related to the supply contracts was immaterial  for the three and six months ended June 30, 2015. 

 

The estimated remaining amortization expense for the supply contracts acquired in connection with the acquisition for each of the five succeeding years and thereafter is as follows (in thousands):

 

 

Amortization of favorable leasehold interests was immaterial for the three and six months ended June 30, 2015.  The estimated remaining amortization for favorable leasehold interests acquired in connection with the acquisition for each of the five succeeding years and thereafter is as follows (in thousands):

 

 

The $94.3 million of goodwill was assigned to the GDSO reporting unit.  The goodwill recognized is attributable primarily to the expansion of the Partnership’s presence in active markets in the East Coast in which the Partnership can leverage its existing operations and dealer relationships without significant incremental expense to grow the business.  The transaction also positions the Partnership to expand through tuck-in acquisitions as well as new-to-industry sites.  The goodwill is expected to be tax deductible.  The operations of Capitol have been integrated into the Partnership’s GDSO reporting segment.

 

In connection with the acquisition of Capitol, the Partnership incurred acquisition costs of approximately $3.1 million which was recorded for the three and six months ended June 30, 2015 and included in selling, general and administrative expenses in the accompanying consolidated statements of operations.

 

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Goodwill

 

The following table presents the changes in goodwill (in thousands):

 

 

Supplemental Pro Forma Information

 

Revenues and net income not included in the Partnership’s consolidated operating results for Warren from January 1, 2015 through January 7, 2015, the acquisition date, were immaterial.  Accordingly, the supplemental pro forma information for the six months ended June 30, 2015 is consistent with the amounts reported in the accompanying statement of operations for the six months ended June 30, 2015.  As the acquisition transitioned the Revere Terminal from a formerly leased facility to an owned facility, the transaction did not have a material impact on the Partnership’s consolidated financial statements.

 

The following unaudited pro forma information for 2015 presents the consolidated results of operations of the Partnership as if the acquisition of Capitol occurred at the beginning of the periods presented, with pro forma adjustments to give effect to certain adjustments.  The following unaudited pro forma information for 2014 presents the consolidated results of operations of the Partnership as if the acquisitions of Warren and Capitol occurred at the beginning of the periods presented, with pro forma adjustments to give effect to intercompany sales and certain other adjustments (in thousands, except per unit data):

 

 

 

Pro forma information for Capitol for the three and six months ended June 30, 2014 is estimated based on annual revenues and net income.  Warren’s revenues and net income included in the Partnership’s consolidated operating results from January 7, 2015, the acquisition date, through the period ended June 30, 2015 were $0.6 billion and $4.4 million, respectively.  Capitol’s revenues and net loss included in the Partnership’s consolidated operating results from June 1, 2015, the acquisition date, through the period ended June 30, 2015 were $25.6 million and ($2.2 million), respectively.

 

 

 

 

Note 3. Net Income (Loss) Per Limited Partner Unit

 

Under the Partnership’s partnership agreement, for any quarterly period, the incentive distribution rights (“IDRs”) participate in net income only to the extent of the amount of cash distributions actually declared, thereby excluding the IDRs from participating in the Partnership’s undistributed net income or losses.  Accordingly, the Partnership’s undistributed net income is assumed to be allocated to the common unitholders, or limited partners’ interest, and to the General Partner’s general partner interest.

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Common units outstanding as reported in the accompanying consolidated financial statements at June 30, 2015 and December 31, 2014 excluded 453,219 and 390,602 common units, respectively, held on behalf of the Partnership pursuant to its repurchase program (see Note 13).  These units are not deemed outstanding for purposes of calculating net income per limited partner unit (basic and diluted).

 

The following table provides a reconciliation of net income (loss) and the assumed allocation of net income (loss) to the limited partners’ interest for purposes of computing net income per limited partner unit for the three and six months ended June 30, 2015 and 2014 (in thousands, except per unit data):

 

 

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During 2015, the board of directors of the General Partner declared the following quarterly cash distribution:

 

 

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See Note 8, “Partners’ Equity and Cash Distributions” for further information.

 

Note 4. Inventories

 

The Partnership hedges substantially all of its petroleum and ethanol inventory using a variety of instruments, primarily exchange-traded futures contracts.  These futures contracts are entered into when inventory is purchased and are either designated as fair value hedges against the inventory on a specific barrel basis for inventories qualifying for fair value hedge accounting or not designated and maintained as economic hedges against certain inventory of the Partnership on a specific barrel basis.  Changes in fair value of these futures contracts, as well as the offsetting change in fair value on the hedged inventory, is recognized in earnings as an increase or decrease in cost of sales.  All hedged inventory designated in a fair value hedge relationship is valued using the lower of cost, as determined by specific identification, or market, as determined at the product level.  All petroleum and ethanol inventory not designated in a fair value hedging relationship is carried at the lower of historical cost, on a first-in, first-out basis, or market.

 

Convenience store inventory and Renewable Identification Numbers (“RINs”) inventory are carried at the lower of historical cost, on a first-in, first-out basis, or market. 

 

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Inventories consisted of the following (in thousands):

 

 

 

In addition to its own inventory, the Partnership has exchange agreements for petroleum products with unrelated third-party suppliers, whereby it may draw inventory from these other suppliers and suppliers may draw inventory from the Partnership.  Positive exchange balances are accounted for as accounts receivable and amounted to $6.3 million and $3.9 million at June 30, 2015 and December 31, 2014, respectively.  Negative exchange balances are accounted for as accounts payable and amounted to $15.6 million and $16.5 million at June 30, 2015 and December 31, 2014, respectively.  Exchange transactions are valued using current carrying costs and have no income statement impact.

 

Note 5. Derivative Financial Instruments

 

The Partnership principally uses derivative instruments, which include regulated exchange-traded futures and options contracts (collectively, “exchange-traded derivatives”) and physical and financial forwards and over-the counter (“OTC”) swaps (collectively, “OTC derivatives”), to reduce its exposure to unfavorable changes in commodity market prices and interest rates.  The Partnership uses these exchange-traded and OTC derivatives to hedge commodity price risk associated with its inventory and undelivered forward commodity purchases and sales (“physical forward contracts”) and uses interest rate swap instruments to reduce its exposure to fluctuations in interest rates associated with the Partnership’s credit facilities.  The Partnership accounts for derivative transactions in accordance with ASC 815, “Derivatives and Hedging,” and recognizes derivatives instruments as either assets or liabilities in the consolidated balance sheet and measures those instruments at fair value.  The changes in fair value of the derivative transactions are presented currently in earnings, unless specific hedge accounting criteria are met.

 

The fair value of exchange-traded derivative transactions reflects amounts that would be received from or paid to the Partnership’s brokers upon liquidation of these contracts.  The fair value of these exchange-traded derivative transactions are presented on a net basis, offset by the cash balances on deposit with the Partnership’s brokers, presented as brokerage margin deposits in the consolidated balance sheets.  The fair value of OTC derivative transactions reflects amounts that would be received from or paid to a third party upon liquidation of these contracts under current market conditions.  The fair value of these OTC derivative transactions is presented on a gross basis as derivative assets or derivative liabilities in the consolidated balance sheets, unless a legal right of offset exists.  The presentation of the change in fair value of the Partnership’s exchange-traded derivatives and OTC derivative transactions depends on the intended use of the derivative and the resulting designation.

 

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The following table summarizes the notional values related to the Partnership’s derivative instruments outstanding at June 30, 2015:

 

 

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Derivatives Accounted for as Hedges

 

The Partnership utilizes fair value hedges and cash flow hedges to hedge commodity price risk and interest rate risk.

 

Fair Value Hedges

 

Derivatives designated as fair value hedges are used to hedge price risk in commodity inventories and principally include exchange-traded futures contracts that are entered into in the ordinary course of business.  For a derivative instrument designated as a fair value hedge, the gain or loss is recognized in earnings in the period of change together with the offsetting change in fair value on the hedged item of the risk being hedged.  Gains and losses related to fair value hedges are recognized in the consolidated statement of operations through cost of sales.  These futures contracts are settled on a daily basis by the Partnership through brokerage margin accounts.

 

The Partnership’s fair value hedges include exchange-traded futures contracts and OTC derivative contracts that are hedges against inventory with specific futures contracts matched to specific barrels.  The change in fair value of these futures contracts and the change in fair value of the underlying inventory generally provide an offset to each other in the consolidated statement of operations.

 

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The following table presents the gains and losses from the Partnership’s derivative instruments involved in fair value hedging relationships recognized in the consolidated statements of operations for the three and six months ended June 30, 2015 and 2014 (in thousands):

 

 

 

Cash Flow Hedges

 

Derivatives designated as cash flow hedges are used to hedge interest rate risk from fluctuations in interest rates and may include various interest rate derivative instruments entered into with major financial institutions.  For a derivative instrument being designated as a cash flow hedge, the effective portion of the derivative gain or loss is initially reported as a component of other comprehensive income (loss) and subsequently reclassified into the consolidated statement of operations through interest expense in the same period that the hedged exposure affects earnings.  The ineffective portion is recognized in the consolidated statement of operations immediately.

 

The Partnership’s cash flow hedges currently include interest rate swaps and an interest rate cap that are hedges of variability in forecasted interest payments due to changes in the interest rate on LIBOR-based borrowings, a summary of which includes the following designations:

 

 

 

 

In the aggregate, these hedging instruments have historically been effective in hedging the variability in interest payments due to changes in the one month LIBOR swap curve or rate with respect to $300.0 million of one month LIBOR based borrowings on the credit facility.

 

In June 2014 and as a result of the issuance of the Partnership’s $375.0 million aggregate principal amount of its 6.25% senior notes due 2022 (see Note 6), the Partnership determined that maintaining an excess of $300.0 million in principal of outstanding floating-rate debt was no longer probable.  Therefore, the Partnership elected to de-designate its interest rate cap and discontinued the related hedge accounting for this instrument.  Accordingly, at June 30, 2015, the Partnership had in place two interest rate swap agreements which are hedging $200.0 million of variable rate debt, both

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of which continue to be accounted for as cash flow hedges. The interest rate cap is not currently in a hedging relationship.  Accordingly, all changes in fair value of this instrument subsequent to the date of de-designation are recorded in the consolidated statement of operations through interest expense.

 

The following table presents the amount of gains and losses from the Partnership’s derivative instruments designated in cash flow hedging relationships recognized in the consolidated statements of operations and partners’ equity for the three and six months ended June 30, 2015 and 2014 (in thousands):

 

 

 

 

 

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The amount of gain (loss) recognized in income as ineffectiveness for derivatives designated in cash flow hedging relationships was $0 for the three and six months ended June 30, 2015 and 2014.

 

Derivatives NOT Accounted for as Hedges

 

The Partnership utilizes petroleum and ethanol commodity contracts, natural gas commodity contracts and foreign currency derivatives to hedge price and currency risk in certain commodity inventories and physical forward contracts.

 

Petroleum and Ethanol Commodity Contracts

 

The Partnership uses exchange-traded derivative contracts to hedge price risk in certain commodity inventories which do not qualify for fair value hedge accounting or are not designated by the Partnership as fair value hedges.  Additionally, the Partnership uses exchange-traded derivative contracts, and occasionally financial forward and OTC

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swap agreements, to hedge commodity exposure associated with its physical forward contracts which are not designated by the Partnership as cash flow hedges.  These physical forward contracts, to the extent they meet the definition of a derivative, are considered OTC physical forwards and are reflected as derivative assets or derivative liabilities in the consolidated balance sheet.  The related exchange-traded derivative contracts (and financial forward and OTC swaps, if applicable) are also reflected as brokerage margin deposits (and derivative assets or derivative liabilities, if applicable) in the consolidated balance sheet, thereby creating an economic hedge.  Changes in fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales.  These futures contracts are settled on a daily basis by the Partnership through brokerage margin accounts.

 

While the Partnership seeks to maintain a position that is substantially balanced within its commodity product purchase and sale activities, it may experience net unbalanced positions for short periods of time as a result of variances in daily purchases and sales and transportation and delivery schedules as well as other logistical issues inherent in the business, such as weather conditions.  In connection with managing these positions, the Partnership is aided by maintaining a constant presence in the marketplace.  The Partnership also engages in a controlled trading program for up to an aggregate of 250,000 barrels of commodity products at any one point in time.  Changes in fair value of these derivative instruments are recognized in the consolidated statement of operations through cost of sales.

 

Natural Gas Commodity Contracts

 

The Partnership uses physical forward purchase contracts to hedge price risk associated with the marketing and selling of natural gas to third-party users.  These physical forward purchase commitments for natural gas are typically executed when the Partnership enters into physical forward sale commitments of product for physical delivery.  These physical forward contracts, to the extent they meet the definition of a derivative, are reflected as derivative assets and derivative liabilities in the consolidated balance sheet.  Changes in fair value of the forward fixed price purchase and sale commitments are recognized in the consolidated statement of operations through cost of sales.

 

Foreign Currency Contracts

 

The Partnership uses forward foreign currency contracts to hedge certain foreign denominated (Canadian) commodity product purchases.  These forward foreign currency contracts are not designated by the Partnership as hedges and are reflected as prepaid expenses and other current assets or accrued expenses and other current liabilities in the consolidated balance sheets.  Changes in fair values of these forward foreign currency contracts are reflected in cost of sales.

 

The following table presents the gains and losses from the Partnership’s derivative instruments not involved in a hedging relationships recognized in the consolidated statements of operations for the three and six months ended June 30, 2015 and 2014 (in thousands):

 

 

 

Margin Deposits

 

All of Partnership’s exchange-traded derivative contracts (designated and not designated) are transacted through clearing brokers.  The Partnership deposits initial margin with the clearing brokers, along with variation margin, which is paid or received on a daily basis, based upon the changes in fair value of open futures contracts and settlement of closed

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futures contracts.  Cash balances on deposit with clearing brokers and open equity are presented on a net basis within brokerage margin deposits in the consolidated balance sheets.

 

Commodity Contracts and Other Derivative Activity

 

The Partnership’s commodity contract derivatives and other derivative activity include: (i) exchange-traded derivative contracts that are hedges against inventory and either do not qualify for hedge accounting or are not designated in a hedge accounting relationship, (ii) exchange-traded derivative contracts used to economically hedge physical forward contracts, (iii) financial forward and swap agreements used to economically hedge physical forward contracts, and (iv) the derivative instruments under the Partnership’s controlled trading program.  The Partnership does not take the normal purchase and sale exemption available under ASC 815 for its physical forward contracts.

 

The following table presents the fair value of each classification of the Partnership’s derivative instruments and its location in the consolidated balance sheets at June 30, 2015 and December 31, 2014 (in thousands):

 

 

 

 

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Credit Risk

 

The Partnership’s derivative financial instruments do not contain credit risk related to other contingent features that could cause accelerated payments when these financial instruments are in net liability positions.

 

The Partnership is exposed to credit loss in the event of nonperformance by counterparties to the Partnership’s exchange-traded and OTC derivative contracts, but the Partnership has no current reason to expect any material nonperformance by any of these counterparties.  Exchange-traded derivative contracts, the primary derivative instrument utilized by the Partnership, are traded on regulated exchanges, greatly reducing potential credit risks.  The Partnership utilizes primarily three clearing brokers, all major financial institutions, for all New York Mercantile Exchange (“NYMEX”), Chicago Mercantile Exchange (“CME”) and IntercontinentalExchange (“ICE”) derivative transactions and the right of offset exists with these financial institutions under master netting agreements.  Accordingly, the fair value of the Partnership’s exchange-traded derivative instruments is presented on a net basis in the consolidated balance sheets.  Exposure on OTC derivatives is limited to the amount of the recorded fair value as of the balance sheet dates.

 

Note 6. Debt

 

Credit Agreement

 

As of June 30, 2015, certain subsidiaries of the Partnership, as borrowers, and the Partnership and certain of its subsidiaries, as guarantors, had a  $1.775 billion senior secured credit facility (the “Credit Agreement”).  The Credit Agreement will mature on April 30, 2018.

 

As of June 30, 2015, there were two facilities under the Credit Agreement:

 

 

 

In addition, the Credit Agreement has an accordion feature whereby the Partnership may request on the same terms and conditions of its then existing credit agreement, provided no Event of Default (as defined in the Credit Agreement) then exists, an increase to the working capital revolving credit facility, the revolving credit facility, or both, by up to another $300.0 million, in the aggregate, for a total credit facility of up to $2.075 billion.  The Partnership cannot provide assurance, however, that its lending group will agree to fund any request by the Partnership for additional amounts in excess of the total available commitments of $1.775 billion.

 

In addition, the Credit Agreement includes a swing line pursuant to which Bank of America, N.A., as the swing line lender, may make swing line loans in U.S. Dollars in an aggregate amount equal to the lesser of (a) $50.0 million and (b) the Aggregate WC Commitments (as defined in the Credit Agreement).  Swing line loans will bear interest at the Base Rate (as defined in the Credit Agreement).  The swing line is a sub-portion of the working capital revolving credit facility and is not an addition to the total available commitments of $1.775 billion.

 

Pursuant to the Credit Agreement, and in connection with any agreement by and between a Loan Party and a Lender (as such terms are defined in the Credit Agreement) or affiliate thereof (an “AR Buyer”), a Loan Party may sell certain of its accounts receivables to an AR Buyer.  The Loan Parties are permitted to sell or transfer any account receivable to an AR Buyer only pursuant to the provisions provided in the Credit Agreement.  To date, the level of receivables sold has not been significant, and the Partnership has accounted for such transfers as sales pursuant to

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ASC 860, “Transfers and Servicing.”  Due to the short term nature of the receivables sold to date, no servicing obligation has been recorded because it would have been de minimis.

 

Availability under the working capital revolving credit facility is subject to a borrowing base which is redetermined from time to time based on specific advance rates on eligible current assets.  Under the Credit Agreement, borrowings under the working capital revolving credit facility cannot exceed the then current borrowing base.  Availability under the borrowing base may be affected by events beyond the Partnership’s control, such as changes in petroleum product prices, collection cycles, counterparty performance, advance rates and limits, and general economic conditions.  These and other events could require the Partnership to seek waivers or amendments of covenants or alternative sources of financing or to reduce expenditures.  The Partnership can provide no assurance that such waivers, amendments or alternative financing could be obtained or, if obtained, would be on terms acceptable to the Partnership.

 

Borrowings under the working capital revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.00% to 2.50%, (2) the cost of funds rate plus 2.00% to 2.50%, or (3) the base rate plus 1.00% to 1.50%, each depending on the Utilization Amount (as defined in the Credit Agreement).  Borrowings under the revolving credit facility bear interest at (1) the Eurocurrency rate plus 2.25% to 3.25%, (2) the cost of funds rate plus 2.25% to 3.25%, or (3) the base rate plus 1.25% to 2.25%, each depending on the Combined Total Leverage Ratio (as defined in the Credit Agreement).

   

The average interest rates for the Credit Agreement were 3.4% and 3.5% for the three months ended June 30, 2015 and 2014, respectively, and 3.4% and 3.6% for the six months ended June 30, 2015 and 2014, respectively.

 

As of June 30, 2015, the Partnership had two interest rate swaps, both of which were used to hedge the variability in interest payments under the Credit Agreement due to changes in LIBOR rates.  See Note 5 for additional information on these cash flow hedges.  Additionally, the Partnership has an interest rate cap that is hedging variable interest.  The cap is not designated for accounting purposes.

 

The Credit Agreement provides for a letter of credit fee equal to the then applicable working capital rate or then applicable revolver rate (each such rate as defined in the Credit Agreement) per annum for each letter of credit issued. In addition, the Partnership incurs a commitment fee on the unused portion of each facility under the Credit Agreement, ranging from 0.375% to 0.50% per annum.

 

The Partnership classifies a portion of its working capital revolving credit facility as a current liability and a portion as a long-term liability.  The portion classified as a long-term liability represents the amounts expected to be outstanding during the entire year based on an analysis of historical borrowings under the working capital revolving credit facility, the seasonality of borrowings, forecasted future working capital requirements and forward product curves, and because the Partnership has a multi-year, long-term commitment from its bank group.  Accordingly, at June 30, 2015, the Partnership estimates working capital revolving credit facility borrowings will equal or exceed $150.0 million over the next twelve months and, therefore, classifies $118.2 million as the current portion at June 30, 2015, representing the amount the Partnership expects to pay down over the next twelve months.  The long-term portion of the working capital revolving credit facility was $150.0 million and $100.0 million at June 30, 2015 and December 31, 2014, respectively, and the current portion was $118.2 million and $0,  at June 30, 2015 and December 31, 2014, respectively.  The increase in total borrowings under the working capital revolving credit facility of $168.2 million from December 31, 2014 was primarily due to cash used in operating assets and liabilities during the period.  Inventory increased due to higher volume stored and, accounts payable and receivables decreased as we exited the heating season.

 

As of June 30, 2015, the Partnership had total borrowings outstanding under the Credit Agreement of $536.2 million, including $268.0 million outstanding on the revolving credit facility.  In addition, the Partnership had outstanding letters of credit of $59.1 million.  Subject to borrowing base limitations, the total remaining availability for borrowings and letters of credit was $1.2 billion and $1.4 billion at June 30, 2015 and December 31, 2014, respectively.

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The Credit Agreement is secured by substantially all of the assets of the Partnership and the Partnership’s wholly owned subsidiaries and is guaranteed by the Partnership and its subsidiaries with the exception of Basin Transload.

 

The Credit Agreement imposes certain requirements on the borrowers including, for example, a prohibition against distributions if any potential default or Event of Default (as defined in the Credit Agreement) would occur as a result thereof, and certain limitations on the Partnership’s ability to grant liens, make certain loans or investments, incur additional indebtedness or guarantee other indebtedness, make any material change to the nature of the Partnership’s business or undergo a fundamental change, make any material dispositions, acquire another company, enter into a merger, consolidation, sale leaseback transaction or purchase of assets, or make capital expenditures in excess of specified levels.

 

The Credit Agreement imposes financial covenants that require the Partnership to maintain certain minimum working capital amounts, a minimum combined interest coverage ratio, a maximum senior secured leverage ratio and a maximum total leverage ratio.  The Partnership was in compliance with the foregoing covenants at June 30, 2015.  The Credit Agreement also contains a representation whereby there can be no event or circumstance, either individually or in the aggregate, that has had or could reasonably be expected to have a Material Adverse Effect (as defined in the Credit Agreement).  In addition, the Credit Agreement limits distributions by the Partnership to its unitholders to the amount of Available Cash (as defined in the Partnership’s partnership agreement).

 

6.25% Senior Notes

 

On June 19, 2014, the Partnership and GLP Finance (the “Issuers”) entered into a Purchase Agreement (the “Purchase Agreement”) with the Initial Purchasers (as defined therein) (the “Initial Purchasers”) pursuant to which the Issuers agreed to sell $375.0 million aggregate principal amount of the Issuers’ 6.25% senior notes due 2022 (the “6.25% Notes”) to the Initial Purchasers in a private placement exempt from the registration requirements under the Securities Act of 1933, as amended (the “Securities Act”).  The 6.25% Notes were resold by the Initial Purchasers to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act.

 

The Purchase Agreement contained customary representations and warranties of the parties and indemnification and contribution provisions under which the Issuers and the subsidiary guarantors, on one hand, and the Initial Purchasers, on the other, agreed to indemnify each other against certain liabilities, including liabilities under the Securities Act.  In addition, the Purchase Agreement required the execution of a registration rights agreement, described below, relating to the 6.25% Notes. Closing of the offering occurred on June 24, 2014.

 

Indenture

 

In connection with the private placement of the 6.25% Notes on June 24, 2014, the Issuers and the subsidiary guarantors and Deutsche Bank Trust Company Americas, as trustee, entered into an indenture (the “Indenture”).

 

The 6.25% Notes mature on July 15, 2022 with interest accruing at a rate of 6.25% per annum and payable semi-annually in arrears on January 15 and July 15 of each year, commencing January 15, 2015.  The 6.25% Notes are guaranteed on a joint and several senior unsecured basis by each of the Issuers and the subsidiary guarantors to the extent set forth in the Indenture.  Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 6.25% Notes may declare the 6.25% Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Partnership, any restricted subsidiary of the Partnership that is a significant subsidiary or any group of its restricted subsidiaries that, taken together, would constitute a significant subsidiary of the Partnership, will automatically cause the 6.25% Notes to become due and payable.

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The Issuers have the option to redeem up to 35% of the 6.25% Notes prior to July 15, 2017 at a redemption price (expressed as a percentage of principal amount) of 106.25% plus accrued and unpaid interest, if any.  The Issuers have the option to redeem the 6.25% Notes, in whole or in part, at any time on or after July 15, 2017, at the redemption prices of 104.688% for the twelve-month period beginning on July 15, 2017, 103.125% for the twelve-month period beginning July 15, 2018, 101.563% for the twelve-month period beginning July 15, 2019, and 100.0% beginning on July 15, 2020 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption.  In addition, before July 15, 2017, the Issuers may redeem all or any part of the 6.25% Notes at a redemption price equal to the sum of the principal amount thereof, plus a make whole premium at the redemption date, plus accrued and unpaid interest, if any, to the redemption date.  The holders of the notes may require the Issuers to repurchase the 6.25% Notes following certain asset sales or a Change of Control (as defined in the Indenture) at the prices and on the terms specified in the Indenture.

 

The Indenture contains covenants that will limit the Partnership’s ability to, among other things, incur additional indebtedness and issue preferred securities, make certain dividends and distributions, make certain investments and other restricted payments, restrict distributions by its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities.  Events of default under the Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 6.25% Notes, (ii) breach of the Partnership’s covenants under the Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of the Partnership or certain subsidiaries if the total amount of such indebtedness unpaid or accelerated exceeds $15.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $15.0 million.

 

Registration Rights Agreement

 

On June 24, 2014, the Issuers and the subsidiary guarantors entered into a registration rights agreement (the “Registration Rights Agreement”) with the Initial Purchasers in connection with the Issuers’ private placement of the 6.25% Notes.  Under the Registration Rights Agreement, the Issuers and the subsidiary guarantors agreed to file and use commercially reasonable efforts to cause to become effective a registration statement relating to an offer to exchange the 6.25% Notes for an issue of SEC-registered notes with terms identical to the 6.25% Notes (except that the exchange notes are not subject to restrictions on transfer or to any increase in annual interest rate for failure to comply with the Registration Rights Agreement) that are registered under the Securities Act so as to permit the exchange offer to be consummated by the 360th day after June 24, 2014. The exchange offer was completed on April 21, 2015, and 100% of the 6.25% Notes have been exchanged for SEC registered notes.

 

7.00% Senior Notes

 

On June 1, 2015, the Issuers entered into a 7.00% Notes Purchase Agreement (the “7.00% Notes Purchase Agreement”) with the Initial Purchasers (as defined therein) (the “7.00% Notes Initial Purchasers”) pursuant to which the Issuers agreed to sell $300.0 million aggregate principal amount of the Issuers’ 7.00% senior notes due 2023 (the “7.00% Notes”) to the 7.00% Notes Initial Purchasers in a private placement exempt from the registration requirements under the Securities Act.  The 7.00% Notes were resold by the 7.00% Notes Initial Purchasers to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act.

 

The 7.00% Notes Purchase Agreement contained customary representations and warranties of the parties and indemnification and contribution provisions under which the Issuers and the subsidiary guarantors, on one hand, and the 7.00% Notes Initial Purchasers, on the other, agreed to indemnify each other against certain liabilities, including liabilities under the Securities Act.  In addition, the 7.00% Notes Purchase Agreement required the execution of a registration rights agreement, described below, relating to the 7.00% Notes.  Closing of the offering occurred on June 4, 2015.

 

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Indenture

 

In connection with the private placement of the 7.00% Notes on June 4, 2015 the Issuers and the subsidiary guarantors and Deutsche Bank Trust Company Americas, as trustee, entered into an indenture (the “7.00% Notes Indenture”).

 

The 7.00% Notes will mature on June 15, 2023 with interest accruing at a rate of 7.00% per annum and payable semi-annually in arrears on June 15 and December 15 of each year, commencing December 15, 2015.  The 7.00% Notes are guaranteed on a joint and several senior unsecured basis by each of the Issuers and the subsidiary guarantors to the extent set forth in the 7.00% Notes Indenture.  Upon a continuing event of default, the trustee or the holders of at least 25% in principal amount of the 7.00% Notes may declare the 7.00% Notes immediately due and payable, except that an event of default resulting from entry into a bankruptcy, insolvency or reorganization with respect to the Partnership, any restricted subsidiary of the Partnership that is a significant subsidiary or any group of its restricted subsidiaries that, taken together, would constitute a significant subsidiary of the Partnership, will automatically cause the 7.00% Notes to become due and payable.

 

The Issuers will have the option to redeem up to 35% of the 7.00% Notes prior to June 15, 2018 at a redemption price (expressed as a percentage of principal amount) of 107.00% plus accrued and unpaid interest, if any.  The Issuers have the option to redeem the 7.00% Notes, in whole or in part, at any time on or after June 15, 2018, at the redemption prices of 105.250% for the twelve-month period beginning June 15, 2018, 103.500% for the twelve-month period beginning June 15, 2019, 101.750% for the twelve-month period beginning June 15, 2020, and 100.0% beginning June 15, 2021 and at any time thereafter, together with any accrued and unpaid interest to the date of redemption.  In addition, before June 15, 2018, the Issuers may redeem all or any part of the 7.00% Notes at a redemption price equal to the sum of the principal amount thereof, plus a make whole premium, plus accrued and unpaid interest, if any, to the redemption date.  The holders of the 7.00% Notes may require the Issuers to repurchase the 7.00% Notes following certain asset sales or a Change of Control (as defined in the 7.00% Notes Indenture) at the prices and on the terms specified in the 7.00% Notes Indenture.

 

The 7.00% Notes Indenture contains covenants that will limit the Partnership’s ability to, among other things, incur additional indebtedness and issue preferred securities, make certain dividends and distributions, make certain investments and other restricted payments, restrict distributions by its subsidiaries, create liens, enter into sale-leaseback transactions, sell assets or merge with other entities.  Events of default under the 7.00% Notes Indenture include (i) a default in payment of principal of, or interest or premium, if any, on, the 7.00% Notes, (ii) breach of the Partnership’s covenants under the 7.00% Notes Indenture, (iii) certain events of bankruptcy and insolvency, (iv) any payment default or acceleration of indebtedness of the Partnership or certain subsidiaries if the total amount of such indebtedness unpaid or accelerated exceeds $50.0 million and (v) failure to pay within 60 days uninsured final judgments exceeding $50.0 million.

 

Registration Rights Agreement

 

On June 4, 2015, the Issuers and the subsidiary guarantors entered into a registration rights agreement (the “7.00% Notes Registration Rights Agreement”) with the 7.00% Notes Initial Purchasers in connection with the Issuers’ private placement of the 7.00% Notes.  Under the 7.00% Notes Registration Rights Agreement, the Issuers and the subsidiary guarantors have agreed to file and use commercially reasonable efforts to cause to become effective a registration statement relating to an offer to exchange the 7.00% Notes for an issue of SEC-registered notes with terms identical to the 7.00% Notes (except that the exchange notes will not be subject to restrictions on transfer or to any increase in annual interest rate for failure to comply with the 7.00% Notes Registration Rights Agreement) that are registered under the Securities Act so as to permit the exchange offer to be consummated by the 420th day after June 4, 2015.  Under specified circumstances, the Issuers and the subsidiary guarantors have also agreed to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 7.00% Notes.  If the exchange

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offer is not completed on or before the 420th day after June 4, 2015, the annual interest rate borne by the 7.00% Notes will be increased by 1.0% per annum until the exchange offer is completed or the shelf registration statement is declared effective (or automatically becomes effective).

 

Line of Credit

 

On December 9, 2013, Basin Transload entered into a line of credit facility which allows for borrowings by Basin Transload of up to $10.0 million on a revolving basis.  The facility matures on December 9, 2015 and had an outstanding balance of $0 and $0.7 million at June 30, 2015 and December 31, 2014, respectively.  The facility is secured by substantially all of the assets of Basin Transload and is not guaranteed by the Partnership or any of its wholly owned subsidiaries.

 

Financing Obligation

 

In connection with the Capitol acquisition on June 1, 2015, the Partnership assumed a  financing obligation of $89.6 million associated with two sale-leaseback transactions by Capitol for 53 leased sites that did not meet the criteria for sale accounting.  During the term of these leases, which expire in May 2028 and September 2029, in lieu of recognizing lease expense for the lease rental payments, the Partnership will incur interest expense associated with the financing obligation.  Interest expense of approximately $0.8 million was recorded for the three and six months ended June 30, 2015 and included in interest expense in the accompanying statements of operations.  The financing obligation will amortize through expiration of the lease based upon the lease rental payments.  The $89.6 million recorded is based on preliminary purchase accounting.  This amount may change as purchase accounting for the Capitol acquisition is finalized.   

 

Deferred Financing Fees

 

The Partnership incurs bank fees related to its Credit Agreement and other financing arrangements.  These deferred financing fees are amortized over the life of the Credit Agreement or other financing arrangements.  The Partnership capitalized additional financing fees of $0.9 million for the three and six months ended June 30, 2015 associated with the issuance of the 7.00% Notes.  Amortization expense of approximately $1.4 million and $1.3 million for the three months ended June 30, 2015 and 2014, respectively, and $2.9 million and $2.6 million for the six months ended June 30, 2015 and 2014, respectively, are included in interest expense in the accompanying consolidated statements of operations.  Unamortized fees are included in other current assets and other long-term assets.

 

Note 7. Related Party Transactions

 

The Partnership was a party to an exclusive Second Amended and Restated Terminal Storage Rental and Throughput Agreement, as amended (the “Terminal Storage Rental and Throughput Agreement”), with GPC, an affiliate of the Partnership that is 100% owned by members of the Slifka family, with respect to the Revere Terminal in Revere, Massachusetts.  On January 14, 2015, the Partnership acquired the Revere Terminal from GPC and related entities, and the Terminal Storage Rental and Throughput Agreement has terminated (see Note 2).  Prior to the acquisition, the agreement was accounted for as an operating lease.  The expenses under this agreement totaled $0 and $2.3 million for the three months ended June 30, 2015 and 2014, respectively, and $0.8 million and $4.6 million for the six months ended June 30, 2015 and 2014, respectively.

 

The Partnership was a party to an Amended and Restated Services Agreement with GPC, whereby GPC provided certain terminal operating management services to the Partnership and used certain administrative, accounting and information processing services of the Partnership.  The expenses from these services totaled approximately $0 and $24,000 for the three months ended June 30, 2015 and 2014, respectively, and $8,000 and $48,000 for the six months

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ended June 30, 2015 and 2014, respectively.  These charges were recorded in selling, general and administrative expenses in the accompanying consolidated statements of operations. 

 

On March 11, 2015, the Partnership entered into the following amendments and restatements to its shared services agreements: (i) Global Companies entered into an Amended and Restated Services Agreement with AE Holdings Corp. (the “AE Holdings Amended and Restated Services Agreement”), and (ii) certain of the Partnership’s subsidiaries entered into a Second Amended and Restated Services Agreement with GPC (the “GPC Second Amended and Restated Services Agreement,” and together with the AE Holdings Amended and Restated Services Agreement, the “Amended and Restated Services Agreements”).

 

Under the AE Holdings Amended and Restated Services Agreement, the Partnership continues to provide AE Holdings with certain tax, accounting, treasury and legal support services for which AE Holdings pays the Partnership an aggregate of $15,000 per year in equal monthly installments.  Under the GPC Second Amended and Restated Services Agreement, GPC no longer provides the Partnership with terminal, environmental and operational support services, but the Partnership continues to provide GPC with certain tax, accounting, treasury, legal, information technology, human resources and financial operations support services for which GPC pays the Partnership a monthly services fee at an agreed amount subject to the approval by the Conflicts Committee of the board of directors of the General Partner.  The Amended and Restated Services Agreements are each for an indefinite term and any party may terminate some or all of the services upon ninety (90) days’ advanced written notice.  As of June 30, 2015, no such notice of termination was given by any party.

 

The General Partner employs substantially all of the Partnership’s employees, except for most of its gasoline station and convenience store employees and certain union personnel, who are employed by GMG or Drake Petroleum.  The Partnership reimburses the General Partner for expenses incurred in connection with these employees.  These expenses, including payroll, payroll taxes and bonus accruals, were $49.2 million and $17.5 million for the three months ended June 30, 2015 and 2014, respectively, and $78.6 million and $48.7 million for the six months ended June 30, 2015 and 2014, respectively.  The Partnership also reimburses the General Partner for its contributions under the General Partner’s 401(k) Savings and Profit Sharing Plan and the General Partner’s qualified and non-qualified pension plans.

 

The table below presents trade receivables with GPC and the Partnership and receivables from the General Partner (in thousands):

 

 

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Note 8.Partners’ Equity and Cash Distributions

 

Partners’ Equity

 

Partners’ equity at June 30, 2015 consisted of 33,995,563 common units issued,  including 8,262,582 common units held by affiliates of the General Partner, including directors and executive officers, collectively representing a

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99.33% limited partner interest in the Partnership, and 230,303 general partner units representing a 0.67% general partner interest in the Partnership.

 

 

Partners’ equity at June 30, 2015 and December 31, 2014 excluded common units outstanding of 453,219 and 390,602, respectively, held pursuant to the Repurchase Program and for future satisfaction of the General Partner’s Obligations (as defined herein).  See Note 13, “Long-Term Incentive Plan—Repurchase Program.”

 

Cash Distributions

 

The Partnership intends to consider regular cash distributions to unitholders on a quarterly basis, although there is no assurance as to the future cash distributions since they are dependent upon future earnings, capital requirements, financial condition and other factors.  The Credit Agreement prohibits the Partnership from making cash distributions if any potential default or Event of Default, as defined in the Credit Agreement, occurs or would result from the cash distribution.

 

Within 45 days after the end of each quarter, the Partnership will distribute all of its Available Cash (as defined in its partnership agreement) to unitholders of record on the applicable record date.  The amount of Available Cash is all cash on hand on the date of determination of Available Cash for the quarter; less the amount of cash reserves established by the General Partner to provide for the proper conduct of the Partnership’s business, to comply with applicable law, any of the Partnership’s debt instruments, or other agreements or to provide funds for distributions to unitholders and the General Partner for any one or more of the next four quarters.

 

The Partnership will make distributions of Available Cash from distributable cash flow for any quarter in the following manner: 99.33% to the common unitholders, pro rata, and 0.67% to the General Partner, until the Partnership distributes for each outstanding common unit an amount equal to the minimum quarterly distribution for that quarter; and thereafter, cash in excess of the minimum quarterly distribution is distributed to the unitholders and the General Partner based on the percentages as provided below.

 

As holder of the IDRs, the General Partner is entitled to incentive distributions if the amount that the Partnership distributes with respect to any quarter exceeds specified target levels shown below:

 

 

 

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The Partnership paid the following cash distribution during 2015 (in thousands, except per unit data):

 

 

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In addition, on July 22, 2015, the board of directors of the General Partner declared a quarterly cash distribution of $0.6925 per unit ($2.77 per unit on an annualized basis) on all of its outstanding common units for the period from April 1, 2015 through June 30, 2015 to the Partnership’s unitholders of record as of the close of business on August 5, 2015.  This distribution will result in the Partnership exceeding its third target level distribution for the quarter ended June 30, 2015.

 

Note 9.Unitholders’ Equity

 

Equity Offering

 

On June 11, 2015, the Partnership entered into an Underwriting Agreement (the “Underwriting Agreement”) relating to the public offering of 3,000,000 common units at a price to the public of $38.12 per common unit.  On June 16, 2015, the Partnership completed the offering, and the net proceeds of approximately $109.3 million (after deducting underwriting discounts and estimated expenses) were used to reduce indebtedness outstanding under the Partnership’s revolving credit facility.

 

The common  units issued pursuant to the Underwriting Agreement were registered under the Securities Act, pursuant to the Partnership’s shelf registration statement on Form S-3 (File No. 333-204233) which was filed with the SEC and became effective on May 15, 2015.

 

At-the-Market Offering

 

On May 19, 2015, the Partnership entered into an Equity Distribution Agreement (the “Agreement”) pursuant to which the Partnership may sell from time to time through its sales agents, the Partnership’s common units having an aggregate offering price of up to $50.0 million.  Sales of the common units, if any, will be made by any method permitted by law deemed to be an “at-the-market” offering, including ordinary brokers’ transactions through the facilities of the New York Stock Exchange, to or through a market maker, or directly on or through an electronic communication network, a “dark pool” or any similar market venue, at market prices, in block transactions, or as otherwise agreed upon by the Partnership and one or more of its sales agents.

 

Under the terms of the Agreement, the Partnership may also sell common units to one or more of its sales agents as principal for its own account at a price to be agreed upon at the time of sale.  Any sale of common units to a sales agent as principal would be pursuant to the terms of a separate agreement between the Partnership and such sales agent

 

The Partnership intends to use the net proceeds from any sales pursuant to the Agreement, after deducting the sales agents’ commissions and the Partnership’s offering expenses, for general partnership purposes, which may include, among other things, repayment of indebtedness, acquisitions and capital expenditures.

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The Common Units will be issued pursuant to the Partnership’s existing effective shelf registration statement on Form S-3 (Registration No. 333-188982).

 

The sales agents and/or affiliates of each of the sales agents have, from time to time, performed, and may in the future perform, various financial advisory and commercial and investment banking services for the Partnership and its affiliates, for which they have received and in the future will receive customary compensation and expense reimbursement.  Affiliates of the sales agents are lenders under the Partnership’s credit facility and, accordingly, may receive a portion of the net proceeds from this offering if and to the extent any proceeds are used to reduce outstanding borrowings under the Partnership’s credit facility.

 

As of June 30, 2015, no common  units were sold by the Partnership pursuant to the Agreement.

 

Note 10.Segment Reporting

 

The Partnership engages in the purchasing, selling and logistics of transporting petroleum and related products, including domestic and Canadian crude oil, gasoline and gasoline blendstocks (such as ethanol and naphtha), distillates (such as home heating oil, diesel and kerosene), residual oil, renewable fuels, natural gas and propane.  The Partnership also receives revenue from convenience store sales and gasoline station rental income.  The Partnership’s operating segments are based upon the revenue sources for which discrete financial information is reviewed by the chief operating decision maker (the “CODM”) and include Wholesale, GDSO and Commercial.  Each of these operating segments generates revenues and incurs expenses and is evaluated for operating performance on a regular basis.

 

These operating segments are also the Partnership’s reporting segments based on the way the CODM manages the business and on the similarity of customers and expected long-term financial performance of each segment.  For the three and six months ended June 30, 2015 and 2014, the Commercial operating segment did not meet the quantitative metrics for disclosure as a reportable segment on a stand-alone basis as defined in accounting guidance related to segment reporting.  However, the Partnership has elected to present segment disclosures for the Commercial operating segment as management believes such disclosures are meaningful to the user of the Partnership’s financial information.  The accounting policies of the segments are the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014.

 

In the Wholesale reporting segment, the Partnership sells branded and unbranded gasoline and gasoline blendstocks and diesel to branded and unbranded gasoline customers and other resellers of transportation fuels.  The Partnership aggregates crude oil by truck or pipeline in the mid-continent region of the United States and Canada, transports it by train and ships it by barge to refiners on the East and West Coasts.  The Partnership sells home heating oil, diesel, kerosene, residual oil and propane to home heating oil and propane retailers and wholesale distributors.  Generally, customers use their own vehicles or contract carriers to take delivery of the gasoline and distillate products at bulk terminals and inland storage facilities that the Partnership owns or controls or with which it has throughput or exchange arrangements.  Additionally, ethanol is shipped primarily by rail and by barge.

 

In the GDSO reporting segment, gasoline distribution includes sales of branded and unbranded gasoline to gasoline station operators and sub jobbers.  Station operations include convenience stores, rental income from gasoline stations leased to dealers or commissioned agents and sundry (car wash sales, lottery and ATM commissions).  The results of Warren, acquired in January 2015, and Capitol, acquired in June 2015 (see Note 2), are included in the GDSO segment.

 

In the Commercial segment, the Partnership includes sales and deliveries to end user customers in the public sector and to large commercial and industrial end users of unbranded gasoline, home heating oil, diesel, kerosene, residual oil, bunker fuel and natural gas.  In the case of public sector commercial and industrial end user customers, the

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Partnership sells products primarily either through a competitive bidding process or through contracts of various terms.  The Partnership generally arranges for the delivery of the product to the customer’s designated location, and the Partnership responds to publicly-issued requests for product proposals and quotes.  The Commercial segment also includes sales of custom blended fuels delivered by barges or from a terminal dock to ships through bunkering activity.

 

The Partnership evaluates segment performance based on product margins before allocations of corporate and indirect operating costs, depreciation, amortization (including non-cash charges) and interest.  Based on the way the CODM manages the business, it is not reasonably possible for the Partnership to allocate the components of operating costs and expenses among the reportable segments.

 

Summarized financial information for the Partnership’s reportable segments is presented in the table below (in thousands):

 

 

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A reconciliation of the totals reported for the reportable segments to the applicable line items in the consolidated financial statements is as follows (in thousands):

 

 

 

The Partnership’s foreign assets and foreign sales were immaterial as of and for the three and six months ended June 30, 2015 and 2014.

 

Segment Assets

 

The Partnership acquired retail gasoline stations from Capitol in June 2015, Warren in January 2015, Alliance in March 2012 and ExxonMobil in September 2010 which have been allocated to the GDSO segment.  The Partnership acquired the Revere Terminal in January 2015 which has been allocated to the Wholesale segment.

 

Due to the commingled nature and uses of the remainder of the Partnership’s assets, it is not reasonably possible for the Partnership to allocate these assets among its reportable segments.

 

The table below presents total assets by reportable segment at June 30, 2015 and December 31, 2014 (in thousands):

 

 

 

The increase in total assets allocated GDSO at June 30, 2015 compared to December 31, 2014 is due to the January 2015 acquisition of Warren and the June 2015 acquisition of Capitol (Note 2).

 

 

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Note 11. Property and Equipment

 

Property and equipment consisted of the following (in thousands):

 

 

 

The increase of approximately $459.9 million in total property and equipment at June 30, 2015 was primarily due to the Partnership’s 2015 acquisitions of Warren, Capitol and the Revere Terminal (see Note 2).   At June 30, 2015 and December 31, 2014, construction in process included $30.5 million related to the Partnership’s ethanol plant acquired from Cascade Kelly in 2013.  Due to the nature of certain assets acquired from Cascade Kelly which are currently idle, the Partnership intends to make the capital improvements necessary to place the ethanol plant into service and expects the plant to be operational in 2016; therefore, as of June 30, 2015 and December 31, 2014, the recorded value of the ethanol plant is included in construction in process.  After the plant has been successfully placed into service, depreciation will commence.

 

As part of continuing operations, the Partnership may periodically divest certain gasoline stations.  The gain (loss) on the sale, representing cash proceeds less net book value of assets at disposition, is recorded in loss on asset sales in the accompanying consolidated statements of operations and amounted to $0.2 million and $0.4 million for the three months ended June 30, 2015 and 2014, respectively, and $0.6 million and $1.1 million for the six months ended June 30, 2015 and 2014, respectively.

 

The Partnership evaluates its assets for impairment on a quarterly basis.  No impairments were required for the three or six months ended June 30, 2015 and 2014.    However, at June 30, 2015, the Partnership had a $3.4 million remaining net book value of long-lived assets used in supplying compressed natural gas (“CNG”) which is viewed as an alternative fuel to oil.  The long-term recoverability of these assets might be adversely impacted by any prolonged decline in commodity prices or the cost differential between natural gas and oil.  Over the long term, if oil remains an attractive alternative to CNG due to lower oil prices, this may become an indicator of the potential impairment of these CNG assets in the future.  The Partnership monitors the pricing environment and the related impact this may have on the CNG operating and cash flows and whether this would constitute an impairment indicator.

 

Note 12. Environmental Liabilities, Asset Retirement Obligations and Renewable Identification Numbers

 

Environmental Liabilities

 

The Partnership owns or leases properties where refined petroleum products, renewable fuels and crude oil are being or may have been handled.  These properties and the refined petroleum products, renewable fuels and crude oil handled thereon may be subject to federal and state environmental laws and regulations.  Under such laws and regulations, the Partnership could be required to remove or remediate containerized hazardous liquids or associated generated wastes (including wastes disposed of or abandoned by prior owners or operators), to clean up contaminated

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property arising from the release of liquids or wastes into the environment, including contaminated groundwater, or to implement best management practices to prevent future contamination.

 

The Partnership maintains insurance of various types with varying levels of coverage that it considers adequate under the circumstances to cover its operations and properties.  The insurance policies are subject to deductibles that the Partnership considers reasonable and not excessive.  In addition, the Partnership has entered into indemnification agreements with various sellers in conjunction with several of its acquisitions.  Allocation of environmental liability is an issue negotiated in connection with each of the Partnership’s acquisition transactions.  In each case, the Partnership makes an assessment of potential environmental liability exposure based on available information.  Based on that assessment and relevant economic and risk factors, the Partnership determines whether to, and the extent to which it will, assume liability for existing environmental conditions.

 

In connection with the June 2015 acquisition of retail gasoline stations from Capitol (see Note 2), the Partnership assumed certain environmental liabilities, including future remediation activities required by applicable federal, state or local law or regulation at certain of the retail gasoline stations owned by Capitol.  Certain environmental remediation obligations at most of the acquired retail gasoline station assets from Capitol are being funded by third parties who assumed certain liabilities in connection with Capitol’s acquisition of these assets from ExxonMobil in 2009 and 2010 and, therefore, cost estimates for such obligations at these stations are not included in this estimate.  As a result, the Partnership recorded, on an undiscounted basis, a total environmental liability of approximately $0.2 million.    

 

In connection with the January 2015 acquisition of the Revere Terminal (see Note 2), the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts.  As a result, the Partnership recorded, on an undiscounted basis, a total environmental liability of approximately $3.1 million.

 

In connection with the January 2015 acquisition of Warren (see Note 2), the Partnership assumed certain environmental liabilities, including certain ongoing environmental remediation efforts at certain of the retail gasoline stations owned by Warren and future remediation activities required by applicable federal, state or local law or regulation.  As a result, the Partnership recorded, on an undiscounted basis, a total environmental liability of approximately $36.1 million.

 

The $0.2 million, $3.1 million and $36.1 million recorded for Capitol, the Revere Terminal and Warren, respectively, were based on preliminary purchase accounting.  These amounts may change as the purchase price accounting is finalized.

 

In connection with the December 2012 acquisition of six New England retail gasoline stations from Mutual Oil, the Partnership assumed certain environmental liabilities, including certain ongoing remediation efforts.  As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $0.6 million.

 

In connection with the March 2012 acquisition of Alliance, the Partnership assumed Alliance’s environmental liabilities, including ongoing environmental remediation at certain of the retail gasoline stations owned by Alliance and future remediation activities required by applicable federal, state or local law or regulation.  Remedial action plans are in place, as may be applicable with the state agencies regulating such ongoing remediation.  Based on reports from environmental engineers, the Partnership’s estimated cost of the ongoing environmental remediation for which Alliance was responsible and future remediation activities required by applicable federal, state or local law or regulation is estimated to be approximately $16.1 million to be expended over an extended period of time.  Certain environmental remediation obligations at the retail stations acquired by Alliance from ExxonMobil in 2011 are being funded by a third party who assumed the liability in connection with the Alliance/ExxonMobil transaction in 2011 and, therefore, cost estimates for such obligations at these stations are not included in this estimate.  As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $16.1 million.

 

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In connection with the September 2010 acquisition of retail gasoline stations from ExxonMobil, the Partnership assumed certain environmental liabilities, including ongoing environmental remediation at and monitoring activities at certain of the acquired sites and future remediation activities required by applicable federal, state or local law or regulation.  Remedial action plans are in place with the applicable state regulatory agencies for the majority of these locations, including plans for soil and groundwater treatment systems at certain sites. Based on consultations with environmental engineers, the Partnership’s estimated cost of the remediation is expected to be approximately $30.0 million to be expended over an extended period of time.  As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $30.0 million.

 

In addition to the above-mentioned environmental liabilities related to the Partnership's retail gasoline stations, the Partnership retains environmental obligations associated with certain gasoline stations that the Partnership has sold.

 

In connection with the June 2010 acquisition of three refined petroleum products terminals in Newburgh, New York, the Partnership assumed certain environmental liabilities, including certain ongoing remediation efforts.  As a result, the Partnership initially recorded, on an undiscounted basis, a total environmental liability of approximately $1.5 million.

 

In connection with the November 2007 acquisition of ExxonMobil’s Glenwood Landing and Inwood, New York terminals, the Partnership assumed certain environmental liabilities, including the remediation obligations under remedial action plans submitted by ExxonMobil to and approved by the New York Department of Environmental Conservation (“NYDEC”) with respect to both terminals.  As a result, the Partnership initially recorded, on an undiscounted basis, total environmental liabilities of approximately $1.2 million.

 

The following table presents a summary roll forward of the Partnership’s environmental liabilities at June 30, 2015 (in thousands):

 

 

The Partnership’s estimates used in these environmental liabilities are based on all known facts at the time and its assessment of the ultimate remedial action outcomes.  Among the many uncertainties that impact the Partnership’s estimates are the necessary regulatory approvals for, and potential modification of, its remediation plans, the amount of data available upon initial assessment of the impact of soil or water contamination, changes in costs associated with environmental remediation services and equipment, relief of obligations through divestures of sites and the possibility of existing legal claims giving rise to additional claims.  Dispositions generally represent relief of legal obligations through the sale of the related property with no retained obligation.  Other adjustments generally represent changes in estimates for existing obligations or obligations associated with new sites.  Therefore, although the Partnership believes that these environmental liabilities are adequate, no assurances can be made that any costs incurred in excess of these environmental liabilities or outside of indemnifications or not otherwise covered by insurance would not have a material adverse effect on the Partnership’s financial condition, results of operations or cash flows.

 

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Asset Retirement Obligations

 

The Partnership is required to account for the legal obligations associated with the long-lived assets that result from the acquisition, construction, development or operation of long-lived assets.  Such asset retirement obligations specifically pertain to the treatment of underground gasoline storage tanks (“USTs”) that exist in those states which statutorily require removal of the USTs at a certain point in time.  Specifically, the Partnership’s retirement obligations consist of the estimated costs of removal and disposals of USTs in specific states.

 

The fair value of a liability for an asset retirement obligation is recognized in the year in which it is incurred.  The associated asset retirement costs are capitalized as part of the carrying cost of the asset.  The Partnership had approximately $6.6 million and $3.8 million in total asset retirement obligations at June 30, 2015 and December 31, 2014, respectively, which are included in other long-term liabilities in the accompanying balance sheets.  Approximately $1.9 million and $0.8 million of these obligations at June 30, 2015 were assumed in the acquisitions of Warren and Capitol, respectively, and were based on preliminary purchase accounting.  These amounts may change as the purchase price accounting valuations are finalized.

 

Renewable Identification Numbers (RINs)

 

A Renewable Identification Number (“RIN”) is a serial number assigned to a batch of renewable fuel for the purpose of tracking its production, use and trading as required by the Environmental Protection Agency’s (the “EPA”) Renewable Fuel Standard that originated with the Energy Policy Act of 2005 and modified by the Energy Independence and Security Act of 2007.  To evidence that the required volume of renewable fuel is blended with gasoline and diesel motor vehicle fuels, obligated parties must retire sufficient RINs to cover their Renewable Volume Obligation (“RVO”). The Partnership’s EPA obligations relative to renewable fuel reporting are largely limited to the foreign gasoline that the Partnership may choose to import and a small amount of blending operations at certain facilities.  As a wholesaler of transportation fuels through its terminals, the Partnership separates RINs from renewable fuel through blending with gasoline and can use those separated RINs to settle its RVO.  While the annual compliance period for the RVO is a calendar year and the settlement of the RVO typically occurs by March 31 of the following year, the settlement of the RVO can occur, under certain EPA deferral actions, more than one year after the close of the compliance period.

 

The Partnership’s Wholesale segment’s operating results are sensitive to the timing associated with its RIN position relative to its RVO at a point in time, and the Partnership may recognize a mark-to-market liability for a shortfall in RINs at the end of each reporting period.  To the extent that the Partnership does not have a sufficient number of RINs to satisfy the RVO as of the balance sheet date, the Partnership charges cost of sales for such deficiency based on the market price of the RINs as of the balance sheet date and records a liability representing the Partnership’s obligation to purchase RINs.  The Partnership’s RVO deficiency was $0.2 million and $0.3 million at June 30, 2015 and December 31, 2014, respectively.

 

The Partnership may enter into RIN forward purchase and sales commitments.  Total losses from firm non-cancellable commitments were immaterial at June 30, 2015 and December 31, 2014.

 

Note 13. Long-Term Incentive Plan

 

The Partnership has a Long Term Incentive Plan, as amended (the “LTIP”) whereby a total of 4,300,000 common units were initially authorized for delivery with respect to awards under the LTIP.  The LTIP provides for awards to employees, consultants and directors of the General Partner and employees and consultants of affiliates of the Partnership who perform services for the Partnership.  The LTIP allows for the award of options, unit appreciation rights, restricted units, phantom units, distribution equivalent rights, unit awards and substitute awards.

 

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Awards granted under the LTIP are authorized by the Compensation Committee of the board of directors of the General Partner (the “Committee”) from time to time. Additionally and in accordance with the LTIP, the Committee established a “CEO Authorized LTIP” program pursuant to which the Chief Executive Officer (“CEO”) may grant awards of phantom units without distribution equivalent rights to employees of the General Partner and the Partnership’s subsidiaries, other than named executive officers.  The CEO Authorized LTIP program was approved for three consecutive calendar years commencing January 1, 2014, subject to modification or earlier termination by the Committee.  During each calendar year of the program, the CEO is authorized to grant awards of up to an aggregate amount of $2.0 million of phantom units payable in common units upon vesting, and no individual grant may be made for an award valued at the time of grant of more than $550,000, unless otherwise previously approved by the Committee.  Awards granted pursuant to the CEO Authorized LTIP would be for a term of six years and vest in equal tranches at the end of each of the fourth, fifth and sixth anniversary dates of the particular award.

 

Phantom Unit Awards

 

In 2013, the Committee granted a total of 498,112 phantom units under the LTIP to certain employees and non-employee directors of the General Partner.  In connection with the awards, grantees who are employees entered into various forms of a Confidentiality, Non Solicitation, and Non-Competition Agreement with the General Partner. On December 31, 2014, a total of 10,266 of the awards granted to one employee and the non-employee directors vested and in January 2015, these phantom unit grants were settled.

 

In 2014, a total of 44,902 phantom units were granted to certain employees, and during the six months ended June 30, 2015, a total of 49,847 phantom units were granted to certain employees and the non-employee directors.

 

The phantom units for these awards vest pursuant to the terms of the grant agreements.  The Partnership currently intends and reasonably expects to issue and deliver the common units upon vesting. 

 

The Partnership recorded total compensation expense related to these awards of $1.1 million and $0.9 million for the three months ended June 30, 2015 and 2014, respectively, and $2.1 million and $1.7 million for the six months ended June 30, 2015 and 2014, respectively, which is included in selling, general and administrative expenses in the accompanying consolidated statement of operations.  The total compensation cost related to the non-vested awards not yet recognized at June 30, 2015 was approximately $14.8 million and is expected to be recognized ratably over the remaining requisite service period.

 

The following table presents a summary of the status of the non-vested phantom units:

 

 

 

 

Repurchase Program

 

In May 2009, the board of directors of the General Partner authorized the repurchase of the Partnership’s common units (the “Repurchase Program”) for the purpose of meeting the General Partner’s anticipated obligations to deliver common units under the LTIP and meeting the General Partner’s obligations under existing employment agreements and

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other employment related obligations of the General Partner (collectively, the “General Partner’s Obligations”).  The General Partner is currently authorized to acquire up to 1,242,427 of its common units in the aggregate over an extended period of time, consistent with the General Partner’s Obligations.  Common units may be repurchased from time to time in open market transactions, including block purchases, or in privately negotiated transactions.  Such authorized unit repurchases may be modified, suspended or terminated at any time and are subject to price and economic and market conditions, applicable legal requirements and available liquidity.  Since the Repurchase Program was implemented, the General Partner has repurchased 791,792 common units pursuant to the Repurchase Program for approximately $23.3 million, of which approximately $2.4 million was purchased during the first quarter ended March 31, 2015.

 

Common units outstanding as reported in the accompanying consolidated financial statements at June 30, 2015 and December 31, 2014 excluded 453,219 and 390,602 common units, respectively, held on behalf of the Partnership pursuant to its Repurchase Program and for future satisfaction of the General Partner’s Obligations.

 

Note 14.Fair Value Measurements

 

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).  The Partnership utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique.  These inputs can be readily observable, market corroborated or generally unobservable.  The Partnership primarily applies the market approach for recurring fair value measurements and endeavors to utilize the best available information.  Accordingly, the Partnership utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.  The Partnership is able to classify fair value balances based on the observability of those inputs.  The fair value hierarchy that prioritizes the inputs used to measure fair value, giving the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).  At each balance sheet reporting date, the Partnership categorizes its financial assets and liabilities using the three levels of the fair value hierarchy defined as follows:

 

 

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Recurring Fair Value Measures

 

Assets and liabilities are classified in the entirety based on the lowest level of input that is significant to the fair value measurement.  The Partnership’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value assets and liabilities and their placement within the fair value hierarchy levels.

 

The following tables present, by level within the fair value hierarchy, the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014 (in thousands):

 

 

 

 

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This table excludes cash on hand and assets and liabilities that are measured at historical cost or any basis other than fair value.  The carrying amounts of certain of the Partnership’s financial instruments, including cash equivalents, accounts receivable, accounts payable and other accrued liabilities approximate fair value due to their short maturities.  The carrying value of the Partnership’s credit facility approximates fair value due to the variable rate nature of these financial instruments. 

 

The carrying values and fair values of the Partnership’s 6.25% Notes and 7.00% Notes, estimated by observing market trading prices of the 6.25% Notes and 7.00% Notes, respectively, were as follows (in thousands):

 

 

 

The carrying value of the Partnership’s inventory qualifying for fair value hedge accounting approximates fair value due to adjustments for changes in fair value of the hedged item.  The fair values of the derivatives used by the Partnership are disclosed in Note 5.

 

The determination of the fair values above incorporates factors including not only the credit standing of the counterparties involved, but also the impact of the Partnership’s nonperformance risks on its liabilities.

 

The values of the Partnership’s Level 1 exchange-traded/cleared derivative instruments and pension plan assets were determined using quoted prices in active markets for identical assets.  Specifically, the fair values of the Partnership’s Level 1 exchange-traded/cleared derivative instruments were based on quoted process obtained from the NYMEX and CME.  The fair values of the Partnership’s Level 1 pension plan assets were based on quoted prices for identical assets which primarily consisted of fixed income securities, equity securities and cash and cash equivalents.

 

The values of the Partnership’s Level 2 derivative contracts were calculated using expected cash flow models and market approaches based on observable market inputs, including published and quoted commodity pricing data, which is verified against other available market data.  Specifically, the fair values of the Partnership’s Level 2 derivative commodity contracts were derived from published and quoted NYMEX, CME, New York Harbor and third-party pricing information for the underlying instruments using market approaches.  The fair value of the Partnership’s Level 2 interest rate instruments were derived from the implied forward LIBOR yield curve for the sale period as the future interest rate swap and interest rate cap settlements using expected cash flow models.  The fair value of the Partnership’s Level 2 foreign currency derivatives were derived from the implied forward currency curve for the Canadian and U.S. Dollar.  The Partnership has not changed its valuation techniques or Level 2 inputs during the six months ended June 30, 2015.

 

Level 3 Information

 

The values of the Partnership’s Level 3 derivative contracts were calculated using market approaches based on a combination of observable and unobservable market inputs, including published and quoted NYMEX, CME, New York Harbor and third-party pricing information for a component of the underlying instruments as well as internally developed assumptions where there is little, if any, published or quoted prices or market activity.  The unobservable inputs used in the measurement of the Partnership’s Level 3 derivative contracts include estimates for location basis, transportation and throughput costs net of an estimated margin for current market participants.  The estimates for these inputs were $7.25 to $10.75 per barrel for the six months ended June 30, 2015 and $10.00 to $12.00 per barrel for the six months ended June 30, 2014.  Gains and losses recognized in earnings (or changes in net assets) are disclosed in Note 5.

 

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Sensitivity of the fair value measurement to changes in the significant unobservable inputs is as follows:

 

 

 

 

The following table presents a reconciliation of changes in fair value of the Partnership’s derivative contracts classified as Level 3 in the fair value hierarchy at June 30, 2015 (in thousands):

 

 

 

Non-Recurring Fair Value Measures

 

Certain nonfinancial assets and liabilities are measured at fair value on a non-recurring basis and are subject to fair value adjustments in certain circumstances, such as acquired assets and liabilities or losses related to firm non-cancellable purchase commitments.  For assets and liabilities measured on a non-recurring basis during the period, accounting guidance requires quantitative disclosures about the fair value measurements separately for each major category.  See Note 2 for acquired assets and liabilities measured on a non-recurring basis during the six months ended June 30, 2015.

 

Note 15. Income Taxes

 

Section 7704 of the Internal Revenue Code provides that publicly-traded partnerships are, as a general rule, taxed as corporations.  However, an exception, referred to as the “Qualifying Income Exception,” exists under Section 7704(c) with respect to publicly-traded partnerships of which 90% or more of the gross income for every taxable year consists of “qualifying income.”  Qualifying income includes income and gains derived from the transportation, storage and marketing of refined petroleum products and crude oil and ethanol to resellers and refiners.  Other types of qualifying income include interest (other than from a financial business), dividends, gains from the sale of real property and gains from the sale or other disposition of capital assets held for the production of income that otherwise constitutes qualifying income.

 

Substantially all of the Partnership’s income is “qualifying income” for federal income tax purposes and, therefore, is not subject to federal income taxes at the partnership level.  Accordingly, no provision has been made for income taxes on the qualifying income in the Partnership’s financial statements.  Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under the Partnership’s agreement of limited partnership.  Individual unitholders have different investment basis depending upon the timing and price at which they acquired their common units.  Further, each unitholder’s tax accounting, which is partially dependent upon the unitholder’s tax position, differs from the accounting followed in the Partnership’s consolidated financial statements.  Accordingly, the aggregate difference in the basis of the Partnership’s net assets for

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financial and tax reporting purposes cannot be readily determined because information regarding each unitholder’s tax attributes in the Partnership is not available to the Partnership.

 

One of the Partnership’s wholly owned subsidiaries, GMG, is a taxable entity for federal and state income tax purposes.  Current and deferred income taxes are recognized on the separate earnings of GMG.  The after-tax earnings of GMG are included in the earnings of the Partnership.  Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes for GMG.  Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis.  Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled.  The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.  The Partnership calculates its current and deferred tax provision based on estimates and assumptions that could differ from actual results reflected in income tax returns filed in subsequent years.  Adjustments based on filed returns are recorded when identified.

 

The Partnership recognizes deferred tax assets to the extent that the recoverability of these assets satisfies the “more likely than not” recognition criteria in accordance with the accounting guidance regarding income taxes.  Based upon projections of future taxable income, the Partnership believes that the recorded deferred tax assets will be realized.

 

Note 16.   Legal Proceedings

 

General

 

Although the Partnership may, from time to time, be involved in litigation and claims arising out of its operations in the normal course of business, the Partnership does not believe that it is a party to any litigation that will have a material adverse impact on its financial condition or results of operations.  Except as described below and in Note 12 included herein, the Partnership is not aware of any significant legal or governmental proceedings against it, or contemplated to be brought against it.  The Partnership maintains insurance policies with insurers in amounts and with coverage and deductibles as its general partner believes are reasonable and prudent.  However, the Partnership can provide no assurance that this insurance will be adequate to protect it from all material expenses related to potential future claims or that these levels of insurance will be available in the future at economically acceptable prices.

 

Other

 

On May 29, 2015 and in connection with a commercial dispute with Tethys Trading Company LLC (“Tethys”), the Partnership received a notice from Tethys alleging a default under, and purporting to terminate, the Partnership’s contract with Tethys for crude oil services at the Partnership’s Oregon facility.  However, the Partnership does not believe Tethys had the right to terminate the contract, and the Partnership will take appropriate action to enforce its rights under the agreement.  The Partnership had expected to receive fees from this contract of approximately $13.2 million for the period July 1, 2015 through December 31, 2015 and approximately $105.2 million in the aggregate for the remaining four years of the contract.

 

On March 26, 2015, the Partnership received a Notice of Non-Compliance (“NON”) from the Massachusetts Department of Environmental Protection (“DEP”) with respect to its terminal located at 101 and 186 Lee Burbank Highway, Revere, Massachusetts (the “Terminal”), alleging certain violations of the National Pollutant Discharge Elimination System Permit (“NPDES Permit”) related to storm water discharges.  The NON requires the Partnership to submit a plan to remedy the reported violations of the NPDES Permit.  The Partnership has responded to the NON with a plan and is implementing modifications to the storm water management system at the Terminal.  The Partnership has determined that compliance with the NON and implementation of the plan will have no material impact on its operations.

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The Partnership has a dispute with Lansing Ethanol Services, LLC (“Lansing”) for damages in excess of $12.0 million. The dispute involves Lansing’s failure to transfer Renewable Fuel Identification Numbers to the Partnership in connection with certain agreements for the purchase and sale of ethanol.  The parties have agreed to arbitrate under the rules of the American Arbitration Association.  The Partnership filed for arbitration on March 24, 2015 and anticipates arbitration to commence during the first quarter ending March 31, 2016.  The Partnership believes it has meritorious positions and intends to vigorously pursue a favorable result in connection with this dispute.

 

On July 2, 2014, a lawsuit was filed by the Northwest Environmental Defense Center and other environmental non-government organizations (the “Plaintiffs”) against the Partnership and Cascade Kelly alleging violations of the Clean Air Act.  The suit, filed in the United States District Court for the district of Oregon, alleges that Cascade Kelly is operating without the proper permit under the applicable rules.  The lawsuit seeks penalties, injunctive relief and reimbursement of attorneys’ fees.  Trial has been scheduled for the fourth quarter of 2015.  The Partnership has meritorious defenses to the lawsuit and is vigorously contesting the actions taken by the Plaintiffs.

 

On May 16, 2014, the Partnership received a subpoena from the Securities and Exchange Commission requesting information for relevant time periods primarily relating to the Partnership’s accounting for Renewable Identification Numbers and the restatements of its consolidated financial statements as of and for the quarters ended March 31, 2013, June 30, 2013 and September 30, 2013.  The Partnership intends to continue to cooperate fully with, and has produced responsive materials to, the SEC.

 

The Partnership received from the EPA, by letters dated November 2, 2011 and March 29, 2012, containing requirements and testing orders (collectively, the “Requests for Information”) for information under the Clean Air Act.  The Requests for Information were part of an EPA investigation to determine whether the Partnership has violated sections of the Clean Air Act at certain of its terminal locations in New England with respect to residual oil and asphalt.  On June 6, 2014, a Notice of Violation (“NOV”) was received from the EPA, alleging certain violations of its Air Emissions License issued by the Maine Department of Environmental Protection, based upon the test results at the South Portland, Maine terminal.  The Partnership met with and provided additional information to the EPA with respect to the alleged violations.  On April 7, 2015, the EPA issued a Supplemental Notice of Violation (the “Supplemental NOV”) modifying the allegations of violations of the terminal’s Air Emissions License.  The Partnership has responded to the Supplemental NOV and is engaged in further negotiations with the EPA.  While the Partnership does not believe that a material violation has occurred, and it contests the allegations presented in the NOV and Supplemental NOV, the Partnership does not believe any adverse determination in connection with the NOV would have a material impact on its operations.

 

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Note 17.   Changes in Accumulated Other Comprehensive Loss

 

The following table presents the changes in accumulated other comprehensive loss by component for the three and six months ended June 30, 2015 (in thousands):

 

 

 

Amounts are presented prior to the income tax effect on other comprehensive income.  Given the Partnership’s master limited partnership status, the effective tax rate is immaterial.

 

Note 18.  New Accounting Standards

 

Accounting Standards or Updates Recently Adopted

 

In April 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” which includes amendments that change the requirements for reporting discontinued operations and require additional disclosures about discontinued operations.  Under the new guidance, only disposals representing a strategic shift in operations that has a major effect on the entity’s operations and financial results should be presented as discontinued operations.  Additionally, this standard requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income and expenses of discontinued operations.  This standard is effective prospectively for fiscal years beginning after December 15, 2014, with early adoption permitted.  The Partnership adopted this standard which did not have a material impact on its consolidated financial statements.

 

Accounting Standards or Updates Not Yet Effective

 

In April 2015, the FASB issued ASU No. 2015-03, “ Interest-Imputation of Interest:  Simplifying the Presentation of Debt Issuance Costs.”  This standard requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying value of that debt liability, consistent with debt discounts.  The recognition and measurement guidance for debt issuance costs are not affected by this standard.  The amendments in this standard are effective retrospectively for fiscal years, and interim periods within those years, beginning after December 15, 2015.  Early adoption is permitted.  The Partnership does not expect the impact of adopting this standard to be material to the Partnership’s consolidated financial statements.

 

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In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers,” that introduces a new five-step revenue recognition model in which an entity should 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.  This standard also requires disclosures sufficient to enable users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract.  In July 2015, the FASB approved a one-year deferral of the effective date of the standard to fiscal periods beginning after December 15, 2017.  The Partnership is currently evaluating the new guidance to determine the impact it will have on its consolidated financial statements.

 

The Partnership has evaluated the accounting guidance recently issued and has determined that there are no other standards or updates will not have a material impact on its financial position, results of operations or cash flows.

 

Note 19.  Subsequent Event

 

On July 22, 2015, the board of directors of the General Partner declared a quarterly cash distribution of $0.6925 per unit ($2.77 per unit on an annualized basis) for the period from April 1, 2015 through June 30, 2015.  On August 14, 2015, the Partnership will pay this cash distribution to its unitholders of record as of the close of business on August 5, 2015.

 

Note 20. Supplemental Guarantor Condensed Consolidating Financial Statements

 

The Partnership’s wholly owned subsidiaries other than GLP Finance Corp. are guarantors of senior notes issued by the Partnership and GLP Finance Corp.  As such, the Partnership is subject to the requirements of Rule 3-10 of Regulation S-X of the Securities and Exchange Commission regarding financial statements of guarantors and issuers of registered guaranteed securities.  The Partnership presents condensed consolidating financial information for its subsidiaries within the notes to consolidated financial statements in accordance with the criteria established for parent companies in the SEC’s Regulation S-X, Rule 3-10(d).

 

The following condensed consolidating financial information presents the Condensed Consolidating Balance Sheets as of June 30, 2015 and December 31, 2014, the Condensed Consolidating Statements of Operations for the three and six months ended June 30, 2015 and 2014 and the Condensed Consolidating Statements of Cash Flows for the six months ended June 30, 2015 and 2014 of the Partnership’s 100% owned guarantor subsidiaries, the non-guarantor subsidiary and the eliminations necessary to arrive at the information for the Partnership on a consolidated basis. The principal elimination entries eliminate investments in subsidiaries and intercompany balances and transactions.

 

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Condensed Consolidating Balance Sheet

June 30, 2015

(In thousands)

 

 

 

 

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Condensed Consolidating Balance Sheet

December 31, 2014

(In thousands)

 

 

 

 

 

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Condensed Consolidating Statement of Operations

Three Months Ended June 30, 2015

(In thousands)

 

 

 

 

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Condensed Consolidating Statement of Operations

Three Months Ended June 30, 2014

(In thousands)

 

 

 

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Condensed Consolidating Statement of Operations

Six Months Ended June 30, 2015

(In thousands)

 

 

 

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Condensed Consolidating Statement of Operations

Six Months Ended June 30, 2014

(In thousands)

 

 

 

 

 

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Condensed Consolidating Statement Cash Flows

Six Months Ended June 30, 2015

(In thousands)

 

 

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Condensed Consolidating Statement Cash Flows

Six Months Ended June 30, 2014

(In thousands)