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GLOBAL PARTNERS LP 10-Q 2007

Documents found in this filing:

  1. 10-Q
  2. Ex-31.1
  3. Ex-31.2
  4. Ex-32.1
  5. Ex-32.2
  6. Ex-32.2

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549


FORM 10-Q

(Mark One)

 

 

x

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

 

 

For the quarterly period ended March 31, 2007

 

 

 

OR

 

 

 

o

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

 

 

For the transition period from              to

 

Commission file number 001-32593

Global Partners LP

(Exact name of registrant as specified in its charter)

Delaware

 

74-3140887

(State or other jurisdiction of incorporation

 

(I.R.S. Employer Identification No.)

or organization)

 

 

 

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 x   No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer (as defined in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer  o

Accelerated filer  x

Non-accelerated filer  o

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).   Yes o   No x

The issuer had 5,642,424 common units, 5,642,424 subordinated units and 1,785,715 Class B units outstanding as of May 9, 2007.

 




 

 

 

TABLE OF CONTENTS

 

PART I.   FINANCIAL INFORMATION

 

 

 

 

 

 

 

Item 1.   Financial Statements

 

 

 

 

 

 

 

Consolidated Balance Sheets as of March 31, 2007 and December 31, 2006

 

 

 

 

 

 

 

Consolidated Statements of Income for the three months ended March 31, 2007 and 2006

 

 

 

 

 

 

 

Consolidated Statements of Cash Flows for the three months ended March 31, 2007 and 2006

 

 

 

 

 

 

 

Consolidated Statements of Partners’ Equity for the three months ended March 31, 2007

 

 

 

 

 

 

 

Notes to Financial Statements

 

 

 

 

 

 

 

Item 2.   Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

 

 

 

 

 

 

Item 3.   Quantitative and Qualitative Disclosures about Market Risk

 

 

 

 

 

 

 

Item 4.   Controls and Procedures

 

 

 

 

 

 

 

PART II.   OTHER INFORMATION

 

 

 

 

 

 

 

Item 1.   Legal Proceedings

 

 

 

 

 

 

 

Item 1A.   Risk Factors

 

 

 

 

 

 

 

Item 6.   Exhibits

 

 

 

 

 

 

 

SIGNATURES

 

 

 

 

 

 

 

INDEX TO EXHIBITS

 

 

 

 




 

Item 1.    Financial Statements

GLOBAL PARTNERS LP
CONSOLIDATED BALANCE SHEETS
(In thousands, except unit data)
(Unaudited)

 

 

March 31
2007

 

December 31
2006

 

Assets

 

 

 

 

 

Current assets:

 

 

 

 

 

Cash and cash equivalents

 

$

1,987

 

$

3,861

 

Accounts receivable, net

 

238,431

 

202,580

 

Accounts receivable—affiliates

 

1,849

 

1,988

 

Inventories

 

142,308

 

288,067

 

Available for sale securities

 

 

13,913

 

Brokerage margin deposits

 

1,379

 

625

 

Fair value of forward fixed contracts

 

 

66,115

 

Prepaid expenses and other current assets

 

9,753

 

18,924

 

Total current assets

 

395,707

 

596,073

 

 

 

 

 

 

 

Property and equipment, net

 

31,691

 

31,657

 

Intangible assets, net

 

8,718

 

9,076

 

Other assets

 

7,074

 

2,081

 

Total assets

 

$

443,190

 

$

638,887

 

 

 

 

 

 

 

Liabilities and partners’ equity

 

 

 

 

 

Current liabilities:

 

 

 

 

 

Accounts payable

 

$

172,704

 

$

222,034

 

Revolving line of credit—current portion

 

53,800

 

188,700

 

Notes payable, other—current portion

 

319

 

319

 

Accrued expenses and other current liabilities

 

22,355

 

35,573

 

Income taxes payable

 

114

 

1,164

 

Obligations on forward fixed contracts and other derivatives

 

57

 

 

Total current liabilities

 

249,349

 

447,790

 

 

 

 

 

 

 

Revolving line of credit—less current portion

 

69,900

 

82,000

 

Notes payable, other—less current portion

 

1,162

 

1,239

 

Accrued pension benefit cost

 

3,431

 

3,170

 

Deferred compensation

 

1,342

 

1,429

 

Other long-term liabilities

 

20

 

20

 

Total liabilities

 

325,204

 

535,648

 

 

 

 

 

 

 

Partners’ equity

 

 

 

 

 

Common unitholders (5,642,424 units issued and outstanding at March 31, 2007 and December 31, 2006)

 

117,754

 

104,212

 

Subordinated unitholders (5,642,424 units issued and outstanding at March 31, 2007 and December 31, 2006)

 

(130

)

(13,672

)

General partner interest (2% interest with 230,303 equivalent units outstanding at March 31, 2007 and December 31, 2006)

 

(8

)

(560

)

Accumulated other comprehensive income

 

370

 

13,259

 

Total partners’ equity

 

117,986

 

103,239

 

Total liabilities and partners’ equity

 

$

443,190

 

$

638,887

 

 

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

1




 

GLOBAL PARTNERS LP
CONSOLIDATED STATEMENTS OF INCOME
(In thousands, except per unit data)
(Unaudited)

 

 

Three Months Ended

 

 

 

March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Sales

 

$

1,573,176

 

$

1,351,023

 

Cost of sales

 

1,530,924

 

1,318,806

 

Gross profit

 

42,252

 

32,217

 

 

 

 

 

 

 

Costs and operating expenses:

 

 

 

 

 

Selling, general and administrative expenses

 

13,406

 

10,928

 

Operating expenses

 

5,890

 

5,551

 

Amortization expenses

 

358

 

406

 

Total costs and operating expenses

 

19,654

 

16,885

 

 

 

 

 

 

 

Operating income

 

22,598

 

15,332

 

 

 

 

 

 

 

Interest expense

 

(3,316

)

(2,320

)

Other income

 

 

356

 

Gain on sale of investment

 

14,118

 

 

 

 

 

 

 

 

Income before income tax expense

 

33,400

 

13,368

 

 

 

 

 

 

 

Income tax expense

 

(525

)

(680

)

 

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

 

 

 

 

 

 

Less:

 

 

 

 

 

General partner’s interest in net income

 

(657

)

(254

)

Limited partners’ interest in net income

 

$

32,218

 

$

12,434

 

 

 

 

 

 

 

Net income per limited partner unit, basic and diluted(1)

 

$

1.75

 

$

0.85

 

 

 

 

 

 

 

Weighted average limited partners’ units outstanding, basic and diluted

 

11,285

 

11,285

 


(1)             See Note 3 for net income per limited partner unit calculation.

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

2




 

GLOBAL PARTNERS LP
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Operating activities

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation and amortization

 

1,164

 

966

 

Amortization of deferred financing fees

 

105

 

106

 

Loss on disposition of property and equipment and other

 

(1

)

11

 

Gain on sale of investment

 

(14,118

)

 

Changes in operating assets and liabilities:

 

 

 

 

 

Accounts receivable

 

(35,852

)

57,435

 

Accounts receivable—affiliate

 

138

 

(175

)

Inventories

 

145,759

 

110,161

 

Broker margin deposits

 

(753

)

4,441

 

Prepaid expenses, all other current assets and other assets

 

8,714

 

1,339

 

Accounts payable

 

(49,329

)

(128,487

)

Income taxes payable

 

(1,051

)

(521

)

Accrued expenses and all other current liabilities

 

(13,095

)

(1,375

)

Change in fair value of forward fixed contracts

 

66,172

 

 

Net cash provided by operating activities

 

140,728

 

56,589

 

 

 

 

 

 

 

Investing activities

 

 

 

 

 

Proceeds from sale of investment

 

15,262

 

 

Maintenance capital expenditures

 

(767

)

(104

)

Capital improvement expenditures

 

(74

)

(744

)

Terminal pre-acquisition deposit and other costs

 

(4,708

)

 

Proceeds from sale of property and equipment

 

2

 

19

 

Net cash provided by (used in) investing activities

 

9,715

 

(829

)

 

 

 

 

 

 

Financing activities

 

 

 

 

 

Payments on revolving line of credit, net

 

(147,000

)

(51,900

)

Payments on note payable, other

 

(78

)

(73

)

Distributions to partners

 

(5,239

)

(4,733

)

Net cash used in financing activities

 

(152,317

)

(56,706

)

 

 

 

 

 

 

Decrease in cash and cash equivalents

 

(1,874

)

(946

)

Cash and cash equivalents at beginning of period

 

3,861

 

1,769

 

Cash and cash equivalents at end of period

 

$

1,987

 

$

823

 

 

 

 

 

 

 

Supplemental information

 

 

 

 

 

Cash paid during the period for interest

 

$

3,422

 

$

2,332

 

 

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

3




 

GLOBAL PARTNERS LP
CONSOLIDATED STATEMENTS OF PARTNERS’ EQUITY
(In thousands)
(Unaudited)

 

 

 

 

 

 

 

 

Accumulated

 

 

 

 

 

 

 

 

 

General

 

Other

 

Total

 

 

 

Common

 

Subordinated

 

Partner

 

Comprehensive

 

Partners’

 

 

 

Unitholders

 

Unitholders

 

Interest

 

Income

 

Equity

 

Balance December 31, 2006

 

$

104,212

 

$

(13,672

)

$

(560

)

$

13,259

 

$

103,239

 

Comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

Net income

 

16,109

 

16,109

 

657

 

 

32,875

 

Other comprehensive income:

 

 

 

 

 

 

 

 

 

 

 

Unrealized gain on NYMEX shares

 

 

 

 

(12,837

)

(12,837

)

Adjustment—SFAS No. 158

 

 

 

 

(52

)

(52

)

Total other comprehensive income

 

16,109

 

16,109

 

657

 

(12,889

)

(19,986

)

Distributions to partners

 

(2,567

)

(2,567

)

(105

)

 

(5,239

)

Balance March 31, 2007

 

$

117,754

 

$

(130

)

$

(8

)

$

370

 

$

117,986

 

 

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

4




 

GLOBAL PARTNERS LP
NOTES TO FINANCIAL STATEMENTS
(Unaudited)

Note 1.                      Organization and Basis of Presentation

Organization

Global Partners LP (the “Partnership”) is a publicly traded master limited partnership that engages in the wholesale and commercial distribution of refined petroleum products and small amounts of natural gas and provides ancillary services to companies domestically and, on a limited basis, internationally.

The Partnership has four operating subsidiaries:  Global Companies LLC, its subsidiary, Glen Hes Corp., Global Montello Group Corp. and Chelsea Sandwich LLC (the four operating subsidiaries, collectively, the “Companies”).  The Companies (other than Glen Hes Corp.) are wholly owned by Global Operating LLC, a wholly owned subsidiary of the Partnership.  In addition, in January 2007, GLP Finance Corp. (“GLP Finance”) was incorporated under the laws of the State of Delaware and became a wholly owned subsidiary of the Partnership.  GLP Finance has no material assets or liabilities.  Its activities will be limited to co-issuing debt securities and engaging in other activities incidental thereto.

In May of 2007, the Partnership issued 1,785,715 unregistered Class B units in a private placement.  The Partnership received proceeds of $50.0 million.  The Class B units are convertible into common units on a one-for-one basis upon the approval of a majority of the votes cast by common unitholders, provided that the total number of votes cast is at least a majority of common units eligible to vote (excluding common units held by Global GP LLC, the Partnership’s general partner (the “General Partner”), and its affiliates).  In addition, the Class B units are convertible into common units on a one-for-one basis if the New York Stock Exchange amends its requirements to eliminate the common unitholder approval requirement.  In connection with the issuance of the Class B units, the Partnership agreed to a discount in the purchase price of approximately $0.8 million, which is the amount equal to the product of (i) the number of issued and outstanding Class B units, times (ii) $0.4650, the amount of the Partnership’s first quarter per unit distribution to be paid to the common and subordinated unitholders on May 15, 2007.  Such discount will be paid by the Partnership to the purchasers of the Class B units substantially contemporaneously with the payment of the Partnership’s first quarter distribution.  As the issuance of the Class B units and related transactions occurred in May of 2007, they are not reflected in the accompanying financial statements for the three months ended March 31, 2007.

Also in May of 2007, the Partnership completed its previously announced acquisition of three contiguous refined petroleum product terminals from ExxonMobil Oil Corporation for cash consideration of approximately $101.5 million.  The Partnership financed the acquisition through an expansion of its credit facility, proceeds from the sale of its NYMEX Holdings shares and related NYMEX seats and the $50.0 million private placement of Class B units discussed above.  As the acquisition of these three terminals and related transactions occurred in May of 2007, they are not reflected in the accompanying financial statements for the three months ended March 31, 2007.

As of May 9, 2007, the Partnership’s 1.73% general partner interest is held by the General Partner.  The General Partner, which is owned by affiliates of the Slifka family, manages the Partnership’s operations and activities and employs its officers and substantially all of its personnel.  Affiliates of the General Partner, including its directors and executive officers, own 60,224 common units and 5,642,424 subordinated units, representing a combined 42.9% limited partner interest.

Basis of Presentation

Interim Financial Statements

The accompanying consolidated financial statements as of March 31, 2007 and December 31, 2006 and for the three months ended March 31, 2007 and 2006 reflect the accounts of the Partnership.  All intercompany balances and transactions have been eliminated.

5




 

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 only 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, 2006 and notes thereto contained in the Partnership’s Annual Report on Form 10-K.  The results of operations for the three months ended March 31, 2007 are not necessarily indicative of the results of operations that will be realized for the entire year ending December 31, 2007.

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, sales are generally higher during the first and fourth quarters of the calendar year which may result in significant fluctuations in the Partnership’s quarterly operating results.

The balance sheet at December 31, 2006 has been derived from the audited financial statements and footnotes thereto included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2006.

Note 2.                      Reclassification

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

Note 3.                      Net Income Per Limited Partner Unit

The computation of net income per limited partner unit is based on the weighted average number of common and subordinated units, or limited partner units, outstanding during the year.  Basic and diluted net income per limited partner unit are determined by dividing net income after deducting the amount allocated to the general partner interest (including incentive distributions on the incentive distribution rights held by the General Partner in excess of its 2% general partner interest) by the weighted average number of outstanding limited partner units during the period in accordance with Emerging Issues Task Force (“EITF”) 03-06, “Participating Securities and the Two-Class Method under FASB Statement No. 128” (“EITF 03-06”).  EITF 03-06 addresses the computation of earnings per share (in the Partnership’s case, net income per limited partner unit) by an entity that has issued securities other than common stock (in the Partnership’s case, limited partner units) that contractually entitle the holder to participate in dividends and earnings of the entity when, and if, it declares dividends on its common stock (in the Partnership’s case, distributions on its limited partner units).  Essentially, EITF 03-06 provides that in any accounting period where the Partnership’s aggregate net income exceeds its aggregate distribution for such period, the Partnership is required to present net income per limited partner unit as if all of the earnings for the periods were distributed, regardless of whether those earnings would actually be distributed during a particular period from an economic or practical perspective.  EITF 03-06 does not impact the Partnership’s overall net income or other financial results; however, for periods in which the Partnership’s aggregate net income exceeds its aggregate distributions for such period, it will have the impact of reducing the earnings per limited partner unit.  This result occurs as a larger portion of the Partnership’s aggregate earnings is allocated to the incentive distribution rights held by the General Partner, as if distributed, even though the Partnership makes cash distributions on the basis of cash available for distributions, not earnings, in any given accounting period.  In accounting periods where aggregate net income does not exceed aggregate distributions for such period, EITF 03-06 does not have any impact on the Partnership’s net income per limited partner unit calculation.

6




 

The following sets forth the net income allocation and per unit data using this method for the periods presented (in thousands, except per unit data):

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

Less:

 

 

 

 

 

General Partner’s 2% general partner interest

 

(657

)

(254

)

Net income available to limited partners

 

32,218

 

12,434

 

Dilutive impact of theoretical distribution of earnings

 

(12,405

)

(2,872

)

Net income available to limited partners under EITF 03-06

 

$

19,813

 

$

9,562

 

 

 

 

 

 

 

 

 

 

 

 

 

Per unit data:

 

 

 

 

 

Net income available to limited partners

 

$

2.85

 

$

1.10

 

Dilutive impact of theoretical distribution of earnings

 

(1.10

)

(0.25

)

Net income available to limited partners under EITF 03-06

 

$

1.75

 

$

0.85

 

 

 

 

 

 

 

Weighted average limited partner units outstanding

 

11,285

 

11,285

 

 

During the three months ended March 31, 2007 and 2006, the Partnership did not declare cash distributions that resulted in incentive distributions to the General Partner, as the holder of the incentive distribution rights, as indicated above.  On April 24, 2007, the board of directors of the General Partner declared a quarterly cash distribution of $0.4650 per unit for the period from January 1, 2007 through March 31, 2007.  This distribution resulted in the Partnership reaching its second target distribution with respect to the incentive distribution rights held by the General Partner for the quarter ended March 31, 2007.  See Note 9, “Cash Distributions” for further information.

Note 4.                      Inventories

The Partnership hedges substantially all of its inventory purchases through futures and swap agreements.  Hedges are executed when inventory is purchased and are identified with that specific inventory.  Changes in the fair value of these contracts, as well as the offsetting gain or loss on the hedged inventory item, are recognized currently in earnings.  All hedged inventory is valued using the lower of cost, as determined by specific identification, or market.  Prior to sale, hedges are removed from specific barrels of inventory, and the then unhedged inventory is sold and accounted for on a first-in, first-out basis.  Inventories consisted of the following (in thousands):

 

 

March 31,
2007

 

December 31,
2006

 

 

 

 

 

 

 

Distillates: home heating oil, diesel and kerosene

 

$

91,657

 

$

235,266

 

Residual oil

 

19,524

 

35,226

 

Gasoline

 

23,319

 

9,870

 

Blend stock

 

7,808

 

7,705

 

Total

 

$

142,308

 

$

288,067

 

 

The decrease of $145.8 million was primarily due to lower distillates and residual oil inventory on hand as the Partnership approached the end of its heating season.

7




 

In addition to its own inventory, the Partnership has exchange agreements 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.  Negative exchange balances are accounted for as accounts payable.  Exchange transactions are valued using current quoted market prices.  The impact of exchange agreements was not material to the Partnership’s financial statements at March 31, 2007 and December 31, 2006.

Note 5.                      Derivative Financial Instruments

The Partnership accounts for its derivatives in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended (“SFAS No. 133”).  SFAS No. 133 establishes accounting and reporting standards for derivative instruments and hedging activities and requires that an entity recognize derivatives as either assets or liabilities on the balance sheet and measure the instruments at fair value.  Changes in the fair value of the derivative are to be recognized currently in earnings, unless specific hedge accounting criteria are met.

The fair value of the Partnership’s derivatives is determined through the use of independent markets and is based upon the prevailing market prices of such instruments at the date of valuation.  The Partnership enters into futures contracts for the receipt or delivery of refined petroleum products in future periods.  The contracts are entered into in the normal course of business to reduce risk of loss of inventory on hand, which could result through fluctuations in market prices.  Changes in the fair value of these contracts, as well as the offsetting gain or loss on the hedged inventory item, are recognized currently in earnings.  Ineffectiveness related to these hedging activities was immaterial at March 31, 2007.

The Partnership also uses futures contracts and swaps to hedge exposure under forward purchase and sale commitments.  These agreements are intended to hedge the cost component of virtually all of the Partnership’s forward commitments.  Changes in the fair value of these contracts, as well as offsetting gains or losses on the forward fixed purchase and sale commitments, are recognized currently in earnings.  Gains and losses on net product margin from forward fixed purchase and sale contracts are reflected in earnings as these contracts mature.

The composition and fair value of derivative instruments relating to forward fixed contracts on the Partnership’s balance sheet consisted of the following (in thousands):

 

March 31,
2007

 

December 31,
2006

 

 

 

 

 

 

 

Futures contracts

 

$

(12

)

$

57,571

 

Swaps, options and other, net

 

(45

)

8,544

 

 

 

$

(57

)

$

66,115

 

 

The Partnership also markets and sells natural gas.  The Partnership generally conducts business by entering into forward purchase commitments for natural gas only when it simultaneously enters into arrangements for the sale of product for physical delivery to third-party users.  The Partnership generally takes delivery under its purchase commitments at the same location as it delivers to third-party users.  Through these transactions, which establish an immediate margin, the Partnership seeks to maintain a position that is substantially balanced between firm forward purchase and sales commitments.  Natural gas is generally purchased and sold at fixed prices and quantities.  Current price quotes from actively traded markets are used in all cases to determine the contracts’ fair value.  Changes in the fair value of these contracts are recognized currently in earnings as an increase or decrease in cost of sales.

8




 

The Partnership formally documents all relationships between hedging instruments and hedged items after its risk management objectives and strategy for undertaking the hedge are determined.  The Partnership calculates hedge effectiveness on a quarterly basis.  This process includes specific identification of the hedging instrument and the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness will be assessed.  Both at the inception of the hedge and on an ongoing basis, the Partnership assesses whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in fair value of hedged items.  The derivative instruments that qualify for hedge accounting are fair value hedges.

The Partnership has a daily margin requirement with its broker based on the prior day’s market results on open futures contracts.  The required brokerage margin balance was $1.4 million and $0.6 million at March 31, 2007 and December 31, 2006, respectively.

The Partnership is exposed to credit loss in the event of nonperformance by counterparties of forward contracts, options and swap agreements, but the Partnership has no current reason to expect any material nonperformance by any of these counterparties.  Futures contracts, the primary derivative instrument utilized by the Partnership, are traded on regulated exchanges, greatly reducing potential credit risks.  Exposure on swap and certain option agreements is limited to the amount of the recorded fair value as of the balance sheet dates.  The Partnership utilizes primarily one broker, a major financial institution, for all derivative transactions and the right of offset exists.  Accordingly, the fair value of all derivative instruments is displayed on a net basis on the balance sheets.

Note 6.                      Debt

In August 2006, the Partnership amended its four-year senior secured credit agreement (the “Credit Agreement”) to increase the permanent working capital revolving credit facility commitment by $100.0 million for total available commitments of $600.0 million.  At March 31, 2007, there were three facilities under the Credit Agreement that included the following:

·              a working capital revolving credit facility to be used for working capital purposes and letters of credit in the principal amount equal to the lesser of the Partnership’s borrowing base and $550.0 million, of which two $50.0 million seasonal overline facilities are available each year only during the period between September 1st and June 30th;

·              a $35.0 million acquisition facility to be used for funding acquisitions similar to the Partnership’s business line that have a purchase price of $25.0 million or less or $35.0 million or less in the aggregate in any 12-month period; and

·              a $15.0 million revolving credit facility to be used for general purposes, including payment of distributions to the Partnership’s unitholders.

At March 31, 2007, borrowings under the Partnership’s working capital revolving credit, acquisition and revolving credit facilities bore interest at the Partnership’s option at (1) the Eurodollar rate, plus 1%, 1¾% and 1½%, respectively, (2) the cost of funds rate, plus 1%, 1¾% and 1½%, respectively, or (3) the bank’s base rate.  The Partnership incurs a letter of credit fee of 1% per annum for each letter of credit issued.  In addition, the Partnership incurs a commitment fee on the unused portion of the three facilities under the Credit Agreement (including the unused portion of either of the seasonal overline facilities exercised by the Partnership) at a rate of 25 basis points per annum, a facility fee of 10 basis points per annum on any unexercised seasonal overline facility during the period between September 1st and June 30th and a seasonal overline fee of $30,000 each time the Partnership elects to exercise either of the seasonal overline facilities.

9




 

The Partnership classifies a portion of its revolving line of credit as a long-term liability because the Partnership has a multi-year, long-term commitment from its bank group.  The long-term portion of the revolving line of credit was $69.9 million and $82.0 million at March 31, 2007 and December 31, 2006, respectively, representing the amounts expected to be outstanding during the year.  In addition, the Partnership classifies a portion of its revolving line of credit as a current liability because it repays amounts outstanding and reborrows funds based on its working capital requirements.  The current portion of the revolving line of credit was approximately $53.8 million and $188.7 million at March 31, 2007 and December 31, 2006, respectively, representing the amount the Partnership expects to pay down during the course of the year.

At March 31, 2007, availability under the Credit Agreement was reduced by the outstanding balance under the working capital revolving credit facility of approximately $123.7 million and by letters of credit totaling approximately $45.2 million.  The average interest rate for the three months ended March 31, 2007 was 6.3%.

The Credit Agreement is secured by substantially all of the assets of the Partnership and each of the Companies and is guaranteed by the General Partner.  The Credit Agreement imposes certain requirements including, for example, a prohibition against distributions if any potential default or event of default as defined in the Credit Agreement, as amended, would occur, and 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 also imposes covenants that require the Partnership to maintain certain minimum working capital amounts, capital expenditure limits, a minimum EBITDA ratio, a minimum interest coverage ratio and a maximum leverage ratio.  The Partnership was in compliance with these covenants at March 31, 2007.

The Credit Agreement limits distributions by the Partnership to its unitholders to the amount of the Partnership’s available cash and permits borrowings to fund such distributions only under the $15.0 million revolving credit facility.  The revolving credit facility is subject to an annual “clean-down” period, requiring the Partnership to reduce the amount outstanding under the revolving credit facility to $0 for 30 consecutive calendar days in each calendar year.

As previously disclosed in a Form 8-K filed by the Partnership on April 26, 2007, the Credit Agreement was amended to, among other things:

·              increase the Partnership’s $35.0 million acquisition facility by $50.0 million to $85.0 million;

·              possibly increase, at the request of the Partnership and provided that no Default or Event of Default (as defined in the Credit Agreement) then exists:  (1) the acquisition facility by up to another $50.0 million, for a total acquisition facility of up to $135.0 million; and (2) the working capital revolving credit facility by up to another $100.0 million, for a total working capital revolving credit facility of up to $650.0 million.  Any such request for an increase by the Partnership must be in a minimum amount of $5.0 million, and no more than three such requests may be made for each facility;

·              extend the term of the Credit Agreement to April 22, 2011;

·              reduce the margins that are added to the Eurodollar rate for interest on indebtedness under the Credit Agreement from a range of 1.00% to 1.75% per annum to a range of 1.00% to 1.50% per annum, depending on which facility is being used;

10




 

·              reduce the minimum EBITDA (as defined in the Credit Agreement) to interest coverage ratio from 2.75:1:00 to 2.50:1.00; and

·              increase the threshold amount in excess of which the Partnership and guarantors are not permitted to make or to become legally obligated to make aggregate permitted capital expenditures in any fiscal year from $4.0 million to $10.0 million.

Note 7.                      Employee Benefit Plan with Related Party

The General Partner employs substantially all of the Partnership’s employees and charges the Partnership for their services.  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 Partnership’s net periodic benefit cost for its defined benefit pension plan consisted of the following components (in thousands):

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Service cost

 

$

204

 

$

191

 

Interest cost

 

163

 

150

 

Expected return on plan assets

 

(158

)

(145

)

Net periodic benefit cost

 

$

209

 

$

196

 

 

Note 8.                      Related Party Transactions

The Partnership entered into a Second Amended and Restated Terminal Storage Rental and Throughput Agreement which, among other things, extended the term of the then current non-cancelable terminal facility agreement with Global Petroleum Corp. (“GPC”) through December 2013.  The agreement is accounted for as an operating lease.  The expenses under this agreement were $2.1 million and $2.0 million for the three months ended March 31, 2007 and 2006, respectively.

Pursuant to the Amended and Restated Services Agreement with GPC, GPC provides certain terminal operating management services to the Partnership and uses certain administrative, accounting and information processing services of the Partnership.  The expense from these services was approximately $18,000 and $17,000 for the three months ended March 31, 2007 and 2006, respectively.  These affiliate charges were recorded in selling, general and administrative expenses in the accompanying statements of income.  The agreement is for an indefinite term, and either party may terminate its receipt of some or all of the services thereunder upon 180 day’s notice at any time after January 1, 2008.

Pursuant to the Amended and Restated Services Agreement, the Partnership also provides certain administrative, accounting and information processing services, and the use of certain facilities, to Alliance Energy Corp. (“Alliance”), an affiliate of the Partnership that is 90% owned by members of the Slifka family.  The income from these services was approximately $132,000 and $80,000 for the three months ended March 31, 2007 and 2006, respectively.  These intercompany fees were recorded as an offset to selling, general and administrative expenses in the accompanying statements of income.  The agreement is for an indefinite term, and Alliance may terminate its receipt of some or all of the services thereunder upon 180 day’s notice at any time after January 1, 2008.

The Partnership sells refined petroleum products to Alliance at arm’s length and at prevailing market prices at the time of delivery.  Sales to Alliance were $5.8 million and $5.0 million for the three months ended March 31, 2007 and 2006, respectively.

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The General Partner employs substantially all of the Partnership’s employees and charges the Partnership for their services.  The expenses for the three months ended March 31, 2007 and 2006, including payroll, payroll taxes and bonus accruals, were $8.3 million and $6.7 million, 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 Alliance, receivables incurred in connection with the services agreements between Alliance and GPC and the Partnership, as the case may be, and receivables from the General Partner (in thousands):

 

March 31, 2007

 

December 31,
2006

 

 

 

 

 

 

 

Receivables from Alliance

 

$

1,628

 

$

1,793

 

Receivables from GPC

 

43

 

81

 

Receivables from the General Partner (1)

 

178

 

114

 

Total

 

$

1,849

 

$

1,988

 


(1)             Receivables from the General Partner reflect the Partnership’s prepayment of payroll taxes and payroll accruals to the General Partner.

Note 9.                      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 cash flows, 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 at the end of the quarter; plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of 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 to the General Partner for any one or more of the next four quarters.  Working capital borrowings are generally borrowings that are made under the Credit Agreement and in all cases are used solely for working capital purposes or to pay distributions to partners.

The Partnership will make distributions of available cash from operating surplus for any quarter during the subordination period as defined in its partnership agreement in the following manner: firstly, 98% to the common unitholders, pro rata, and 2% to the General Partner, until the Partnership distributes for each outstanding common unit an amount equal to the minimum quarterly distribution for that quarter; secondly, 98% to the common unitholders, pro rata, and 2% to the General Partner, until the Partnership distributes for each outstanding common unit an amount equal to any arrearages in payment of the minimum quarterly distribution on the common units for any prior quarters during the subordination period; thirdly, 98% to the subordinated unitholders, pro rata, and 2% to the General Partner, until the Partnership distributes for each subordinated unit an amount equal to the minimum quarterly distribution for that quarter; and thereafter, cash in excess of the minimum quarterly distributions is distributed to the unitholders and the General Partner based on the percentages as provided below.

12




 

As the holder of the incentive distribution rights, 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:

 

 

Total Quarterly Distribution

 

Marginal Percentage Interest in
Distributions

 

 

Target Amount

 

Unitholders

 

General Partner

Minimum Quarterly Distribution

 

$0.4125

 

98%

 

2%

First Target Distribution

 

Up to $0.4625

 

98%

 

2%

Second Target Distribution

 

above $0.4625 up to $0.5375

 

85%

 

15%

Third Target Distribution

 

above $0.5375 up to $0.6625

 

75%

 

25%

Thereafter

 

above $0.6625

 

50%

 

50%

 

The Partnership paid the following cash distribution during 2007 (in thousands, except per unit data):

Cash Distribution Payment Date

 

Per Unit
Cash
Distribution

 

Common
Units

 

Subordinated
Units

 

General
Partner

 

Total Cash
Distribution

 

02/14/07

 

$

0.4550

 

$

2,567

 

$

2,567

 

$

105

 

$

5,239

 

 

In addition, on April 24, 2007, the board of directors of the General Partner declared a quarterly cash distribution of $0.4650 per unit for the period from January 1, 2007 through March 31, 2007 ($1.86 per unit on an annualized basis) to the Partnership’s common and subordinated unitholders of record as of the close of business May 4, 2007.  This distribution resulted in the Partnership reaching its second target distribution for the quarter ended March 31, 2007.

Note 10.               Segment Reporting

The Partnership is a wholesale and commercial distributor of gasoline, distillates and residual oil whose business is organized within two operating segments, Wholesale and Commercial, based on the way the chief operating decision maker (CEO) manages the business and on the similarity of customers and expected long-term financial performance of each segment.  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, 2006.

In the Wholesale segment, the Partnership sells gasoline, home heating oil, diesel, kerosene and residual oil to unbranded retail gasoline stations and other resellers of transportation fuels, home heating oil retailers and wholesale distributors.  Generally, customers use their own vehicles or contract carriers to take delivery of the product at bulk terminals and inland storage facilities that the Partnership owns or controls or with which it has throughput arrangements.

The Commercial segment includes (1) sales and deliveries of unbranded gasoline, home heating oil, diesel, kerosene and residual oil and small amounts of natural gas to customers in the public sector and to large commercial and industrial customers, either through a competitive bidding process or through contracts of various terms, and (2) sales of custom blended distillates and residual oil delivered by barges or from a terminal dock.  Commercial segment customers include federal and state agencies, municipalities, large industrial companies, many autonomous authorities such as transportation authorities and water resource authorities, colleges and universities and a limited group of small utilities.  Unlike the Wholesale segment, in the Commercial segment, the Partnership generally arranges the delivery of the product to the customer’s designated location, typically hiring third-party common carriers to deliver the product.

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The Partnership evaluates segment performance based on net product margins before allocations of corporate and indirect operating costs, depreciation, amortization (including non-cash charges) and interest.  Based on the way the CEO manages the business, it is not reasonably possible for the Partnership to allocate the components of operating costs and expenses between the reportable segments.  Additionally, due to the commingled nature and uses of the Partnership’s assets, it is not reasonably possible for the Partnership to allocate assets between the two segments.  There were no intersegment sales for any of the periods presented below.

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

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Wholesale Segment:

 

 

 

 

 

Sales

 

$

1,440,610

 

$

1,196,979

 

Net product margin (1)

 

 

 

 

 

Distillates

 

$

26,741

 

$

19,597

 

Gasoline

 

1,618

 

3,236

 

Residual oil

 

9,884

 

4,654

 

Total

 

$

38,243

 

$

27,487

 

Commercial Segment:

 

 

 

 

 

Sales

 

132,566

 

154,044

 

Net product margin (1)

 

4,600

 

5,136

 

Combined sales and net product margin:

 

 

 

 

 

Sales

 

$

1,573,176

 

$

1,351,023

 

Net product margin (1)

 

$

42,843

 

$

32,623

 

Depreciation allocated to cost of sales

 

591

 

406

 

Combined gross profit

 

$

42,252

 

$

32,217

 


(1)             Net product margin is a non-GAAP financial measure used by management and external users of the Partnership’s financial statements to assess the Partnership’s business.  The table above reconciles net product margin on a combined basis to gross profit, a directly comparable GAAP measure.

14




 

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):

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Combined gross profit

 

$

42,252

 

$

32,217

 

Operating costs and expenses not allocated to reportable segments:

 

 

 

 

 

Selling, general and administrative expenses

 

13,406

 

10,928

 

Operating expenses

 

5,890

 

5,551

 

Amortization expenses

 

358

 

406

 

Total operating costs and expenses

 

19,654

 

16,885

 

Operating income

 

22,598

 

15,332

 

Interest expense

 

(3,316

)

(2,320

)

Other income

 

 

356

 

Gain on sale of investment

 

14,118

 

 

Income tax expense

 

(525

)

(680

)

Net income

 

$

32,875

 

$

12,688

 

 

There were no foreign sales for the three months ended March 31, 2007 and 2006.  The Partnership has no foreign assets.

Note 11.               Capital Expenditures

The Partnership’s terminalling operations require investments to expand, upgrade or enhance existing operations and to meet environmental and operations regulations.  The Partnership’s capital requirements primarily consist of maintenance capital expenditures and capital improvement expenditures.  Maintenance capital expenditures represent capital expenditures to replace partially or fully depreciated assets to maintain the operating capacity of, or sales generated by, existing assets and extend their useful lives such as expenditures required to maintain equipment reliability, tankage and pipeline integrity and safety, and to address environmental regulations.  The Partnership had approximately $0.8 million and $0.1 million in maintenance capital expenditures for the three months ended March 31, 2007 and 2006, respectively.  Repair and maintenance expenses associated with existing assets that are minor in nature and do not extend the useful life of existing assets are charged to operating expenses as incurred.

Capital improvement expenditures include expenditures to acquire assets to grow the Partnership’s business and to expand existing facilities, such as projects that increase operating capacity by increasing tankage or adding terminals.  The Partnership had approximately $0.1 million and $0.7 million in capital improvement expenditures for the three months ended March 31, 2007 and 2006, respectively, to increase its operating capacity and capabilities.

15




 

Note 12.               Investment in Equity Securities

The Partnership held an investment in NYMEX Holdings, Inc. which was accounted for under the provisions of SFAS No. 115, “Accounting for Certain Investments in Debt and Equity Securities.”  At December 31, 2006, the Partnership recorded the investment at a fair value of $13.9 million, based on its quoted market price, and classified the security as available for sale in the accompanying balance sheet.  The Partnership’s unrealized gain of $12.8 million was recorded in other comprehensive income.  Additionally, the Partnership recorded related dividend income of $356,000 in the accompanying statements of income for the three months ended March 31, 2006.

On March 6, 2007, the Partnership sold its investment in NYMEX Holdings, Inc. along with its NYMEX seats for approximately $15.3 million and realized a gain of approximately $14.1 million in the statement of income for the quarter ended March 31, 2007.

Note 13.               Income Taxes

Global Montello Group Corp. is a taxable entity for federal and state income tax purposes.  Current and deferred income taxes are recognized on the separate earnings of Global Montello Group Corp. for the three months ended March 31, 2007 and 2006.  The after-tax earnings of Global Montello Group Corp. 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 Global Montello Group Corp.

On January 1, 2007, the Partnership adopted the provisions of FASB issued Interpretation No. 48, “Accounting for Uncertainty in Income Taxes — an interpretation of FASB Statement No. 109” (“FIN 48”).  FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with SFAS No. 109, “Accounting for Income Taxes.”  It also prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return, and it provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition.

The Partnership performed an evaluation for the tax years ended December 31, 2006 and 2005, the tax years that remain subject to examination by major tax jurisdictions as of March 31, 2007.  Based on such evaluation, the Partnership concluded that there were no significant uncertain tax positions requiring recognition in its financial statements as of March 31, 2007.  As such, the adoption of FIN 48 did not impact the Partnership’s consolidated financial condition, results of operations or cash flows.

Note 14.               Recent Accounting Pronouncements

In September 2006, the FASB issued SFAS No. 157, “Fair Value Measurements” (“SFAS No. 157”).  This statement defines fair value, establishes guidelines for measuring fair value and requires additional disclosures regarding fair value measurements.  SFAS No. 157 applies only to fair value measurements currently required or permitted by other accounting standards and is expected to increase the consistency of those measurements.  SFAS No. 157 is effective for fiscal years beginning after November 15, 2007.  The Partnership will adopt this statement on January 1, 2008 and is in the process of evaluating the impact of SFAS No. 157 on its consolidated financial statements.

16




 

Note 15.               Subsequent Events

As previously disclosed in a Form 8-K filed on April 24, 2007, the General Partner’s board of directors declared a quarterly cash distribution of $0.4650 per unit for the period from January 1, 2007 through March 31, 2007 ($1.86 per unit on an annualized basis).  On May 15, 2007, the Partnership will pay this cash distribution to its common and subordinated unitholders of record as of the close of business May 4, 2007.

As previously disclosed in a Form 8-K filed on April 26, 2007, the Partnership and its subsidiaries, except for GLP Finance Corp., and the General Partner entered into a Third Amendment to Credit Agreement and Accession Agreement which amended the Credit Agreement dated October 4, 2005, as amended.

On May 9, 2007, the Partnership issued 1,785,715 unregistered Class B units in a private placement.  The Partnership received proceeds of $50.0 million.  The Class B units are convertible into common units on a one-for-one basis upon the approval of a majority of the votes cast by common unitholders, provided that the total number of votes cast is at least a majority of common units eligible to vote (excluding common units held by the Partnership’s general partner and its affiliates).  In addition, the Class B units are convertible into common units on a one-for-one basis if the New York Stock Exchange amends its requirements to eliminate the common unitholder approval requirement.  In connection with the issuance of the Class B units, the Partnership agreed to a discount in the purchase price of approximately $0.8 million, which is the amount equal to the product of (i) the number of issued and outstanding Class B units, times (ii) $0.4650, the amount of the Partnership’s first quarter per unit distribution to be paid to the common and subordinated unitholders on May 15, 2007.  Such discount will be paid by the Partnership to the purchasers of the Class B units substantially contemporaneously with the payment of the Partnership’s first quarter distribution.

Also in May of 2007, the Partnership completed its previously announced acquisition of three contiguous refined petroleum product terminals from ExxonMobil Oil Corporation for cash consideration of approximately $101.5 million.  The Partnership financed the acquisition through an expansion of its credit facility, proceeds from the sale of its NYMEX Holdings shares and related NYMEX seats and the $50.0 million private placement of Class B units discussed above.

On May 10, 2007, the Partnership executed an interest rate derivative contract. The purpose of the contract is to provide the Partnership protection against future interest rate increases with respect to $100.0 million of borrowings under the Partnership’s Credit Agreement. The effective date of the instrument is May 14, 2007 and it expires on the maturity date of the Partnership’s Credit Agreement.

17




 

Item 2.                          Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of financial condition and results of operations of Global Partners LP should be read in conjunction with the historical consolidated financial statements of Global Partners LP and the notes thereto included elsewhere in this Quarterly Report on Form 10-Q.

Forward-Looking Statements

This Quarterly Report on Form 10-Q contains certain forward-looking statements within the meaning of the federal securities laws.  These forward-looking statements are identified as any statements that do not relate strictly to historical or current facts and can generally be identified by the use of forward-looking terminology including “may,” “believe,” “expect,” “anticipate,” “estimate,” “continue” or other similar words.  Such statements may discuss future expectations for, or contain projections of, results of operations, financial condition or our ability to make distributions to unitholders or state other forward-looking information.  Forward-looking statements are not guarantees of performance.  Although we believe these forward-looking statements are based on reasonable assumptions, statements made regarding future results are subject to a number of assumptions, uncertainties and risks, many of which are beyond our control, which may cause future results to be materially different from the results stated or implied in this document.  These risks and uncertainties include, among other things:

·              We may not have sufficient cash from operations to enable us to pay the minimum quarterly distribution following establishment of cash reserves and payment of fees and expenses, including payments to our general partner.

·              Warmer weather conditions could adversely affect our results of operations and cash available for distribution to our unitholders.

·              Our risk management policies cannot eliminate all commodity risk.  In addition, any noncompliance with our risk management policies could result in significant financial losses.

·              We are exposed to trade credit risk in the ordinary course of our business activities.

·              Due to our lack of asset and geographic diversification, adverse developments in the terminals that we use or in our operating areas could reduce our ability to make distributions to our unitholders.

·              We are exposed to performance risk in our supply chain.

·              Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which may permit them to favor their own interests to the detriment of unitholders.

·              Unitholders have limited voting rights and are not entitled to elect our general partner or its directors or initially to remove our general partner without its consent, which could lower the trading price of our common units.

·              Unitholders may be required to pay taxes on their share of our income even if they do not receive any cash distributions from us.

Additional information about risks and uncertainties that could cause actual results to differ materially from forward-looking statements is contained in Part II, Item 1A, “Risk Factors.”

All forward-looking statements included in this Form 10-Q and all subsequent written or oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these cautionary statements.  The forward-looking statements speak only as of the date made, other than as required by law, and we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

18




 

Overview

General

We own, control or have access to one of the largest terminal networks of refined petroleum products in the Northeast.  We are one of the largest wholesale distributors of gasoline, distillates (such as home heating oil, diesel and kerosene) and residual oil to wholesalers, retailers and commercial customers in the Northeast.  During the first three months of 2007, we sold approximately $1.6 billion of refined petroleum products and small amounts of natural gas.

We purchase our refined petroleum products primarily from domestic and foreign refiners, traders and producers and sell these products in two segments, Wholesale and Commercial.  Like most independent marketers of refined petroleum products, we base our pricing on spot physical prices and routinely use the New York Mercantile Exchange (“NYMEX”) or derivatives to hedge our commodity risk inherent in buying and selling energy commodities.  Through the use of regulated exchanges or derivatives, we maintain a position that is substantially balanced between purchased volumes and sales volumes or future delivery obligations.  We earn a margin by selling the product for physical delivery to third parties.

Products and Operational Structure

Our products include gasoline, distillates and residual oil.  We sell gasoline to unbranded retail gasoline stations and resellers.  The distillates we sell are used primarily for fuel for trucks and off-road construction equipment and for space heating of residential and commercial buildings.  We sell residual oil to major housing units, such as public housing authorities, colleges and hospitals and large industrial facilities that use processed steam in their manufacturing processes.  In addition, we sell bunker fuel, which we can custom blend, to cruise ships, bulk carriers and fishing fleets.

Our business is divided into two segments:

·              Wholesale.  This segment includes sales of gasoline, distillates and residual oil to unbranded retail gasoline stations and other resellers of transportation fuels, home heating oil retailers and wholesale distributors.

·              Commercial.  This segment includes sales and deliveries of unbranded gasoline, distillates, residual oil and small amounts of natural gas to customers in the public sector and to large commercial and industrial customers, either through a competitive bidding process or through contracts of various terms.  This segment also purchases, custom blends, sells and delivers bunker fuel and diesel to cruise ships, bulk carriers and fishing fleets generally by barges.

Our business activities are substantially comprised of purchasing, terminalling, storing and selling refined petroleum products.  We believe that the combination of our terminalling and storage activities, together with our marketing activities, provides a balance that has a stabilizing effect on our results of operations and cash flow.  Our results of operations are less weather sensitive than they have been in the past.  The increase in the non-weather sensitive components of our business helps to partially offset the economic impact that warmer weather conditions may have on our home heating oil and residual oil sales.  In addition, substantial portions of our heating oil are sold on a forward fixed basis.  In a contango market (when product prices for future deliveries are higher than for current deliveries), we may use our storage capacity to improve our margins by storing products we have purchased at lower prices in the current month for delivery to customers at higher prices in future months.  In a backwardated market (when product prices for future deliveries are lower than for current deliveries) because of our high turnover of inventory, we are able to minimize our inventories and commodity risk while attempting to maintain or increase net product margins.

19




 

Outlook

This section identifies certain risks and certain economic or industry-wide factors that may affect our financial performance and results of operations in the future, both in the short-term and in the long-term.  Our results of operations and financial condition depend, in part, upon the following:

·              We commit substantial resources to pursuing acquisitions, though there is no certainty that we will successfully complete any acquisitions or receive the economic results we anticipate from completed acquisitions.  Consistent with our business strategy, we are continuously engaged in discussions with potential sellers of terminalling, storage and/or marketing assets and related businesses.  In an effort to prudently and economically leverage our asset base, knowledge base and skill sets, management has also expanded its efforts to pursue businesses that are closely related to or significantly intertwined with our existing lines of business.  Our growth may depend on our ability to make accretive acquisitions.  We may be unable to make such accretive acquisitions for a number of reasons, including, but not limited to, the following:  (1) we are unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them; (2) we are unable to raise financing for such acquisitions on economically acceptable terms; or (3) we are outbid by competitors.  In addition, we may consummate acquisitions that at the time of consummation we believe will be accretive, but that ultimately may not be accretive.  If any of these events were to occur, our future growth would be limited.  We can give no assurance that our current or future acquisition efforts will be successful or that any such acquisition will be completed on terms that are favorable to us.

·              Our financial results are generally better in the first and fourth quarters of the calendar year.  Demand for some refined petroleum products, specifically home heating oil and residual oil for space heating purposes, is generally higher during November through March than during April through October.  We obtain a significant portion of our sales during these winter months.  Therefore, our results of operations for the first and fourth calendar quarters are generally better than for the second and third quarters.  With lower cash flow during the second and third calendar quarters, we may be required to borrow money in order to pay the minimum quarterly distribution to our unitholders.

·              Warmer weather conditions could adversely affect our results of operations and financial condition.  Weather conditions generally have an impact on the demand for both home heating oil and residual oil.  Because we supply distributors whose customers depend on home heating oil and residual oil for space heating purposes during the winter, warmer-than-normal temperatures during the first and fourth calendar quarters in one or more regions in which we operate can decrease the total volume we sell and the gross profit realized on those sales.

·              Energy efficiency, new technology and alternative fuels, natural gas in particular, could reduce demand for our products.  Increased conservation and technological advances have adversely affected the demand for home heating oil and residual oil.  Consumption of residual oil has steadily declined over the last three decades.  We could face additional competition from alternative energy sources as a result of future government-mandated controls or regulation further promoting the use of cleaner fuels.  Due in part to support for conversion to natural gas on environmental grounds, some industrial residual oil users have switched to natural gas.  Those end users who are dual-fuel users have the ability to switch between residual oil and natural gas.  During a period of increasing residual oil prices relative to the prices of natural gas, dual-fuel customers may switch to natural gas or, over the long-term, may convert to natural gas.  Such switching or conversion could have an adverse effect on our results of operations and financial condition.

·              New, stricter environmental laws and regulations could significantly increase our costs, which could adversely affect our results of operations and financial condition.  Our operations are subject to federal, state and local laws and regulations regulating product quality specifications and other environmental matters.  The trend in environmental regulation is towards more restrictions and limitations on activities that may affect the environment.  Our business may be adversely affected by increased costs and liabilities resulting from such stricter laws and regulations.  We try to anticipate future regulatory requirements that might be imposed and plan accordingly to remain in compliance with changing environmental laws and regulations and to minimize the costs of such compliance.  However, there can be no assurances as to the timing and type of such changes in existing laws or the promulgation of new laws or the amount of any required expenditures associated therewith.

20




 

Results of Operations

Evaluating Our Results of Operations

Our management uses a variety of financial and operational measurements to analyze our performance.  These measurements include: (1) net product margin, (2) gross profit, (3) selling, general and administrative expenses (“SG&A”), (4) operating expenses, (5) heating degree days, (6) adjusted net income per diluted limited partner unit, (7) earnings before interest, taxes, depreciation and amortization (“EBITDA”), Adjusted EBITDA and net income as adjusted for one-time gains and (8) distributable cash flow.

Net Product Margin

We view net product margin as an important performance measure of the core profitability of our operations.  We review net product margin monthly for consistency and trend analysis.  We define net product margin as our sales minus product costs.  Sales include sales of unbranded gasoline, distillates, residual oil and natural gas.  Product costs include the cost of acquiring the refined petroleum products that we sell and all associated costs including shipping and handling costs to bring such products to the point of sale.  Net product margin is a non-GAAP financial measure used by management and external users of the Partnership’s financial statements to assess the Partnership’s business.

Gross Profit

We define gross profit as our sales minus product costs and terminal depreciation expense allocated to cost of sales.  Sales include sales of unbranded gasoline, distillates, residual oil and natural gas.  Product costs include the cost of acquiring the refined petroleum products that we sell and all associated costs to bring such products to the point of sale.

Selling, General and Administrative Expenses

Our SG&A expenses include marketing costs, corporate overhead, employee salaries and benefits, pension and 401(k) plan expenses, discretionary bonuses, non-interest financing costs, professional fees and information technology expenses.  Employee-related expenses including employee salaries, discretionary bonuses and related payroll taxes, and benefits, pension and 401(k) plan expenses are paid by our general partner which, in turn, is reimbursed for these expenses by us.

Operating Expenses

Operating expenses are costs associated with the operation of the terminals used in our business.  Lease payments and storage expenses, maintenance and repair, utilities, taxes, labor and labor-related expenses comprise the most significant portion of our operating expenses.  These expenses remain relatively stable independent of the volumes through our system but fluctuate slightly depending on the activities performed during a specific period.

Degree Day

A “degree day” is an industry measurement of temperature designed to evaluate energy demand and consumption.  Degree days are based on how far the average temperature departs from a human comfort level of 65°F.  Each degree of temperature above 65°F is counted as one cooling degree day, and each degree of temperature below 65°F is counted as one heating degree day.  Degree days are accumulated each day over the course of a year and can be compared to a monthly or a long-term (multi-year) average, or normal, to see if a month or a year was warmer or cooler than usual.  Degree days are officially observed by the National Weather Service and officially archived by the National Climatic Data Center.  For purposes of evaluating our results of operations, we use the normal heating degree day amount as reported by the National Weather Service at its Logan International Airport station in Boston, Massachusetts.

21




 

Adjusted Net Income Per Diluted Limited Partner Unit

We use adjusted net income per diluted limited partner unit to measure our financial performance on a per-unit basis.  Adjusted net income per diluted limited partner unit is defined as net income after adding back the theoretical amount allocated to the general partner’s interest as provided under EITF 03-06, “Participating Securities and the Two-Class Method under FASB Statement No. 128” (“EITF 03-06”), divided by the weighted average number of outstanding diluted common and subordinated units, or limited partner units, during the period.  Net income per diluted limited partner unit as dictated by EITF 03-06 is theoretical and pro forma in nature and does not reflect the economic probabilities of whether earnings for an accounting period would or could be distributed to unitholders.  The partnership agreement does not provide for the quarterly distribution of net income; rather, it provides for the distribution of available cash, which is a contractually defined term that generally means all cash on hand at the end of each quarter after establishment of sufficient cash reserves required to operate our business.  Accordingly, the distributions we historically paid and will pay in future periods are not impacted by net income per diluted limited partner unit as dictated by EITF 03-06.  However, adjusted net income per diluted limited partner unit is a non-GAAP financial measure and should not be considered as an alternative to net income per diluted limited partner unit or any other measure of financial performance presented in accordance with GAAP.  In addition, our adjusted net income per diluted limited partner unit may not be comparable to the adjusted net incomer per diluted limited partner unit or similarly titled measure of other companies.

EBITDA, Adjusted EBIDTA and Net Income as Adjusted for One-time Gains

EBITDA, adjusted EBITDA and net income as adjusted for one-time gains are used as supplemental financial measures by management and external users of our financial statements, such as investors, commercial banks and research analysts, to assess:

·              our compliance with certain financial covenants included in our debt agreements;

·              our financial performance without regard to financing methods, capital structure, income taxes or historical cost basis;

·              our ability to generate cash sufficient to pay interest on our indebtedness and to make distributions to our partners;

·              our operating performance and return on invested capital as compared to those of other companies in the wholesale marketing and distribution of refined petroleum products business, without regard to financing methods and capital structure; and

·              the viability of acquisitions and capital expenditure projects and the overall rates of return of alternative investment opportunities.

Adjusted EBITDA and net income as adjusted for one-time gains reflect the exclusion of the $14.1 million gain on investment in the first quarter of 2007.  EBITDA, adjusted EBITDA and net income as adjusted for one-time gains should not be considered an alternative to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.  EBITDA, adjusted EBITDA and net income as adjusted for one-time gains exclude some, but not all, items that affect net income, and these measures may vary among other companies.  Therefore, EBITDA, adjusted EBITDA and net income as adjusted for one-time gains may not be comparable to similarly titled measures of other companies.

Distributable Cash Flow

Distributable cash flow also is an important non-GAAP financial measure for our limited partners since it serves as an indicator of our success in providing a cash return on their investment.  Specifically, this financial measure indicates to investors whether or not we are generating cash flow at a level that can sustain or support an increase in our quarterly cash distribution.  Distributable cash flow is also a quantitative standard used by the investment community with respect to publicly traded partnerships.  However, distributable cash flow is a non-GAAP financial measure and should not be considered as an alternative to net income, cash flow from operations, or any other measure of financial performance presented in accordance with GAAP.  In addition, our distributable cash flow may not be comparable to distributable cash flow or similarly titled measures of other companies.

22




 

Three Months Ended March 31, 2007 and 2006

During the first quarter ended March 31, 2007, we experienced higher volumes in our transportation fuels and, aided in part by colder-than-normal temperatures, strong heating oil sales.  Additionally, we benefited from favorable market conditions that enabled us to achieve a higher net product margin in our wholesale residual oil business as compared to the same period in 2006.  For the quarter ended March 31, 2007 compared to the same period in 2006, prices for gasoline and distillates increased by approximately 9% and 1%, respectively, while prices for residual oil decreased by 3%.  Temperatures were 2% colder than normal for the three months ended March 31, 2007, as measured by aggregate heating degree days.

23




 

Key Performance Indicators

The following table provides a summary of some of the key performance indicators that may be used to assess our results of operations.  These comparisons are not necessarily indicative of future results (dollars in thousands, except per unit amounts):

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Net income as adjusted for one-time gains (1)

 

$

18,757

 

$

12,688

 

 

 

 

 

 

 

Adjusted net income per diluted limited partner unit (2)

 

$

2.85

 

$

1.10

 

 

 

 

 

 

 

Adjusted EBITDA (3)

 

$

23,867

 

$

16,760

 

 

 

 

 

 

 

Distributable cash flow (4)

 

$

19,259

 

$

13,656

 

 

 

 

 

 

 

Wholesale Segment:

 

 

 

 

 

Volume (gallons)

 

810,822

 

688,484

 

Sales

 

$

1,440,610

 

$

1,196,979

 

Net product margin (5)

 

 

 

 

 

Distillates

 

$

26,741

 

$

19,597

 

Gasoline

 

1,618

 

3,236

 

Residual oil

 

9,884

 

4,654

 

Total

 

$

38,243

 

$

27,487

 

Commercial Segment:

 

 

 

 

 

Volume (gallons)

 

95,550

 

109,479

 

Sales

 

132,566

 

154,044

 

Net product margin (5)

 

4,600

 

5,136

 

Combined sales and net product margin:

 

 

 

 

 

Sales

 

$

1,573,176

 

$

1,351,023

 

Net product margin (5)

 

$

42,843

 

$

32,623

 

Depreciation allocated to cost of sales

 

591

 

406

 

Combined gross profit

 

$

42,252

 

$

32,217

 

 

 

 

 

 

 

Weather conditions:

 

 

 

 

 

Normal heating degree days

 

2,870

 

2,870

 

Actual heating degree days

 

2,918

 

2,635

 

Variance from normal heating degree days

 

2

%

(8

%)

Variance from prior period actual heating degree days

 

11

%

(13

%)


(1)            Net income as adjusted for one-time gains is a non-GAAP financial measure which is discussed above under “Evaluating Our Operating Results.”  The table below presents a reconciliation of net income as adjusted for one-time gains to the most directly comparable GAAP financial measure.

(2)            Adjusted net income per diluted limited partner unit is a non-GAAP financial measure which is discussed above under “Evaluating Our Operating Results.”  The table below presents a reconciliation of adjusted net income per diluted limited partner unit to the most directly comparable GAAP financial measure.

(3)            Adjusted EBITDA is a non-GAAP financial measure which is discussed above under “Evaluating Our Operating Results.”  The table below presents reconciliations of Adjusted EBITDA to the most directly comparable GAAP financial measures.

(4)            Distributable cash flow is a non-GAAP financial measure which is discussed above under “Evaluating Our Operating Results.”  The table below presents reconciliations of distributable cash flow to the most directly comparable GAAP financial measures.

(5)            Net product margin is a non-GAAP financial measure which is discussed above under “Evaluating Our Operating Results.”  The table above reconciles net product margin on a combined basis to gross profit, a directly comparable GAAP financial measure.

24




 

The following table presents a reconciliation of net income as adjusted for one-time gains to the most directly comparable GAAP financial measure on a historical basis for each period presented:

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Reconciliation of net income to net income as adjusted for one-time gains:

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

Gain on sale of investment

 

(14,118

)

 

Net income as adjusted for one-time gains

 

$

18,757

 

$

12,688

 

 

The following table presents a reconciliation of adjusted net income per diluted limited partner unit to the most directly comparable GAAP financial measure on a historical basis for each period presented:

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Reconciliation of net income per diluted limited partner unit to adjusted net income per diluted limited partner unit:

 

 

 

 

 

Net income per diluted limited partner unit under EITF 03-06

 

$

1.75

 

$

0.85

 

Dilutive impact of theoretical distribution of earnings

 

1.10

 

0.25

 

Adjusted net income per diluted limited partner unit

 

$

2.85

 

$

1.10

 

 

The following table presents reconciliations of EBITDA and Adjusted EBITDA to the most directly comparable GAAP financial measures on a historical basis for each period presented (in thousands):

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Reconciliation of net income to EBITDA and Adjusted EBITDA:

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

Depreciation and amortization

 

1,269

 

1,072

 

Interest expense

 

3,316

 

2,320

 

Income tax expense

 

525

 

680

 

EBITDA

 

37,985

 

16,760

 

Gain on sale of investment

 

(14,118

)

 

Adjusted EBITDA

 

$

23,867

 

$

16,760

 

 

 

 

 

 

 

Reconciliation of cash flow provided by operating activities to EBITDA and Adjusted EBITDA:

 

 

 

 

 

Cash flow provided by operating activities

 

$

140,728

 

$

56,589

 

Net changes in operating assets and liabilities

 

(106,584

)

(42,829

)

Interest expense

 

3,316

 

2,320

 

Income tax expense

 

525

 

680

 

EBITDA

 

37,985

 

16,760

 

Gain on sale of investment

 

(14,118

)

 

Adjusted EBITDA

 

$

23,867

 

$

16,760

 

 

25




 

The following table presents reconciliations of distributable cash flow to the most directly comparable GAAP financial measures on a historical basis for each period presented (in thousands):

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

Reconciliation of net income to distributable cash flow:

 

 

 

 

 

Net income

 

$

32,875

 

$

12,688

 

Depreciation and amortization

 

1,269

 

1,072

 

Gain on sale of investment

 

(14,118

)

 

Maintenance capital expenditures

 

(767

)

(104

)

Distributable cash flow

 

$

19,259

 

$

13,656

 

 

 

 

 

 

 

Reconciliation of cash flow provided by operating activities to distributable cash flow:

 

 

 

 

 

Cash flow provided by operating activities

 

$

140,728

 

$

56,589

 

Net changes in operating assets and liabilities

 

(106,584

)

(42,829

)

Gain on sale of investment

 

(14,118

)

 

Maintenance capital expenditures

 

(767

)

(104

)

Distributable cash flow

 

$

19,259

 

$

13,656

 

 

Consolidated Results

Our total sales for the first quarter of 2007 increased by $222.2 million, or 16%, to $1,573.2 million compared to $1,351.0 million for the same period in 2006.  The increase was driven primarily by increased heating oil sales due to colder-than-normal temperatures and higher gasoline and distillate sales.  Our aggregate volume of product sold increased by approximately 108 million gallons, or 14%, to 906 million gallons.  The increase in volume primarily includes increases of 97 million and 41 million gallons in distillates and gasoline, respectively, as a result of our terminal acquisitions in Bridgeport, Connecticut and Macungie, Pennsylvania and higher-than-normal heating degree days, offset by a 25 million gallon decrease in residual oil.  The number of actual heating degree days increased 11% to 2,918 compared to 2,635 for the quarters ended March 31, 2007 and 2006, respectively.  Our gross profit for the first quarter of 2007 was $42.2 million, an increase of $10.0 million, or 31%, compared to $32.2 million for the same period in 2006.  The increase was primarily due to higher net product margins in our Wholesale segment for distillates and residual oil.

Wholesale Segment

Distillates.  Wholesale distillate sales for the three months ended March 31, 2007 increased by $188.2 million, or 22%, to $1,048.8 million from $860.6 million for three months ended March 31, 2006 primarily due to increases in volume sold and in distillate prices for the first quarter of 2007 compared to the same period in 2006.  We attribute the increase in volume sold to the terminal acquisitions in Bridgeport, Connecticut and Macungie, Pennsylvania as well as to temperatures that were 2% colder-than-normal for the first quarter of 2007 and 11% colder compared to the first quarter of 2006.  Our net product margin contribution from distillate sales increased by $7.1 million, or 36%, to $26.7 million for the three months ended March 31, 2007 compared to the same period in 2006.  The increase was, in part, the result of our ability to pass through to customers our increased costs related to sales and the introduction of specialty fuels, such as lower sulfur grades of diesel fuel, into our marketplaces.

Gasoline.  Wholesale gasoline sales for the three months ended March 31, 2007 were $381.3 million compared to 306.6 million for the same period in 2006.  The increase of $74.7 million, or 24%, for the first quarter of 2007 compared to the first quarter of 2006 was due to an increase of 22% in gasoline volume sold and higher gasoline prices.  Our net product margin from gasoline sales decreased by $1.6 million, or 50%, to $1.6 million for the three months ended March 31, 2007 compared to the same period in 2006, primarily due to the return of margins to more historical norms as the industry adjusts to the introduction of ethanol-based gasoline and other transportation fuels.

26




 

Residual Oil.  Wholesale residual oil sales for the three months ended March 31, 2007 were $10.6 million compared to $29.8 million for the three months ended March 31, 2006.  The decrease of $19.2 million, or 64%, for the first three months of 2007 compared to 2006 was the result of a 60% decline in residual oil volume sold and a decrease in residual oil prices.  We attribute the decrease in volume sold to competitive pricing and alternative products.  Our product margin contribution from residual oil sales increased by $5.2 million, or 112%, to $9.9 million for the first quarter of 2007 compared to 2006, primarily due to an increase in net product margin and favorable market conditions.

Commercial Segment

In our Commercial segment, residual oil accounted for approximately 80% and 84% of total commercial volume sold for the three months ended March 31, 2007 and 2006, respectively.  Distillates, gasoline and natural gas accounted for the remainder of the total commercial volume sold.

Commercial residual oil sales for the quarter ended March 31, 2007 decreased 17% compared to the same period in 2006 due to a 16% decrease in volume sold.  We attribute the decrease in volume sold to competitive pricing and alternative products.

Selling, General and Administrative Expenses

SG&A expenses increased by $2.5 million, or 23%, to $13.4 million for the three months ended March 31, 2007 compared to $10.9 million for the same period in 2006.  During the first quarter of 2007, we had increases of approximately $1.2 million in salaries and bonuses, $0.7 million in professional and consulting fees, $0.2 million in information technology expenses, $0.2 million related to employee vacation benefits and $0.2 million in other SG&A expenses.

Operating Expenses

Operating expenses increased by $0.3 million, or 5%, to $5.9 million for the three months ended March 31, 2007 compared to $5.6 million for the same period in 2006.  The increase was primarily due to $0.4 million in costs associated with operating our Bridgeport, Connecticut and Macungie, Pennsylvania facilities, $0.1 million in increased rent for additional tankage at the Capital Terminal in East Providence, Rhode Island and $0.1 million in other operating expenses, offset by $0.3 million in pipeline repair expenses we incurred during the first quarter of 2006.

Interest Expense

Interest expense for the three months ended March 31, 2007 increased $1.0 million, or 43%, to $3.3 million compared to $2.3 million for the same period in 2006, primarily due to higher average balances on our revolving line of credit and higher average interest rates during the three months ended March 31, 2007.

Other Income

Other income for the three months ended March 31, 2006 represented dividend income from our ownership interest in our NYMEX seats and related holdings.  In March 2007, we sold our investment in NYMEX Holdings, Inc. along with our NYMEX seats and, as a result, other income was not recognized for the three months ended March 31, 2007.  See Note 12 of Notes to Financial Statements.

Gain on Sale of Investment

The $14.1 million gain on sale of investment represents the amount we realized on the March 2007 sale of our NYMEX seats and holdings.  See Note 12 of Notes to Financial Statements.

27




 

Liquidity and Capital Resources

Liquidity

Our primary liquidity needs are to fund our capital expenditures and our working capital requirements.  Cash generated from operations and our working capital revolving credit facility provides our primary sources of liquidity.  Working capital was $146.4 million at March 31, 2007 compared to $148.3 million at December 31, 2006.

On February 8, 2007, we and certain of our subsidiaries filed a universal shelf registration statement on Form S-3 with the SEC to register the issuance and sale, from time to time and in such amounts as is determined by market conditions and our needs, of up to $400.0 million of our common units and debt securities of both us and certain of our subsidiaries.  We will use the net proceeds from the sale of the securities covered by the shelf registration for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.  On April 3, 2007, we filed an amendment to the registration statement on Form S-3 /A, and on April 9, 2007, the registration statement on Form S-3 became effective by the SEC.

On February 14, 2007, we paid a cash distribution of $5.2 million for the fourth quarter of 2006 to our common and subordinated unitholders of record as of the close of business on February 5, 2007.

On April 24, 2007, the General Partner’s board of directors declared a quarterly cash distribution of $0.4650 per unit for the first quarter of 2007 to our common and subordinated unitholders of record as of the close of business on May 4, 2007.  This distribution resulted in our reaching the second target distribution with respect to the incentive distribution rights held by the General Partner for the quarter ended March 31, 2007.  We expect to pay the cash distribution of approximately $5.4 million on May 15, 2007.

On April 24, 2007, we amended our Credit Agreement to, among other things, increase the amount available to us for acquisitions from $35.0 million to $85.0 million and extend the term of the Credit Agreement through April 2011.  See “Credit Agreement” below for further details.

On May 9, 2007, we issued 1,785,715 unregistered Class B units in a private placement.  We received proceeds of $50.0 million.  The Class B units are convertible into common units on a one-for-one basis upon the approval of a majority of the votes cast by common unitholders, provided that the total number of votes cast is at least a majority of common units eligible to vote (excluding common units held by our general partner and its affiliates).  In addition, the Class B units are convertible into common units on a one-for-one basis if the New York Stock Exchange amends its requirements to eliminate the common unitholder approval requirement.  In connection with the issuance of the Class B units, we agreed to a discount in the purchase price of approximately $0.8 million, which is the amount equal to the product of (i) the number of issued and outstanding Class B units, times (ii) $0.4650, the amount of our first quarter per unit distribution to be paid to the common and subordinated unitholders on May 15, 2007.  Such discount will be paid by us to the purchasers of the Class B units substantially contemporaneously with the payment of our first quarter distribution.

On May 9, 2007, we completed our previously announced acquisition of three contiguous refined petroleum product terminals from ExxonMobil Oil Corporation for cash consideration of approximately $101.5 million.  We financed the acquisition through an expansion of our credit facility, proceeds from the sale of our NYMEX Holdings shares and related NYMEX seats and the $50.0 million private placement of Class B units discussed above.

Capital Expenditures

Our terminalling operations require investments to expand, upgrade or enhance existing operations and to meet environmental and operations regulations.  Our capital requirements primarily consist of maintenance capital expenditures and capital improvement expenditures.  Maintenance capital expenditures represent capital expenditures to replace partially or fully depreciated assets to maintain the operating capacity of, or sales generated by, existing assets and extend their useful lives, such as expenditures required to maintain equipment reliability, tankage and pipeline integrity and safety, and to address environmental regulations.  We had approximately $0.8 million and $0.1 million in maintenance capital expenditures for the three months ended March 31, 2007 and 2006, respectively.  Repair and maintenance expenses associated with existing assets that are minor in nature and do not extend the useful life of existing assets are charged to operating expenses as incurred.

28




 

Capital improvement expenditures include expenditures to acquire assets to grow our business and to expand existing facilities, such as projects that increase operating capacity by increasing tankage or adding terminals.  We had approximately $0.1 million and $0.7 million in capital improvement expenditures for the three months ended March 31, 2007 and 2006, respectively, to increase operating capacity and capabilities.

We anticipate that maintenance capital expenditures will be funded with cash generated by operations.  We believe that we will have sufficient liquid assets, cash flow from operations, borrowing capacity under our credit agreement and the ability to issue additional common units and/or debt securities under our shelf registration statement to meet our financial commitments, debt service obligations, contingencies and anticipated capital expenditures.  However, we are subject to business and operational risks that could adversely affect our cash flow.  A material decrease in our cash flows would likely produce a corollary adverse effect on our borrowing capacity.

Cash Flow

The following table summarizes cash flow activity (in thousands):

 

 

Three Months Ended
March 31,

 

 

 

2007

 

2006

 

 

 

 

 

 

 

Net cash provided by operating activities

 

$

140,728

 

$

56,589

 

Net cash provided by (used in) investing activities

 

$

9,715

 

$

(829

)

Net cash used in financing activities

 

$

(152,317

)

$

(56,706

)

 

Net cash provided by operating activities increased by $84.1 million for the quarter ended March 31, 2007 compared to the same period in 2006 and generally reflects the contraction of our balance sheet from decreases in the carrying values of inventories and accounts payable as we exit our peak season, offset by an increase in the carrying value of accounts receivable due to a prolonged heating season in the first quarter of 2007 compared to the same period in 2006 and the increase in our gasoline sales.

The increase in cash provided by operating activities also includes net income of $32.9 million, the adjustment of $14.1 million for the gain on the sale of our NYMEX Holdings shares and related seats, and a $66.2 million change in fair value of our forward fixed purchase and sale contracts.

Net cash provided by investing activities was $9.7 million for the three months ended March 31, 2007 compared to cash used in the amount of $0.8 million for the same period in 2006.  The $10.5 million increase was primarily attributable to proceeds of $15.3 million from the sale of our investment in NYMEX Holdings and related seats, offset by $4.7 million used for a pre-acquisition deposit and other costs and $0.8 million used for total capital expenditures during the first quarter of 2007.

Net cash used in financing activities increased $95.6 million for the three months ended March 31, 2007 compared to the same period in 2006.  During the first quarter of 2007, we paid $147.0 million on our revolving line of credit and $5.2 million in cash distributions to our common and subordinated unitholders.  In comparison, for the first quarter in 2006, we paid $51.9 million on our credit facility and $4.7 million in cash distributions.

Credit Agreement

In August 2006, we, our general partner, our operating company and our operating subsidiaries amended our four-year senior secured credit agreement to increase the permanent working capital revolving credit facility commitment by $100.0 million for total available commitments of $600.0 million.  We repay amounts outstanding and reborrow funds based on our working capital requirements and, therefore, classify as a current liability the portion of the revolving line of credit we expect to pay down during the course of the year.  The long-term portion of the revolving line of credit is the amount we expect to be outstanding during the entire year.

29




 

At March 31, 2007, there were three facilities under our Credit Agreement that included the following:

·              a working capital revolving credit facility to be used for working capital purposes and letters of credit in the principal amount equal to the lesser of our borrowing base and $550.0 million, of which two $50.0 million seasonal overline facilities are available each year only during the period between September 1st and June 30th;

·              a $35.0 million acquisition facility to be used for funding acquisitions similar to our business line that have a purchase price of $25.0 million or less or $35.0 million or less in the aggregate in any 12-month period; and

·              a $15.0 million revolving credit facility to be used for general purposes, including payment of distributions to our unitholders.

At March 31, 2007, borrowings under our working capital revolving credit, acquisition and revolving credit facilities bore interest at our option at (1) the Eurodollar rate, plus 1%, 1¾% and 1½%, respectively, (2) the cost of funds rate, plus 1%, 1¾% and 1½%, respectively, or (3) the bank’s base rate.  The average interest rate for the three months ended March 31, 2007 was 6.3%.  We incur a letter of credit fee of 1% per annum for each letter of credit issued.  In addition, we incur a commitment fee on the unused portion of the three facilities under the Credit Agreement (including the unused portion of either of the seasonal overline facilities exercised by us) at a rate of 25 basis points per annum, a facility fee of 10 basis points per annum on any unexercised seasonal overline facility during the period between September 1st and June 30th and a seasonal overline fee of $30,000 each time we elect to exercise either of the seasonal overline facilities.  As of March 31, 2007, we had total borrowings outstanding under our working capital revolving credit facility of $123.7 million and outstanding letters of credit of $45.2 million, for a total indebtedness of $168.9 million.

Our obligations under the Credit Agreement are secured by substantially all of our assets and the assets of our operating company and operating subsidiaries.

As previously disclosed in a Form 8-K filed by us on April 26, 2007, the Credit Agreement was amended to, among other things:

·              increase our $35.0 million acquisition facility by $50.0 million to $85.0 million;

·              possibly increase, at our request and provided that no Default or Event of Default (as defined in the Credit Agreement) then exists: (1) the acquisition facility by up to another $50.0 million, for a total acquisition facility of up to $135.0 million; and (2) the working capital revolving credit facility by up to another $100.0 million, for a total working capital revolving credit facility of up to $650.0 million.  Any such request for an increase by us must be in a minimum amount of $5.0 million, and no more than three such requests may be made for each facility;

·              extend the term of the Credit Agreement to April 22, 2011;

·              reduce the margins that are added to the Eurodollar rate for interest on indebtedness under the Credit Agreement from a range of 1.00% to 1.75% per annum to a range of 1.00% to 1.50% per annum, depending on which facility is being used;

·              reduce the minimum EBITDA (as defined in the Credit Agreement) to interest coverage ratio from 2.75:1:00 to 2.50:1.00; and

·              increase the threshold amount in excess of which we are not permitted to make or to become legally obligated to make aggregate permitted capital expenditures in any fiscal year from $4.0 million to $10.0 million.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

30




 

Critical Accounting Policies and Estimates

Management’s Discussion and Analysis of Financial Condition and Results of Operations discusses our consolidated financial statements, which have been prepared in accordance with GAAP.  The preparation of these financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results may differ from these estimates under different assumptions or conditions.

These estimates are based on our knowledge and understanding of current conditions and actions that we may take in the future.  Changes in these estimates will occur as a result of the passage of time and the occurrence of future events.  We have identified the following estimates that, in our opinion, are subjective in nature, require the exercise of judgment, and involve complex analysis:  inventory, leases, revenue recognition, derivative financial instruments and environmental and other liabilities.

The significant accounting policies and estimates that we have adopted and followed in the preparation of our consolidated financial statements are detailed in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies and Estimates” and Note 2 of Notes to Financial Statements, “Summary of Significant Accounting Policies” included in our Annual Report on Form 10-K for the year ended December 31, 2006.  There have been no subsequent changes in these policies and estimates that had a significant impact on our financial condition and results of operations for the periods covered in this report.

Recent Accounting Pronouncements

A description and related impact expected from the adoption of certain new accounting pronouncements is provided in Note 14 of Notes to Financial Statements.

Item 3.        Quantitative and Qualitative Disclosures about Market Risk

Market risk is the risk of loss arising from adverse changes in market rates and prices.  The principal market risks to which we are exposed are interest rate risk and commodity risk.  We utilize various derivative instruments to manage exposure to commodity risk.  Because the outstanding amount under our credit facility fluctuates due to commodity prices and the seasonality of our business, we have chosen currently and historically not to enter into any hedging instruments related to our variable rate debt.

Interest Rate Risk

We utilize variable rate debt and are exposed to market risk due to the floating interest rates on our current credit facility and term loan.  Therefore, from time to time, we may utilize interest rate swaps and collars to hedge interest obligations on specific and anticipated debt issuances.  We had no interest rate hedging instruments outstanding as of March 31, 2007.  Borrowings under our working capital revolving credit, acquisition credit and revolving credit facilities bore interest at our option at (1) the Eurodollar rate, plus 1%, 1¾% and 1½ %, respectively, (2) the cost of funds rate, plus 1%, 1¾% and 1½ %, respectively, or (3) the bank’s base rate (the average rate for the three months ended March 31, 2007 was 6.3%).  As of March 31, 2007, we had total borrowings outstanding under our working capital revolving credit facility of $123.7 million.  The impact of a 1% increase in the interest rate on this amount of debt would have resulted in an increase in interest expense, and a corresponding decrease in our results of operations, of approximately $1.2 million annually, assuming, however, that our indebtedness remained constant throughout the year.

Commodity Risk

We hedge our exposure to price fluctuations with respect to refined petroleum products in storage and expected purchases and sales of these commodities.  The derivative instruments utilized consist primarily of futures and option contracts traded on the NYMEX and over-the-counter transactions, including swap contracts entered into with established financial institutions and other credit-approved energy companies.  Our policy is generally to purchase only products for which we have a market and to structure our sales contracts so that price fluctuations do not materially

31




 

affect the profit we receive.  While our policies are designed to minimize market risk, some degree of exposure to unforeseen fluctuations in market conditions remains.  Except for the controlled trading program discussed below, we do not acquire and hold futures contracts or other derivative products for the purpose of speculating on price changes that might expose us to indeterminable losses.

While we seek to maintain a position that is substantially balanced within our product purchase activities, we may experience net unbalanced positions for short periods of time as a result of variances in daily sales and transportation and delivery schedules as well as logistical issues associated with inclement weather conditions.  In connection with managing these positions and maintaining a constant presence in the marketplace, both necessary for our business, we engage in a controlled trading program for up to an aggregate of 250,000 barrels of refined petroleum products.

We enter into future contracts to minimize or hedge the impact of market fluctuations on our purchase and fixed forward sales of refined petroleum products.  Any hedge ineffectiveness is reflected in our results of operations.  We utilize the NYMEX, which is a regulated exchange for energy products that it trades, thereby reducing potential delivery and supply risks.  Generally, our practice is to close all NYMEX positions rather than to make or receive physical deliveries.  With respect to other energy products, we enter into derivative agreements with counterparties that we believe have a strong credit profile, in order to hedge market fluctuations and/or lock-in margins relative to our commitments.

At March 31, 2007, the fair value of all of our commodity risk derivative instruments and the change in fair value that would be expected from a 10% price decrease are shown in the table below (in thousands):

(Loss) gain:

 

 

Fair Value at
March 31, 2007

 

Effect of 10%
Price Decrease

 

 

 

 

 

 

 

NYMEX contracts

 

$

(1,691

)

$

1,080

 

Swaps, options and other, net

 

(675

)

13

 

 

 

$

(2,366

)

$

1,093

 

 

The fair values of the futures contracts are based on quoted market prices obtained from the NYMEX. The fair value of the swaps and option contracts are estimated based on quoted prices from various sources such as independent reporting services, industry publications and brokers.  These quotes are compared to the contract price of the swap, which approximates the gain or loss that would have been realized if the contracts had been closed out at March 31, 2007. For positions where independent quotations are not available, an estimate is provided, or the prevailing market price at which the positions could be liquidated is used. All hedge positions offset physical exposures to the spot market; none of these offsetting physical exposures are included in the above table.  Price-risk sensitivities were calculated by assuming an across-the-board 10% decrease in price regardless of term or historical relationships between the contractual price of the instruments and the underlying commodity price. In the event of an actual 10% change in prompt month prices, the fair value of our derivative portfolio would typically change less than that shown in the table due to lower volatility in out-month prices. We have a daily margin requirement to maintain a cash deposit with our broker based on the prior day’s market results on open futures contracts. The balance of this deposit will fluctuate based on our open market positions and the commodity exchange’s requirements. The required brokerage margin balance was $1.4 million at March 31, 2007.

We are exposed to credit loss in the event of nonperformance by counterparties of forward contracts, options and swap agreements, but do not anticipate nonperformance by any of these counterparties.  Futures contracts, the primary derivative instrument utilized, are traded on regulated exchanges, greatly reducing potential credit risks.  Exposure on swap and certain option agreements is limited to the amount of the recorded fair value as of the balance sheet dates.  We utilize primarily one broker, a major financial institution, for all derivative transactions and the right of offset exists.  Accordingly, the fair value of all derivative instruments is displayed on a net basis.

32




 

Item 4.        Controls and Procedures

In designing and evaluating controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Disclosure Controls and Procedures

Our management, with the participation of our principal executive officer and principal financial officer, evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (the “Exchange Act”)) as of the fiscal quarter ended March 31, 2007.  Based on this evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures are effective to ensure that the information required to be disclosed by us in the reports we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms.

Internal Control over Financial Reporting

There has not been any change in our internal control over financial reporting (as defined in Rule 13a-15(f) of the Exchange Act) that occurred during the fiscal quarter ended March 31, 2007 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

33




 

PART II.  OTHER INFORMATION

Item 1.        Legal Proceedings

Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we do not believe that we are a party to any litigation that will have a material adverse impact on our financial condition or results of operations.  Except as described in our Annual Report on Form 10-K for the year ended December 31, 2006, we are not aware of any significant legal or governmental proceedings against us, or contemplated to be brought against us.  We maintain insurance policies with insurers in amounts and with coverage and deductibles as our general partner believes are reasonable and prudent.  However, we can provide no assurance that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at economical prices.

34




 

Item 1A.     Risk Factors

There have been no material changes to the Risk Factors disclosed in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2006.

Item 6.        Exhibits

 

31.1

 

 

Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

31.2

 

 

Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

32.1 †

 

 

Section 1350 Certification of Chief Executive Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

32.2 †

 

 

Section 1350 Certification of Chief Financial Officer of Global GP LLC, general partner of Global Partners LP.


                      Not deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liability of that section.

35




 

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

GLOBAL PARTNERS LP

 

By:

Global GP LLC,

 

 

its general partner

 

 

 

 

 

 

Dated: May 10, 2007

By:

/s/ Eric Slifka

 

 

Eric Slifka

 

 

President and Chief Executive Officer

 

 

(Principal Executive Officer)

 

 

 

 

 

 

Dated: May 10, 2007

By:

/s/ Thomas J. Hollister

 

 

Thomas J. Hollister

 

 

Executive Vice President, Chief Operating Officer and Chief Financial Officer

 

 

(Principal Financial Officer)

 

 

36




 

INDEX TO EXHIBITS

Exhibit
Number

 

 

 

Description

 

 

 

 

 

 

 

 

31.1

 

 

 

Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

 

31.2

 

 

 

Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

 

32.1 †

 

 

 

Section 1350 Certification of Chief Executive Officer of Global GP LLC, general partner of Global Partners LP.

 

 

 

 

 

 

 

 

32.2 †

 

 

 

Section 1350 Certification of Chief Financial Officer of Global GP LLC, general partner of Global Partners LP.


                      Not deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liability of that section.

 



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