GLOBAL PARTNERS LP - Quarter Report: 2007 June (Form 10-Q)

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 June 30, 2007

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

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 7,428,139 common units and 5,642,424 subordinated units outstanding as of August 1, 2007.

TABLE OF CONTENTS

PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements

Consolidated Balance Sheets as of June 30, 2007 and December 31, 2006

Consolidated Statements of Income for the three and six months ended June 30, 2007 and 2006

Consolidated Statements of Cash Flows for the six months ended June 30, 2007 and 2006

Consolidated Statements of Partners’ Equity for the six months ended June 30, 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)

	June 30, 2007			December 31, 2006
Assets
Current assets:
Cash and cash equivalents	$	2,527		$	3,861
Accounts receivable, net	272,993			202,580
Accounts receivable—affiliates	5,506			1,988
Inventories	239,477			288,067
Available for sale securities	—			13,913
Brokerage margin deposits	4,591			625
Fair value of forward fixed contracts	944			66,115
Prepaid expenses and other current assets	10,563			18,924
Total current assets	536,601			596,073
Property and equipment, net	142,885			31,657
Intangible assets, net	8,360			9,076
Other assets	3,454			2,081
Total assets	$	691,300		$	638,887
Liabilities and partners’ equity
Current liabilities:
Accounts payable	$	232,898		$	222,034
Revolving line of credit—current portion	98,100			188,700
Notes payable, other—current portion	319			319
Environmental liabilities—current portion	500			—
Accrued expenses and other current liabilities	50,459			35,573
Income taxes payable	—			1,164
Obligations on forward fixed contracts and other derivatives	10,517			—
Total current liabilities	392,793			447,790
Revolving line of credit—less current portion	122,000			82,000
Notes payable, other—less current portion	1,083			1,239
Environmental liabilities—less current portion	7,500			—
Accrued pension benefit cost	3,511			3,170
Deferred compensation	1,388			1,429
Other long-term liabilities	20			20
Total liabilities	528,295			535,648
Partners’ equity
Common unitholders (7,428,139 units issued and outstanding at June 30, 2007 and 5,642,424 at December 31, 2006)	164,554			104,212
Subordinated unitholders (5,642,424 units issued and outstanding at June 30, 2007 and December 31, 2006)	(2,480		)	(13,672		)
General partner interest (230,303 equivalent units outstanding at June 30, 2007 and December 31, 2006)	(108		)	(560		)
Accumulated other comprehensive income	1,039			13,259
Total partners’ equity	163,005			103,239
Total liabilities and partners’ equity	$	691,300		$	638,887

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

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2007			2006			2007			2006

Sales	$	1,384,090		$	1,031,353		$	2,957,266		$	2,382,376
Cost of sales	1,362,468			1,010,709			2,893,392			2,329,515
Gross profit	21,622			20,644			63,874			52,861

Costs and operating expenses:
Selling, general and administrative expenses	11,458			9,416			24,864			20,344
Operating expenses	6,310			5,266			12,200			10,817
Amortization expenses	358			406			716			812
Total costs and operating expenses	18,126			15,088			37,780			31,973

Operating income	3,496			5,556			26,094			20,888

Interest expense	(2,523		)	(1,786		)	(5,839		)	(4,106		)
Other income	—			—			—			356
Gain on sale of investment	—			—			14,118			—

Income before income tax expense	973			3,770			34,373			17,138

Income tax expense	(363		)	(290		)	(888		)	(970		)

Net income	$	610		$	3,480		$	33,485		$	16,168

Less:
General partner’s interest in net income	(11		)	(70		)	(668		)	(324		)
Limited partners’ interest in net income	$	599		$	3,410		$	32,817		$	15,844

Net (loss) income per limited partner unit, basic and diluted(1)	$	(1.28	)	$	0.30		$	0.47		$	1.15

Weighted average limited partners’ units outstanding, basic and diluted	12,325			11,285			11,808			11,285

(1) See Note 3 for net (loss) income per limited partner unit calculation which includes a non-cash reduction in net income available to limited partners under EITF 98-05 (See Note 12).

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

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

	Six Months Ended June 30,
	2007			2006

Operating activities
Net income	$	33,485		$	16,168
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	3,126			1,960
Amortization of deferred financing fees	210			200
Disposition of property and equipment and other	(1		)	175
Gain on sale of investment	(14,118		)	—
Changes in operating assets and liabilities:
Accounts receivable	(70,413		)	69,061
Accounts receivable — affiliate	(3,518		)	222
Inventories	48,590			(3,223		)
Broker margin deposits	(3,965		)	3,694
Prepaid expenses, all other current assets and other assets	7,249			(4,842		)
Accounts payable	10,864			(75,295		)
Income taxes payable	(1,164		)	(461		)
Accrued expenses and all other current liabilities	15,264			4,580
Change in fair value of forward fixed contracts	75,688			—
Net cash provided by operating activities	101,297			12,239

Investing activities
Terminal acquisitions	(102,620		)	(2,348		)
Proceeds from sale of investment	15,262			—
Capital expenditures	(3,019		)	(3,165		)
Proceeds from sale of property and equipment	2			19
Net cash used in investing activities	(90,375		)	(5,494		)

Financing activities
Proceeds from common unit issuance, net of discount and fees	49,099			—
(Payments on) proceeds from credit facilities, net	(50,600		)	2,200
Payments on note payable, other	(157		)	(147		)
Distributions to partners	(10,598		)	(9,627		)
Net cash used in financing activities	(12,256		)	(7,574		)

Decrease in cash and cash equivalents	(1,334		)	(829		)
Cash and cash equivalents at beginning of period	3,861			1,769
Cash and cash equivalents at end of period	$	2,527		$	940

Supplemental information
Cash paid during the period for interest	$	5,506		$	4,070

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

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

												Accumulated
									General			Other		Total
	Common			Class B		Subordinated			Partner			Comprehensive		Partners’
	Unitholders			Units		Unitholders			Interest			Income		Equity
Balance December 31, 2006	$	104,212		$	—	$	(13,672	)	$	(560	)	$	13,259	$	103,239
Proceeds of issuance of Class B units, net	—			49,099		—			—			—		49,099
Non-cash reduction under EITF 98-05 on issuance of Class B units (Note 12)	(16,400		)	16,400		—			—			—		—
Conversion of Class B units	65,499			(65,499)		—			—			—		—
Distributions to partners	(5,191)			—		(5,191)			(216)			—		(10,598)
Comprehensive income:
Net income	16,434			—		16,383			668			—		33,485
Other comprehensive income:
Unrealized gain on NYMEX shares	—			—		—			—			(12,837)		(12,837)
Change in fair value of interest rate collar	—			—		—			—			540		540
Adjustment - SFAS No. 158	—			—		—			—			77		77
Total other comprehensive income	16,434			—		16,383			688			(12,220)		21,265
Balance June 30, 2007	$	164,554		$	—	$	(2,480)		$	(108)		$	1,039	$	163,005

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

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, GLP Finance Corp. (“GLP Finance”) is 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.

On May 9, 2007, the Partnership issued 1,785,715 unregistered Class B units in a private placement from which it received gross proceeds of $50.0 million. The Class B units were convertible into common units on a one-for-one basis. 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, and (ii) $0.4650, the amount of the Partnership’s first quarter per unit distribution that was paid to the common and subordinated unitholders on May 15, 2007. Such discount was paid by the Partnership to the purchasers of the Class B units substantially contemporaneously with the payment of the Partnership’s first quarter distribution and resulted in proceeds of $49.2 million. On May 22, 2007, the Class B units converted into common units on a one-for-one basis. See Note 12 for additional information on the private placement.

Also on May 9, 2007, the Partnership completed its acquisition of three refined petroleum products terminals located in Albany and Newburgh, New York and Burlington, Vermont from ExxonMobil Oil Corporation (“ExxonMobil”). 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 private placement of Class B units discussed above. See Note 13 for information on the acquisition.

The Partnership’s 1.73% general partner interest (reduced from 2% following the private placement of Class B units discussed above and in Note 12) is held by Global GP LLC, the Partnership’s general partner (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 June 30, 2007 and December 31, 2006 and for the three and six months ended June 30, 2007 and 2006 reflect the accounts of the Partnership. All intercompany balances and transactions have been eliminated.

The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and reflect all adjustments (consisting 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 and six months ended June 30, 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 consolidated balance sheet at December 31, 2006 has been derived from the audited financial statements and

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 (Loss) Income Per Limited Partner Unit

The computation of net (loss) 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 (loss) 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 general partner interest) by the weighted average number of outstanding limited partner units during the period in accordance with Emerging Issues Task Force 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 (loss) 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.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2007			2006			2007			2006

Net income	$	610		$	3,480		$	33,485		$	16,168
Less:
General Partner’s general partner interest(1)	(11		)	(70		)	(668		)	(324		)
Non-cash reduction under EITF 98-05 allocated to limited partners(2)	(16,400)			—			(16,400)			—
Net (loss) income available to limited partners	(15,801)			3,410			16,417			15,844
Dilutive impact of theoretical distribution of earnings	—			—			(12,405)			(2,872)
Net (loss) income available to limited partners under EITF 03-06 and EITF 98-05	$	(15,801)		$	3,410		$	4,012		$	12,972

Per unit data:
Net (loss) income available to limited partners	$	(1.28)		$	0.30		$	1.57		$	1.40
Dilutive impact of theoretical distribution of earnings	—			—			(1.10)			(0.25)
Net (loss) income available to limited partners under EITF 03-06 and EITF 98-05(3)	$	(1.28)		$	0.30		$	0.47		$	1.15

Weighted average limited partner units outstanding	12,325			11,285			11,808			11,285

(1) On May 9, 2007, the general partner interest was reduced to 1.73% as a result of the private placement of Class B units. Calculation includes the effect of the private placement of Class B units and is based on a weighted average of 1.83% and 1.99% for the three and six months ended June 30, 2007, respectively. For the three and six months ended June 30, 2006, the general partner interest was 2%.

(2) In connection with the private placement of Class B units (see Note 12), the Partnership was required to take into account the effect of EITF 98-05, “Accounting for Convertible Securities with Beneficial Conversion Features or Contingently Adjustable Conversion Ratios” (“EITF 98-05”). As a result, a non-cash reduction in net income available to limited partners was recorded because the fair value of the Partnership’s common units on May 9, 2007 (the date on which the Class B units were issued) was greater than the purchase price of the Class B units, which was established at the time of the execution of the Unit Purchase Agreement on March 14, 2007. Although EITF 98-05 affects net income available to limited partners, it does not affect net income nor does it affect total unitholders’ equity.

(3) Per unit data includes the weighted average effect of the private placement of Class B units which were converted to common units for the three and six months ended June 30, 2007. Per unit data is calculated on a quarterly basis pursuant to EITF 03-06, therefore, per unit data for the six months ended June 30, 2007 and 2006 equals the sums of the respective first and second quarters.

On April 24, 2007, the board of directors of our General Partner declared a quarterly cash distribution of $0.4650 per unit for the period from January 1, 2007 through March 31, 2007. On July 24, 2007, the board declared a quarterly cash distribution of $0.4725 per unit for the period from April 1, 2007 through June 30, 2007. These declared cash distributions resulted in incentive distributions to our General Partner, as the holder of the incentive distribution rights, as indicated above, and enabled the Partnership to reach its second target distribution with respect to such incentive distribution rights. 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):

	June 30, 2007		December 31, 2006

Distillates: home heating oil, diesel and kerosene	$	152,842	$	235,266
Residual oil	25,466		35,226
Gasoline	46,719		9,870
Blendstock	14,450		7,705
Total	$	239,477	$	288,067

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 June 30, 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.

Fair Value Hedges

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 June 30, 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 consolidated balance sheet consisted of the following (in thousands):

	June 30, 2007			December 31, 2006
Futures contracts	$	(9,467	)	$	57,571
Swaps, options and other, net	(106		)	8,544
	$	(9,573	)	$	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.

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 $4.6 million and $0.6 million at June 30, 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 presented on a net basis on the consolidated balance sheets.

Interest Rate Hedge

In May 2007, the Partnership executed a zero premium interest rate collar with a major financial institution. The collar, which became effective on May 14, 2007, is used to hedge the variability in interest payments due to changes in the three-month LIBOR rate with respect to $100.0 million of long-term three-month LIBOR-based borrowings. Under the collar, the Partnership capped its exposure at a maximum three-month LIBOR rate of 5.75%. In addition, the Partnership established a minimum floor rate of 3.75%. The collar, which expires on May 14, 2011, is designated as a cash flow hedge and accounted for under the provisions of SFAS No. 133. As of June 30, 2007, the change in fair value of the collar was an asset of approximately $0.5 million and was recorded in both other long-term assets and accumulated other comprehensive income in the accompanying consolidated balance sheet. There was no ineffectiveness related to the collar as of June 30, 2007.

Note 6. Debt

The Partnership has a four-year senior secured credit agreement (the “Credit Agreement”) with total available commitments of $650.0 million. At June 30, 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;

· an $85.0 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.

In addition, provided no Event of Default (as defined in the Credit Agreement) then exists, the Partnership may request to increase: (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.

At June 30, 2007, borrowings under the Partnership’s working capital revolving credit, acquisition and revolving credit facilities bear interest at the Partnership’s option at (1) the Eurodollar rate, plus 1%, 1½% and 1½%, respectively, (2) the cost of funds rate, plus 1%, 1¾% and 1½%, respectively, or (3) the bank’s base rate. In May 2007, the Partnership executed a zero premium interest rate collar with a major financial institution. The collar, which became effective on May 14, 2007, is used to hedge the variability in interest payments due to changes in the three-month LIBOR rate with respect to $100.0 million of long-term three-month LIBOR-based borrowings (see Note 5 for further discussion on the interest rate collar). 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.

The Credit Agreement will mature on April 22, 2011. 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 $122.0 million and $82.0 million at June 30, 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 $98.1 million and $188.7 million at June 30, 2007 and December 31, 2006, respectively, representing the amounts the Partnership expects to pay down during the course of the year.

At June 30, 2007, availability under the Credit Agreement was reduced by the outstanding balance of approximately $220.1 million and by letters of credit totaling approximately $59.0 million. The average interest rates for the three and six months ended June 30, 2007 were 6.4% and 6.3%, respectively.

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 June 30, 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.

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 June 30,						Six Months Ended June 30
	2007			2006			2007			2006
Service cost	$	203		$	191		$	407		$	382
Interest cost	164			149			327			299
Expected return on plan assets	(158		)	(144		)	(316		)	(289		)
Net periodic benefit cost	$	209		$	196		$	418		$	392

Note 8. Related Party Transactions

The Partnership is a party to a Second Amended and Restated Terminal Storage Rental and Throughput Agreement with Global Petroleum Corp. (“GPC”), an affiliate of the Partnership, which extends through December 2013. The agreement is accounted for as an operating lease. The expenses under this agreement totaled approximately $2.1 million and $2.0 million for the three months ended June 30, 2007 and 2006, respectively, and $4.1 million for each of the six months ended June 30, 2007 and 2006.

Pursuant to an 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 expenses from these services totaled approximately $18,000 and $22,000 for the three months ended June 30, 2007 and 2006, respectively, and $36,000 and $39,000 for the six months ended June 30, 2007 and 2006, respectively. These affiliate charges were recorded in selling, general and administrative expenses in the accompanying consolidated 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 Partnership’s Amended and Restated Services Agreement with Alliance Energy Corp. (“Alliance”), the Partnership also provides certain administrative, accounting and information processing services, and the use of certain facilities, to 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 $298,000 for the three months ended June 30, 2007 and 2006, respectively, and $264,000 and $378,000 for the six months ended June 30, 2007 and 2006, respectively. These intercompany fees were recorded as an offset to selling, general and administrative expenses in the accompanying consolidated 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 $13.2 million and $6.5 million for the three months ended June 30, 2007 and 2006, respectively, and $19.0 million and $11.5 million for the six months ended June 30, 2007 and 2006, respectively.

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 June 30, 2007 and 2006, including payroll, payroll taxes and bonus accruals, were $6.3 million and $4.5 million, respectively, and $14.6 million and $11.2 million for the six months ended June 30, 2007 and 2006, 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):

	June 30, 2007		December 31, 2006
Receivables from Alliance	$	5,113	$	1,793
Receivables from GPC	134		81
Receivables from the General Partner (1)	259		114
Total	$	5,506	$	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, 98.27% to the common unitholders, pro rata, and 1.73% 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, 98.27% to the common unitholders, pro rata, and 1.73% 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, 98.27% to the subordinated unitholders, pro rata, and 1.73% 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.

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	98.27	%	1.73	%
First Target Distribution	Up to $0.4625	98.27	%	1.73	%
Second Target Distribution	above $0.4625 up to $0.5375	85.27	%	14.73	%
Third Target Distribution	above $0.5375 up to $0.6625	75.27	%	24.73	%
Thereafter	above $0.6625	50.27	%	49.73	%

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		General Partner Incentive Distribution(1)		Total Cash Distribution
02/14/07	$	0.4550	$	2,567	$	2,567	$	105	$	—	$	5,239
05/15/07	0.4650		2,624		2,624		107		4		5359

(1) This distribution of $0.4650 per unit resulted in the Partnership reaching its second target distribution for the first quarter of 2007. As a result, the General Partner received an additional distribution of approximately $4.

The Partnership also paid a cash distribution of approximately $0.8 million to the purchasers of the Class B units (see Note 1). In addition, on July 24, 2007, the board of directors of the General Partner declared a quarterly cash distribution of $0.4725 per unit for the period from April 1, 2007 through June 30, 2007 ($1.89 per unit on an annualized basis) to the Partnership’s common and subordinated unitholders of record as of the close of business August 3, 2007. This distribution resulted in the Partnership reaching its second target distribution for the second quarter ended June 30, 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.

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 June 30,				Six Months Ended June 30,
	2007		2006		2007		2006
Wholesale Segment:
Sales	$	1,304,171	$	950,801	$	2,744,781	$	2,147,780
Net product margin (1)
Distillates	$	12,555	$	5,992	$	39,296	$	25,589
Gasoline	2,316		7,166		3,934		10,402
Residual oil	5,488		5,266		15,372		9,920
Total	$	20,359	$	18,424	$	58,602	$	45,911
Commercial Segment:
Sales	$	79,919	$	80,552	$	212,485	$	234,596
Net product margin (1)	$	2,634	$	2,644	$	7,234	$	7,780
Combined sales and net product margin:
Sales	$	1,384,090	$	1,031,353	$	2,957,266	$	2,382,376
Net product margin (1)	$	22,993	$	21,068	$	65,836	$	53,691
Depreciation allocated to cost of sales	1,371		424		1,962		830
Combined gross profit	$	21,622	$	20,644	$	63,874	$	52,861

(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.

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 June 30, 2007						Six Months Ended June 30, 2006
	2007			2006			2007			2006
Combined gross profit	$	21,622		$	20,644		$	63,874		$	52,861
Operating costs and expenses not allocated to reportable segments:
Selling, general and administrative expenses	11,458			9,416			24,864			20,344
Operating expenses	6,310			5,266			12,200			10,817
Amortization expenses	358			406			716			812
Total operating costs and expenses	18,126			15,088			37,780			31,973
Operating income	3,496			5,556			26,094			20,888
Interest expense	(2,523		)	(1,786		)	(5,839		)	(4,106		)
Other income	—			—			—			356
Gain on sale of investment	—			—			14,118			—
Income tax expense	(363)			(290)			(888)			(970		)
Net income	$	610		$	3,480		$	33,485		$	16,168

There were no foreign sales for the three and six months ended June 30, 2007 and 2006. The Partnership has no foreign assets.

Note 11. 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 consolidated 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 consolidated statements of income for the six months ended June 30, 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 consolidated statements of income for the six months ended June 30, 2007.

Note 12. Unitholders’ Equity

Private Placement

On March 13, 2007, the Partnership entered into a Class B Unit Purchase Agreement (the “Unit Purchase Agreement”) with Kayne Anderson MLP Investment Company and funds managed by Tortoise Capital Advisors, LLC and Fiduciary Asset Management, LLC (the “Purchasers”) to sell $50.0 million of Class B units representing limited partner interests of the Partnership in a private placement (the “Private Placement”). The Partnership issued and sold 1,785,715 Class B units to the Purchasers pursuant to the Unit Purchase Agreement on May 9, 2007. The Class B units were convertible into common units on a one-for-one basis.

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 approximate amount of the product of (i) the 1,785,715 Class B units, and (ii) $0.4650, the amount of the Partnership’s first quarter per unit distribution that was paid to the common and subordinated unitholders on May 15, 2007. Such discount was paid by the Partnership to the Purchasers of the Class B units substantially contemporaneously with the payment of the Partnership’s first quarter distribution. After giving effect to such reduction, the purchase price for the Class B units was approximately $49.2 million, or $27.53 per unit. The net purchase price of the Class B units, after the reduction and related fees, was $49.1 million. The net proceeds of the Class B units were used to partially finance the acquisition of three refined petroleum products terminals in Albany and Newburgh, New York and Burlington, Vermont from ExxonMobil (see Note 13). On May 22, 2007, the Class B units converted into common units on one-for-one basis.

In connection with the Unit Purchase Agreement, the Partnership entered into a registration rights agreement (the “Registration Rights Agreement”) dated May 9, 2007 with the Purchasers. Pursuant to the Registration Rights Agreement, the Partnership is required to file a shelf registration statement to register the common units issuable upon conversion of the Class B units issued to the Purchasers within 90 days, and use its commercially reasonable efforts to cause the registration statement to become effective within 180 days of the closing of the Private Placement. On August 6, 2007, the Partnership filed a Registration Statement on Form S-3 with the SEC for the registration of the 1,785,715 common units into which the Class B units converted. In addition, the Registration Rights Agreement gives the Purchasers piggyback registration rights under certain circumstances. These registration rights are transferable to affiliates of the Purchasers and, in certain circumstances, to third parties.

If the shelf registration statement is not effective by November 5, 2007, then the Partnership could potentially pay the Purchasers liquidated damages of $125,000 per 30-day period for the first 60 days following November 5, 2007. This amount could increase by an additional $125,000 per 30-day period for each subsequent 60 days, up to a maximum of $500,000 per 30-day period. The aggregate amount of liquidated damages the Partnership could pay will not exceed 10% of the gross purchase price, or $5.0 million. Based upon its evaluation of the liability exposure related to the liquidated damages, the Partnership determined such exposure is remote and, therefore, did not record a liability as of June 30, 2007.

Class B Units Convert into Common Units

On May 9, 2007, the Partnership issued and sold to the Purchasers 1,785,715 Class B units representing limited partner interests of the Partnership in a private placement for $50.0 million. After giving effect to a price reduction as discussed above, the purchase price for the Class B units was approximately $49.2 million, or $27.53 per unit. On May 22, 2007, the Class B units converted into common units on one-for-one basis.

In connection with the transaction, the Partnership was required to take into account the effect of EITF 98-05. As a result, a non-cash reduction in net income available to limited partners was recorded. This non-cash reduction is required to be recorded pursuant to EITF 98-05 because the fair value of the Partnership’s common units on May 9, 2007 (the date on which the Class B units were issued) was greater than the purchase price of the Class B units, which was established at the time of the execution of the Unit Purchase Agreement on March 14, 2007. The non-cash reduction was approximately $16.4 million computed as the product of (i) the 1,785,715 Class B units, and (ii) the difference between the fair value of a common unit on the date of issuance ($36.71) and the conversion rate after the price reduction ($27.53). The non-cash reduction resulted in the Partnership recognizing a $16.4 million decrease in common unit equity and a corresponding increase in Class B unit equity. Additionally, the Partnership recorded accretion of $16.4 million as a non-cash distribution to common unitholders.

Although EITF 98-05 affects net income available to limited partners, it does not affect net income, nor does it affect total unitholders’ equity.

Note 13. Terminal Acquisition

On May 9, 2007, the Partnership completed its acquisition of three refined petroleum products terminals located in Albany and Newburgh, New York and Burlington, Vermont from ExxonMobil for cash consideration of approximately $101.5 million plus $1.1 million in acquisition costs, for an aggregate purchase price of $102.6 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 private placement of Class B units (see Notes 6, 11 and 12, respectively). This acquisition has been accounted for as an asset acquisition.

The following table presents the preliminary allocation of the purchase price to the estimated fair value of the assets acquired and environmental liabilities assumed. The allocation of the purchase price will be finalized as the Partnership receives other information relevant to the acquisition, including a valuation of the assets purchased and further information with respect to the environmental liabilities assumed. The final allocation for this acquisition may be different from the preliminary estimates presented below. The impact of any adjustments to the final allocation is not expected to be material to the Partnership’s results for the year ended December 31, 2007 (in thousands):

Assets purchased:
Buildings, docks, terminal facilities and improvements	$	88,771
Land	21,434
Fixtures, equipment and automobiles	415
Total assets purchased	110,620

Less environmental liabilities assumed (see Note 14)	(8,000		)

Total purchase price	$	102,620

Note 14. Environmental Liabilities

The Partnership currently owns or leases properties where refined petroleum products are being or have been handled. These properties and the refined petroleum products handled thereon may be subject to federal and state environmental laws and regulations. Under such laws and regulations, the Partnership could be required to remove or remediate containerized hazardous liquids or associated generated wastes (including wastes disposed of or abandoned by prior owners or operators), to clean up contaminated property arising from the release of liquids or wastes to the environment, including contaminated groundwater, or to implement best management practices to prevent future contamination.

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

In connection with the purchase of ExxonMobil’s Albany and Newburgh, New York and Burlington, Vermont terminals in May, 2007, the Partnership identified certain environmental liabilities which it assumed, including the remediation obligations under a proposed remedial action plan submitted by ExxonMobil to the New York Department of Environmental Conservation (“NYDEC”) with respect to the Albany, New York terminal. As a result, the Partnership recorded, on an undiscounted basis, total environmental liabilities of $8.0 million of which $0.5 million was recorded as a current liability and $7.5 million was recorded as a long-term liability on the accompanying consolidated balance sheet at June 30, 2007.

In connection with the 2006 acquisition of its Macungie, Pennsylvania terminal (the “Global Macungie Terminal”), the Partnership assumed certain existing environmental liabilities at the terminal. The Partnership did not accrue for these contingencies as it currently believes that the aggregate amount of these liabilities cannot be reasonably estimated at this time. The Partnership also executed an Administrative Order on Consent (“AOC”) with the U.S. Environmental Protection Agency, Region III (“EPA”) requiring certain investigatory activities at the Global Macungie Terminal. Although the Partnership cannot predict the outcome of the investigation of the Global Macungie Terminal, based upon current information, the Partnership does not anticipate that the outcome will have a material adverse effect on it. Furthermore, the Partnership does not believe that compliance with the terms of the AOC executed by it will result in material costs or have a material impact on the Partnership’s operations.

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

Note 15. Property and Equipment

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

	June 30, 2007			December 31, 2006

Buildings, docks, terminal facilities and improvements	$	117,777		$	27,598
Land	26,852			5,418
Fixtures, equipment and automobiles	5,525			3,508
	150,154			36,524
Less accumulated depreciation	(7,269		)	(4,867		)
Total	$	142,885		$	31,657

The increase of approximately $113.6 million in property and equipment and $2.4 million in accumulated depreciation is primarily due to the Partnership’s acquisition of three refined petroleum products terminals from ExxonMobil (see Note 13).

Note 16. 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 and six months ended June 30, 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 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 June 30, 2007. Based on such evaluation, the Partnership concluded that there were no significant uncertain tax positions requiring recognition in its financial statements as of June 30, 2007. As such, the adoption of FIN 48 did not impact the Partnership’s consolidated financial condition, results of operations or cash flows.

Note 17. Recent Accounting Pronouncements

In February 2007, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS No. 159”) which provides entities with an option to measure many financial instruments and certain other items at fair value that are not currently measured at fair value. The election to use the fair value option is available when an entity first recognizes a financial asset or financial liability or upon entering into a firm commitment. Subsequent changes in fair value must be recorded in earnings. This statement also establishes presentation and disclosure requirements designed to facilitate comparisons between entities that choose different measurement attributes for similar types of assets and liabilities. SFAS No. 159 is effective for financial statements issued 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. 159 on its consolidated financial statements.

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.

Note 18. Subsequent Events

The General Partner’s board of directors declared a quarterly cash distribution of $0.4725 per unit ($1.89 per unit on an annualized basis) for the period from April 1, 2007 through June 30, 2007. On August 14, 2007, the Partnership will pay this cash distribution to its common and subordinated unitholders of record as of the close of business August 3, 2007.

On July 9, 2007, the Partnership announced that it entered into a Terminals and Sale Purchase Agreement to acquire two refined petroleum products terminals located in Glenwood Landing and Inwood, New York from ExxonMobil for cash consideration of approximately $34.7 million.

On August 6, 2007, pursuant to the Registration Rights Agreement described in Note 12, the Partnership filed a Registration Statement on Form S-3 with the SEC for the registration of 1,785,715 common units. This Registration Statement is intended to satisfy the Partnership’s obligation to register the common units into which Class B units issued to the Purchasers in the Private Placement described in Note 12 converted on May 22, 2007.

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 I, Item 1A, “Risk Factors,” in our Annual Report on Form 10-K for the year ended December 31, 2006 and in Part II, Item 1A, “Risk Factors,” in this Quarterly Report on Form 10-Q.

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.

Reconciliation of Net (Loss) Income Available to Limited Partners

In connection with the private placement of Class B units (see Note 12 of Notes to Financial Statements), we were required to take into account the effect of EITF 98-05. As a result, a non-cash reduction in net income available to limited partners was recorded. This non-cash reduction is required to be recorded pursuant to EITF 98-05 because the fair value of our common units on May 9, 2007 (the date on which the Class B units were issued) was greater than the purchase price of the Class B units, which was established at the time of the execution of the Unit Purchase Agreement on March 14, 2007. Although EITF 98-05 affects net income available to limited partners, it does not affect net income or distributable cash flow to limited partners, nor does it affect total unitholders’ equity.

The following sets forth the reconciliation of net (loss) income available to limited partners for the periods presented (in thousands, except per unit data):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2007			2006			2007			2006

Net income	$	610		$	3,480		$	33,485		$	16,168
Less: General Partner’s general partner interest	(11		)	(70		)	(668		)	(324		)
Net income available to limited partners before the effect of EITF 98-05	599			3,410			32,817			15,844
Less: Non-cash reduction under EITF 98-05 allocated to limited partners	(16,400		)	—			(16,400		)	—
Net (loss) income available to limited partners	(15,801		)	3,410			16,417			15,844
Less: Dilutive impact of theoretical distribution of earnings	—			—			(12,405		)	(2,872		)
Net (loss) income available to limited partners under EITF 03-06 and EITF 98-05	$	(15,801	)	$	3,410		$	4,012		$	12,092

Per unit data:
Net (loss) income per diluted limited partner unit under EITF 03-06 and EITF 98-05	$	(1.28	)	$	0.30		0.47			$	1.15
Dilutive impact of non-cash reduction under EITF 98-05 allocated to limited partner units	1.33			—			1.33			—
Dilutive impact of theoretical distribution of earnings	—			—			1.10			0.25
Adjusted net income per diluted limited partner unit(1)	$	0.05		$	0.30		2.90			1.40

As noted above, the effect of EITF 98-05 does not affect distributable cash flow. The following is a reconciliation of net income to distributable cash flow for the periods presented (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2007			2006			2007			2006
Reconciliation of net income to distributable cash flow(2):
Net income	$	610		$	3,480		$	33,485		$	16,168
Depreciation and amortization	2,067			1,088			3,336			2,160
Gain on sale of investment	—			—			(14,118		)	—
Maintenance capital expenditures	(1,100		)	(411		)	(1,867		)	(515		)
Distributable cash flow	$	1,577		$	4,157		$	20,836		$	17,813

(1) Adjusted net income per diluted limited partner unit is a non-GAAP financial measure used to measure our financial performance on a per-unit basis and is discussed below under “Evaluating Our Operating Results.”

(2) Distributable cash flow is a non-GAAP financial measure used for our limited partners since it serves as an indicator of our success in providing a cash return on their investment and is discussed below under “Evaluating Our Operating Results.”

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. For the three and six months ended June 30, 2007, we sold approximately $1.4 billion and $3.0 billion, respectively, 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 including, without limitation, transportation fuels 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.

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.

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.

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 and a non-cash reduction in net income available to limited partners under EITF 98-05, 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.

The non-cash reduction under EITF 98-05 is the result of accounting for the sale of Class B units (see Note 12 of Notes to Financial Statements). Although EITF 98-05 affects net income available to limited partners, it does not affect net income or distributable cash flow to limited partners, nor does it affect total unitholders equity.

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 EBITDA 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 for the six months ended June 30, 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.

Three and Six Months Ended June 30, 2007 and 2006

During the second quarter ended June 30, 2007, we experienced higher sales volumes primarily due to our terminal acquisitions and cooler-than-normal temperatures. Additionally, we benefited from margin expansion, volume expansion related to our terminal acquisitions and volume expansion due to weather that enabled us to achieve a higher net product margin in our wholesale distillate business and favorable market conditions that enabled us to achieve a higher net product margin in our residual oil business as compared to the same period in 2006. Commodity prices continued to rise for the three and six months ended June 30, 2007. Temperatures were 4% colder and 2% colder than normal for the three and six months ended June 30, 2007, respectively, and 7% colder and 10% colder than last year for the three and six months ended June 30, 2007, respectively, as measured by aggregate heating degree days.

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 June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
Net income as adjusted for one-time gains (1)	$	610		$	3,480		$	19,367		$	16,168

Adjusted net income per diluted limited partner unit (2)	$	0.05		$	0.30		$	2.90		$	1.40

Adjusted EBITDA (3)	$	5,563		$	6,644		$	29,430		$	23,404

Distributable cash flow (4)	$	1,577		$	4,157		$	20,836		$	17,813

Wholesale Segment:
Volume (gallons)	630,155			462,087			1,440,977			1,150,571
Sales	$	1,304,171		$	950,801		$	2,744,781		$	2,147,780
Net product margin (5)
Distillates	$	12,555		$	5,992		$	39,296		$	25,589
Gasoline	2,316			7,166			3,934			10,402
Residual oil	5,488			5,266			15,372			9,920
Total	$	20,359		$	18,424		$	58,602		$	45,911
Commercial Segment:
Volume (gallons)	53,223			56,827			148,773			166,307
Sales	$	79,919		$	80,552		$	212,485		$	234,596
Net product margin (5)	$	2,634		$	2,644		$	7,234		$	7,780
Combined sales and net product margin:
Sales	$	1,384,090		$	1,031,353		$	2,957,266		$	2,382,376
Net product margin (5)	$	22,993		$	21,068		$	65,836		$	53,691
Depreciation allocated to cost of sales	1,371			424			1,962			830
Combined gross profit	$	21,622		$	20,644		$	63,874		$	52,861

Weather conditions:
Normal heating degree days	784			784			3,654			3,654
Actual heating degree days	817			762			3,735			3,397
Variance from normal heating degree days	4		%	(3		)%	2		%	(7		)%
Variance from prior period actual heating degree days	7		%	(16		)%	10		%	(14		)%

(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.

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 June 30,				Six Months Ended June 30,
	2007		2006		2007			2006
Reconciliation of net income to net income as adjusted for one-time gains:
Net income	$	610	$	3,480	$	33,485		$	16,168
Gain on sale of investment	—		—		(14,118		)	—
Net income as adjusted for one-time gains	$	610	$	3,480	$	19,367		$	16,168

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 June 30,					Six Months Ended June 30,
	2007			2006		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 and EITF 98-05	$	(1.28	)	$	0.30	$	0.47	$	1.15
Dilutive impact of non-cash reduction under EITF 98-05	1.33			—		1.33		—
Dilutive impact of theoretical distribution of earnings	—			—		1.10		0.25
Adjusted net income per diluted limited partner unit	$	0.05		$	0.30	$	2.90	$	1.40

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 June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
Reconciliation of net income to EBITDA and Adjusted EBITDA:
Net income	$	610		$	3,480		$	33,485		$	16,168
Depreciation and amortization	2,067			1,088			3,336			2,160
Interest expense	2,523			1,786			5,839			4,106
Income tax expense	363			290			888			970
EBITDA	5,563			6,644			43,548			23,404
Gain on sale of investment	—			—			(14,118		)	—
Adjusted EBITDA	$	5,563		$	6,644		$	29,430		$	23,404

Reconciliation of cash flow (used in) provided by operating activities to EBITDA and Adjusted EBITDA:
Cash flow (used in) provided by operating activities	$	(39,431	)	$	(44,350	)	$	101,297		$	12,239
Net changes in operating assets and liabilities	42,108			48,918			(64,476		)	6,089
Interest expense	2,523			1,786			5,839			4,106
Income tax expense	363			290			888			970
EBITDA	5,563			6,644			43,548			23,404
Gain on sale of investment	—			—			(14,118		)	—
Adjusted EBITDA	$	5,563		$	6,644		$	29,430		$	23,404

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 June 30,						Six Months Ended June 30,
	2007			2006			2007			2006
Reconciliation of net income to distributable cash flow:
Net income	$	610		$	3,480		$	33,485		$	16,168
Depreciation and amortization	2,067			1,088			3,336			2,160
Gain on sale of investment	—			—			(14,118		)	—
Maintenance capital expenditures	(1,100		)	(411		)	(1,867		)	(515		)
Distributable cash flow	$	1,577		$	4,157		$	20,836		$	17,813

Reconciliation of cash flow (used in) provided by operating activities to distributable cash flow:
Cash flow (used in) provided by operating activities	$	(39,431	)	$	(44,350	)	$	101,297		$	12,239
Net changes in operating assets and liabilities	42,108			48,918			(64,476		)	6,089
Gain on sale of investment	—			—			(14,118		)	—
Maintenance capital expenditures	(1,100		)	(411		)	(1,867		)	(515		)
Distributable cash flow	$	1,577		$	4,157		$	20,836		$	17,813

Consolidated Results

Our total sales for the second quarter of 2007 increased by $352.7 million, or 34%, to $1,384.1 million compared to $1,031.4 million for the same period in 2006. The increase was driven primarily by our terminal acquisitions in Albany and Newburgh, New York and Burlington, Vermont in May 2007 and in Bridgeport, Connecticut and Macungie, Pennsylvania in 2006 and increased heating oil sales due to colder-than-normal temperatures. Our aggregate volume of product sold increased by approximately 164 million gallons, or 32%, to 683 million gallons. The increase in volume primarily includes increases of 85 million and 91 million gallons in distillates and gasoline, respectively, as a result of our terminal acquisitions and higher-than-normal heating degree days. The increase in volume was offset by an 8 million gallon decrease in residual oil. The number of actual heating degree days increased 7% to 817 compared with 762 for the quarters ended June 30, 2007 and 2006, respectively. Our gross profit for the second quarter of 2007 was $21.6 million, an increase of $1.0 million, or 5%, compared to $20.6 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, offset by a decline in gasoline margins.

Our total sales for the six months ended June 30, 2007 increased by $574.9 million, or 24%, to $2,957.3 million compared to $2,382.4 million for the same period in 2006. The increase was driven primarily by our terminal acquisitions in Albany and Newburgh, New York and Burlington, Vermont in May 2007 and in Bridgeport, Connecticut and Macungie, Pennsylvania in 2006 and increased heating oil sales due to colder-than-normal temperatures. Our aggregate volume of product sold increased by approximately 273 million gallons, or 21%, to 1,589 million gallons. The increase in volume primarily includes increases of 182 million and 132 million gallons in distillates and gasoline, respectively, as a result of our terminal acquisitions and higher-than-normal heating degree days. The increase in volume was offset by a 33 million gallon decrease in residual oil. The number of actual heating degree days increased by approximately 10% to 3,735 compared to 3,397 for the six months ended June 30, 2007 and 2006, respectively. Our gross profit for the six months ended June30, 2007 was $63.9 million, an increase of $11.0 million, or 21% compared to $52.9 million for the same period in 2006. The increases in our gross profits for the three and six months ended June 30, 2007 were primarily due to higher net product margins in distillates and residual oil.

Wholesale Segment

Distillates. Wholesale distillate sales for the three months ended June 30, 2007 were $584.1 million compared to $424.3 million for three months ended June 30, 2006. During the first six months of 2007, wholesale distillate sales were $1,632.9 million compared to $1,284.8 million for the same period in 2006. The increases of $159.8 million, or 38%, and $348.1 million, or 27%, for the three and six months ended June 30, 2007, respectively, were due to increases in volume sold and in distillate prices for the three and six months ended June 30, 2007 compared to the same periods in 2006. We attribute the increases in volume sold to the 2006 terminal acquisitions in Bridgeport, Connecticut and Macungie, Pennsylvania and our recent terminal acquisitions in Albany and Newburgh, New York and Burlington, Vermont, as well as to temperatures that were 4% colder and 2% colder than normal for the three and six months ended June 30, 2007, respectively, and 7% colder and 10% colder than last year for the three and six months ended June 30, 2007, respectively.

Our net product margin contribution from distillate sales increased by $6.6 million, or 110%, to $12.6 million for the three months ended June 30, 2007 and by $13.7 million, or 54%, to $39.3 million for the six months ended June 30, 2007 compared to the same periods in 2006. The increases were, in part, the result of margin expansion, volume expansion related to our terminal acquisitions in Albany and Newburgh, New York and Burlington, Vermont in May 2007 and Bridgeport, Connecticut and Macungie, Pennsylvania in 2006, and additional volume expansion due to colder-than-normal temperatures in 2007 and colder weather during the three and six months ended June 30, 2007 compared to the same periods in 2006.

Gasoline. Wholesale gasoline sales for the three months ended June 30, 2007 were $698.0 million compared to $497.7 million for the same period in 2006. During the first six months of 2007, wholesale gasoline sales were $1,079.3 million compared to $804.3 million for the same period in 2006. The increases of $200.3 million, or 40%, and $274.9 million, or 34%, for the three and six months ended June 30, 2007, respectively, were due to our recent acquisition of the Albany and Newburgh, New York and Burlington, Vermont terminals and increases in gasoline volume sold and prices.

Our net product margin from gasoline sales decreased by $4.8 million, or 68%, to $2.3 million for the three months ended June 30, 2007 and by $6.5 million, or 62%, to $3.9 million for the six months ended June 30, 2007 compared to the same periods in 2006. We attribute these decreases in net product margin to the return of margins to more historical norms as the industry adjusts to the introduction of ethanol-based gasoline, narrower net product margins generally and some initial start-up supply costs at the new Albany and Newburgh, New York and Burlington, Vermont terminals.

Residual Oil. Wholesale residual oil sales for the three months ended June 30, 2007 were $22.1 million compared to $28.8 million for the three months ended June 30, 2007. During the first six months of 2007, residual oil sales were $32.7 million compared to $58.6 million for the same period in 2006. The decreases of $6.7 million, or 23%, and $25.9 million, or 44%, for the three and six months ended June 30, 2007, respectively, compared to the same periods in 2006 were the result of declines in residual oil volume sold attributable to competitive pricing and competition from alternative products.

Our net product margin contribution from residual oil sales increased $0.2 million, or 4%, to $5.5 million for the three months ended June 30, 2007 and $5.4 million, or 55%, to $15.4 million for the six months ended June 30, 2007 compared to the same periods in 2007, primarily due to favorable market conditions.

Commercial Segment

In our Commercial segment, residual oil accounted for approximately 74% and 78% of total commercial volume sold for the three months ended June 30, 2007 and 2006, respectively, and approximately 78% and 82% of total commercial volume sold for the six months ended June 30, 2007 and 2006, respectively. Distillates, gasoline and natural gas accounted for the remainder of the total volume sold.

Commercial residual oil sales for the quarter ended June 30, 2007 decreased by 4% compared to the same period in 2006 due to an 8% decrease in volume sold. For the six months ended June 30, 2007, residual oil sales decreased by 14% compared to the same period in 2006 due to a 14% decrease in volume sold. We attribute the decreases in volume sold to competitive pricing and competition from alternative products.

Selling, General and Administrative Expenses

Attributed, in part, to the extension of our terminal network, SG&A expenses increased by $2.1 million, or 22%, to $11.5 million for the three months ended June 30, 2007 compared to $9.4 million for the same period in 2006. During the second quarter of 2007, we had increases of approximately $1.2 million in salaries and accrued bonuses, $0.3 million in licensing fees and insurance premiums, $0.1 million in professional and consulting fees and $0.5 million in other SG&A expenses.

During the six months ended June 30, 2007, SG&A expenses increased by $4.5 million, or 22%, to $24.9 million compared to $20.3 million for the same period in 2006. The increase was primarily due to approximately $2.3 million in salaries and accrued bonuses, $0.9 million in professional and consulting fees, $0.4 million in licensing fees and insurance premiums, $0.3 million related to employee vacation benefits and $0.6 million in other SG&A expenses.

Operating Expenses

Operating expenses increased by $1.0 million, or 19%, to $6.3 million for the three months ended June 30, 2007 compared to $5.3 million for the same period in 2006. The increase was primarily due to $0.6 million in costs associated with operating our newly acquired Albany and Newburgh, New York and Burlington, Vermont terminals, $0.4 million in costs associated with operating our Bridgeport, Connecticut and Macungie, Pennsylvania facilities, $0.1 million in increased rent for additional tankage and $0.1 million in repair expenses at the Capital Terminal in East Providence, Rhode Island and $0.2 million in other operating expenses, offset by $0.4 million for the expansion of storage and delivery systems at an alternative location in New Bedford, Massachusetts during the second quarter of 2006.

Operating expenses for the six months ended June 30, 2007 increased by $1.4 million, or 13%, to $12.2 million compared to $10.8 million for the same period in 2006. The increase was primarily due to $0.8 million in costs associated with operating our Bridgeport, Connecticut and Macungie, Pennsylvania facilities, $0.6 million in costs associated with operating our newly acquired Albany and Newburgh, New York and Burlington, Vermont terminals, $0.1 million in increased rent at our Gateway terminal, $0.1 million in increased rent for additional tankage and $0.1 million in repair expenses at the Capital Terminal in East Providence, Rhode Island and $0.5 million in other operating expenses, offset by $0.3 million in pipeline repair expenses and $0.5 million for the expansion of storage and delivery systems at an alternative location in New Bedford, Massachusetts incurred during the six months ended June 30, 2006.

Interest Expense

Interest expense for the three months ended June 30, 2007 increased by $0.7 million, or 41%, to $2.5 million compared to $1.8 million for the same period in 2006. Interest expense for the six months ended June 30, 2007 increased by $1.7 million, or 42%, to $5.8 million compared to $4.1 million for the same period in 2006. We attribute the increases primarily to borrowing on our acquisition facility to fund the acquisition of the Albany and Newburgh, New York and Burlington, Vermont terminals, higher average balances on our revolving line of credit and higher average interest rates during the three and six months ended June 30, 2007.

Other Income

Other income for the three and six months ended June 30, 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 and six months ended June 30, 2007. See Note 11 of Notes to Financial Statements.

Gain on Sale of Investment

The $14.1 million gain on sale of investment for the six months ended June 30, 2007 represented the amount we realized on the March 2007 sale of our NYMEX seats and holdings. See Note 11 of Notes to Financial Statements.

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 provide our primary sources of liquidity. Working capital was $143.8 million at June 30, 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, and on April 9, 2007, the SEC declared the registration statement effective.

On May 9, 2007, we issued 1,785,715 Class B units in a private placement from which we received gross proceeds of $50.0 million. The Class B units were convertible into common units on a one-for-one basis. 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 and (ii) $0.4650, the amount of our first quarter per unit distribution that was paid to the common and subordinated unitholders on May 15, 2007. Such discount was paid by us to the purchasers of the Class B units substantially contemporaneously with the payment of our first quarter distribution. On May 22, 2007, the Class B units converted into common units on a one-for-one basis. See Note 12 of Notes to Financial Statements for additional information on the private placement.

On May 9, 2007, we completed the acquisition of three refined petroleum products terminals located in Albany and Newburgh, New York and Burlington, Vermont from ExxonMobil for cash consideration of approximately $101.5 million plus $1.1 million in acquisition costs, for an aggregate purchase price of $102.6 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 private placement of Class B units discussed above. See Note 13 of Notes to Financial Statements for additional information on the acquisition.

On May 15, 2007, we paid a cash distribution of $5.4 million for the first quarter of 2007 to our common and subordinated unitholders of record as of the close of business on May 4, 2007.

On July 24, 2007, our General Partner’s board of directors declared a quarterly cash distribution of $0.4725 per unit on all of our outstanding common and subordinated units for the second quarter of 2007 to our common and subordinated unitholders of record as of the close of business August 3, 2007. We expect to pay the cash distribution of approximately $6.3 million on August 14, 2007.

On August 6, 2007, pursuant to the Registration Rights Agreement described in Note 12 of Notes to Financial Statements, we filed a Registration Statement on Form S-3 with the SEC for the registration of 1,785,715 common units. This Registration Statement is intended to satisfy our obligation to register the common units into which Class B units issued to the Purchasers in the Private Placement described in Note 12 of Notes to Financial Statements converted on May 22, 2007.

Capital Expenditures

Our terminalling operations require investments to expand, upgrade and 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 $1.9 million and $0.5 million in maintenance capital expenditures for the six months ended June 30, 2007 and 2006, respectively, which are included in capital expenditures in the accompanying consolidated statements of cash flows. 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 our business and to expand existing facilities, such as projects that increase operating capacity by increasing tankage or adding terminals. We had approximately 1.1 million and $2.7 million in capital improvement expenditures for the six months ended June 30, 2007 and 2006, respectively, which are included in capital expenditures in the accompanying consolidated statements of cash flows, to increase our operating capacity and capabilities. In addition, in May of 2007, we acquired three refined petroleum products terminals located in Albany and Newburgh, New York and Burlington, Vermont from ExxonMobil for cash consideration of approximately $101. 5 million plus $1.1 million in acquisition costs, for an aggregate purchase price of $102.6 million. In May of 2006, we acquired the Bridgeport, Connecticut facility for approximately $2.3 million.

We also made some investments in our information technology infrastructure to maintain uniformity among all our locations as we add acquired assets. For example, we are implementing an enterprise wide system that provides us real-time access to information about inventory, pricing and sales by locations.

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 an adverse effect on our borrowing capacity.

Cash Flow

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

	Six Months Ended June 30,
	2007			2006

Net cash provided by operating activities	$	101,297		$	12,239
Net cash used in investing activities	$	(90,375	)	$	(5,494	)
Net cash used in financing activities	$	(12,256	)	$	(7,574	)

Cash flow from operating activities generally increases during the second quarter since accounts receivable, accounts payable and inventories generally contract as we enter the season when sales from heat-based products are lower. Net cash provided by operating activities increased by $89.1 million for the six months ended June 30, 2007 compared to the same period in 2006 and primarily reflects increased earnings of $17.3 million, a $75.7 million change in fair value of our forward fixed contracts as these contracts are honored by our customers during our heating season and a $48.6 million decrease in inventories as we exit our peak season, offset by the increase in the carrying value of accounts receivable due to increased sales associated with our recent terminal acquisitions and colder-than-normal temperatures.

Net cash used in investing activities increased by $84.9 million for the six months June 30, 2007 compared to the same period in 2006, and included approximately $102.6 million to acquire the Albany and Newburgh, New York and Burlington, Vermont terminals and a total of $3.0 million in other capital expenditures, offset by gross proceeds of $15.3 million from the sale of our investment in NYMEX Holdings and related NYMEX seats.

Net cash used in financing activities increased by $4.7 million for the six months ended June 30, 2007 compared to the same period in 2006 and included a net change in our credit facilities of $50.6 million consisting of $87.1 million in payments on our revolving line of credit and $36.5 million in proceeds from our acquisition line of credit to fund the purchase of the Albany and Newburgh, New York and Burlington, Vermont terminals, and $10.6 million in cash distributions to our common and subordinated unitholders for the six months ended June 30, 2007, offset by net proceeds of $49.1 million from the issuance of Class B units.

Credit Agreement

We, our general partner, our operating company and our operating subsidiaries have a four-year senior secured credit agreement with total available commitments of $650.0 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. The credit agreement will mature on April 22, 2011.

At June 30, 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;

· an $85.0 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.

In addition, provided no Event of Default (as defined in the Credit Agreement) then exists, the we may request to increase: (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.

At June 30, 2007, borrowings under our working capital revolving credit, acquisition and revolving credit facilities bear interest at our option at (1) the Eurodollar rate, plus 1%, 1½% 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 rates for the three and six months ended June 30, 2007 were 6.4% and 6.3%, respectively. 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 June 30, 2007, we had total borrowings outstanding under our working capital revolving credit facility of $220.1 million and outstanding letters of credit of $59.0 million, for a total indebtedness of $279.1 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.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

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 17 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 one interest rate collar to manage exposure to interest rate risk and various derivative instruments to manage exposure to commodity risk.

Interest Rate Risk

We utilize variable rate debt and are exposed to market risk due to the floating interest rates on our 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.

Borrowings under our working capital revolving credit, acquisition credit and revolving credit facilities bear interest at our option at (1) the Eurodollar rate, plus 1%, 1½% and 1½ %, respectively, (2) the cost of funds rate, plus 1%, 1¾% and 1½ %, respectively, or (3) the bank’s base rate (the average rates for the three and six months ended June 30, 2007 were 6.4% and 6.3%, respectively). As of June 30, 2007, we had total borrowings outstanding under our working capital revolving credit facility of $220.1 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 $2.2 million annually, assuming, however, that our indebtedness remained constant throughout the year.

On May 10, 2007, we executed a zero premium interest rate collar with a major financial institution. The collar, which became effective on May 14, 2007, is used to hedge the variability in interest payments due to changes in the three-month LIBOR rate with respect to $100.0 million of long-term three-month LIBOR-based borrowings. Under the contract, we capped our exposure at a maximum three-month LIBOR rate of 5.75%. In addition, we established a minimum floor three-month LIBOR rate of 3.75%. As of June 30, 2007, the three-month LIBOR rate of 5.36% was within the cap and floor. Whenever the three-month LIBOR rate is greater than the cap, we receive from the financial institution the difference between the cap and the current three-month LIBOR rate on the $100.0 million of long-term three-month LIBOR-based borrowings. Conversely, whenever the three-month LIBOR rate is lower than the floor, we remit to the financial institution the difference between the floor and the current three-month LIBOR rate on the $100.0 million of long-term three-month LIBOR-based borrowings. As of June 30, 2007, the three-month LIBOR rate of 5.36% was within the cap and floor. The collar, which expires on May 14, 2011, is designated as a cash flow hedge and accounted for under the provisions of SFAS No. 133, as amended (see Note 5 of Notes to Financial Statements).

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 affect our profit. 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 June 30, 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):

Gain (loss):

	Fair Value at June 30, 2007			Effect of 10% Price Decrease

NYMEX contracts	$	2,405		$	8,591
Swaps, options and other, net	(795		)	654
	$	1,610		$	9,245

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 June 30, 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 $4.6 million at June 30, 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.

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 June 30, 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 and accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

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 June 30, 2007 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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 below and 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.

In November 2006, the EPA notified Global Companies LLC, as the operator of a refined petroleum product marketing and bulk storage terminal in Macungie, Pennsylvania of the EPA’s intention to negotiate an AOC with Global Companies LLC and the previous owner and owners of an adjacent terminal, to investigate and remediate in the soil and groundwater at the two sites. In July 2007, Global Companies LLC and the previous owner of the Global Macungie Terminal executed an AOC with the EPA requiring investigatory activities, including additional groundwater monitoring and soil sampling at the Global Macungie Terminal. In addition, the AOC executed by Global Companies LLC does not impose any obligations on Global Companies LLC relative to the adjacent terminal. At the same time, the parties associated with the adjacent terminal entered into separate AOCs with the EPA. Although we cannot predict the outcome of said additional investigation of the Global Macungie Terminal, based upon our current information, we do not anticipate that either outcome will have a material adverse effect on us. Furthermore, we do not believe that compliance with the terms of the AOC executed by us will result in material costs or have a material impact on our operations.

In connection with our May 2007 acquisition of ExxonMobil’s Albany and Newburgh, New York and Burlington, Vermont terminals, we assumed certain environmental liabilities, including the remediation obligations under a proposed remedial action plan submitted by ExxonMobil to the NYDEC with respect to the Albany, New York terminal. In connection with the acquisition, we recorded an environmental reserve of $8.0 million in respect of the assumed environmental liabilities. NYDEC is currently reviewing the proposed remedial action plan submitted by ExxonMobil. Subject to NYDEC’s approval of the proposed remedial action plan, we do not believe that compliance with the terms thereof will result in material costs in excess of the environmental reserve or have a material impact on our operations.

Item 1A. Risk Factors

Please refer to our Annual Report on Form 10-K for the year ended December 31, 2006 for additional risk factors.

Tax Risks

We have adopted certain valuation methodologies that may result in a shift of income, gain, loss and deduction between the general partner and the unitholders. The IRS may challenge this treatment, which could adversely affect the value of the common units.

When we issue additional units or engage in certain other transactions, we determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner. Although we may from time to time consult with professional appraisers regarding valuation matters, including the valuation of our assets, we make many of the fair market value estimates of our assets ourselves using a methodology based on the market value of our common units as a means to measure the fair market value of our assets. Our methodology may be viewed as understating the value of our assets. In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and the general partner, which may be unfavorable to such unitholders. Moreover, under our current valuation methods, subsequent purchasers of common units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS may challenge our valuation methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of income, gain, loss and deduction between the general partner and certain of our unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our unitholders. It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.

Item 6. Exhibits

3.1		—	Second Amended and Restated Agreement of Limited Partnership of Global Partners LP, dated as of May 9, 2007 (incorporated herein by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on May 10, 2007).

4.1		—	Registration Rights Agreement, dated May 9, 2007, by and between Global Partners LP and the purchasers named therein (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on May 10, 2007).

10.1		—	Terminals Sale and Purchase Agreement, dated March 16, 2007, by and between Global Partners LP and ExxonMobil Oil Corporation.

10.2		—	Third Amendment to Credit Agreement, dated as of April 24, 2007, among Global Operating LLC, Global Companies LLC, Global Montello Group Corp., Glen Hes Corp. and Chelsea Sandwich LLC, as borrowers, Global Partners LP and Global GP LLC, as guarantors, each lender from time to time party thereto, and Bank of America, N.A., as Administrative Agent and L/C Issuer (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on April 26, 2007).

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.

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: August 9, 2007

By:

/s/ Eric Slifka

Eric Slifka

President and Chief Executive Officer

(Principal Executive Officer)

Dated: August 9, 2007

By:

/s/ Thomas J. Hollister

Thomas J. Hollister

Executive Vice President, Chief Operating Officer
and Chief Financial Officer

(Principal Financial Officer)

INDEX TO EXHIBITS

Exhibit Number			Description

3.1		—	Second Amended and Restated Agreement of Limited Partnership of Global Partners LP, dated as of May 9, 2007 (incorporated herein by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on May 10, 2007).

4.1		—	Registration Rights Agreement, dated May 9, 2007, by and between Global Partners LP and the purchasers named therein (incorporated herein by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on May 10, 2007).

10.1		—	Terminals Sale and Purchase Agreement, dated March 16, 2007, by and between Global Partners LP and ExxonMobil Oil Corporation.

10.2		—	Third Amendment to Credit Agreement, dated as of April 24, 2007, among Global Operating LLC, Global Companies LLC, Global Montello Group Corp., Glen Hes Corp. and Chelsea Sandwich LLC, as borrowers, Global Partners LP and Global GP LLC, as guarantors, each lender from time to time party thereto, and Bank of America, N.A., as Administrative Agent and L/C Issuer (incorporated herein by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on April 26, 2007).

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.