UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K/A

(Amendment No. 1)

(Mark One)

þ		Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

o		Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission file number 1-9356

Buckeye Partners, L.P.

(Exact name of registrant as specified in its charter)

Delaware		23-2432497
(State or other jurisdiction of incorporation or organization)		(IRS Employer Identification number)
One Greenway Plaza Suite 600 Houston, TX		77046
(Address of principal executive offices)		(Zip Code)

		Name of each exchange on
Title of each class		which registered
Limited partner units representing limited partnership interests		New York Stock Exchange

None

     Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes þ   No o

     Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
Yes o No þ

     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 þ No o

     Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Date File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes o No o

     Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ

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

Large accelerated filer þ

Accelerated filer o

Non-accelerated filer o (Do not check if a smaller reporting company)

Smaller reporting company o

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

     At June 30, 2009, the aggregate market value of the registrant’s limited partner units held by non-affiliates was $2.1 billion. The calculation of such market value should not be construed as an admission or conclusion by the registrant that any person is in fact an affiliate of the registrant.

     Limited partner units outstanding as of February 19, 2010: 51,464,265

 

 

TABLE OF CONTENTS

				Page
Explanatory Note					2
		PART II
Item 7.		Management’s Discussion and Analysis of Financial Condition and Results of Operations			3
		PART IV
Item 15.		Exhibits, Financial Statement Schedules			27
EX-31.1
EX-31.2

EXPLANATORY NOTE

     Buckeye Partners, L.P. (“Buckeye”) is filing this Amendment No. 1 on Form 10-K/A (“Amendment No. 1”) to amend Item 7 and Item 15 of its Annual Report on Form 10-K for the fiscal year ended December 31, 2009, originally filed with the Securities and Exchange Commission on February 26, 2010 (the “Original Annual Report”). Buckeye is filing Amendment No. 1 for the sole purpose of removing certain credit agency ratings information in the Original Annual Report.

     As required by Rule 12b-15 of the Securities and Exchange Act of 1934, as amended, Buckeye is also filing as exhibits to Amendment No. 1 the certifications required under Section 302 of the Sarbanes-Oxley Act of 2002.

     Except for the foregoing, Amendment No. 1 neither alters the Original Annual Report nor updates the Original Annual Report to reflect events or developments since the date of filing of the Original Annual Report.

     For the convenience of the reader, this Amendment No. 1 restates in its entirety the section “Management’s Discussion and Analysis of Financial Condition and Results of Operations” from the Original Annual Report, although Buckeye is only removing certain credit agency ratings information.

PART II

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

     The following information should be read in conjunction with our consolidated financial statements and our accompanying notes thereto included in Item 8 of this Report. Our discussion and analysis includes the following:

	•		Overview of Business;
	•		General Outlook for 2010;
	•		2009 Developments — discusses major items impacting our results in 2009;
	•		Results of Operations — discusses material year-to-year variances in the consolidated statements of operations;
	•		Liquidity and Capital Resources — addresses available sources of liquidity and capital resources and includes a discussion of our capital spending;
	•		Critical Accounting Policies and Estimates — presents accounting policies that are among the most critical to the portrayal of our financial position and results of operations;
	•		Other Items — includes information related to contractual obligations, off-balance sheet arrangements and other matters; and
	•		Recent Accounting Pronouncements.

     This discussion contains forward-looking statements based on current expectations that are subject to risks and uncertainties, such as statements of our plans, objectives, expectations and intentions. Our actual results and the timing of events could differ materially from those anticipated or implied by the forward-looking statements discussed here as a result of various factors, including, among others, those set forth under “Cautionary Note Regarding Forward-Looking Statements” and “Risk Factors” herein.

     Our consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”).

Overview of Business

     Our primary business strategies are to generate stable cash flows, increase pipeline and terminal throughput and pursue strategic cash-flow accretive acquisitions that complement our existing asset base, improve operating efficiencies and allow increased cash distributions to Unitholders.

     We operate and report in five business segments: Pipeline Operations; Terminalling and Storage; Natural Gas Storage; Energy Services; and Development and Logistics. We previously referred to the Development and Logistics segment as the Other Operations segment. We renamed the segment to better describe the business activities conducted within the segment. See Note 23 in the Notes to Consolidated Financial Statements for a more detailed discussion of our business segments.

     Our principal line of business is the transportation, terminalling, storage and marketing of refined petroleum products in the United States for major integrated oil companies, large refined petroleum product marketing companies and major end users of refined petroleum products on a fee basis through facilities we own and operate. We own a major natural gas storage facility in northern California. We also operate pipelines owned by third parties under contracts with major integrated oil and chemical companies, and perform certain construction activities, generally for the owners of those third-party pipelines.

General Outlook for 2010

     During 2008 and 2009, demand for refined petroleum products was adversely impacted by the slowdown in the overall economy. In 2010, however, we anticipate that demand will level out as underlying economic conditions stabilize or improve. We expect that the aggregate rates for our transportation and storage services in 2010 will show modest increases despite the impact of negative economic conditions during 2009. Ultimately, our ability to

maintain or increase transportation and storage volumes and rates in 2010 will be largely dependent upon the strength of the overall economy and demand for refined petroleum products in the areas we serve.

     The capital markets strengthened considerably in 2009, compared to 2008, and we successfully accessed both the debt and equity markets to fund our 2009 growth initiatives. Although we have no specific plans to access the capital markets in 2010, should we elect to raise capital, we believe that, under current financial market conditions, we would be able to raise capital in both the debt and equity markets on acceptable terms.

     We expect that our earnings in 2010 will be positively impacted by the full year contribution from the refined petroleum products pipelines and terminals acquired from ConocoPhillips in November 2009, cost savings from the organizational restructuring completed in 2009, and incremental revenue from growth capital expenditures in 2009 and 2010.

     Throughout 2010, we will continue to evaluate opportunities to acquire or construct assets that are complementary to our business and support our long term growth strategy and will determine the appropriate financing structure for any opportunity we pursue.

2009 Developments

     Major items impacting our results in 2009 include:

Consolidated Statements of Operations

	•		In early 2009, we began a “best practices” review of our business and organization structure to identify improved business practices, operating efficiencies and cost savings in anticipation of changing needs in the energy markets. This review culminated in the approval by the Board of Directors of Buckeye GP of an organizational restructuring. The organizational restructuring included a workforce reduction of approximately 230 employees, in excess of 20% of our workforce. The program was initiated in the second quarter of 2009 and was substantially complete by the end of 2009. As part of the workforce reduction, we offered certain eligible employees the option of enrolling in a voluntary early retirement program, which approximately 80 employees accepted. The remaining affected positions have been eliminated involuntarily under our ongoing severance plan. Most terminations were effective as of July 20, 2009. The restructuring also included the relocation of some employees consistent with the goals of the reorganization. We have incurred $32.1 million of expenses in connection with this organizational restructuring for the year ended December 31, 2009. See Note 3 in the Notes to Consolidated Financial Statements for further discussion.
	•		We recorded a non-cash charge of $59.7 million during the year ended December 31, 2009 related to an impairment of Buckeye NGL. During the second quarter of 2009, we recorded a non-cash charge of $72.5 million. Effective January 1, 2010, we sold our interest in Buckeye NGL for $22.0 million. The sales proceeds exceeded the previously impaired carrying value of the NGL pipeline by $12.8 million resulting in the reversal of $12.8 million of the previously recorded asset impairment expense in the fourth quarter of 2009. The impairment and subsequent reversal is reflected within the category “Asset Impairment Expense” on our consolidated statements of operations. See Note 8 in the Notes to Consolidated Financial Statements for further discussion.
	•		We experienced a delay in the startup of the Kirby Hills Phase II expansion project in our Natural Gas Storage segment, which we initially expected to occur in April 2009. The project was ultimately placed into service in June 2009.
	•		We experienced lower Pipeline Operations product transportation volumes of 5.2% in 2009 as compared to 2008, which resulted in an approximate $19.0 million reduction in revenues.
	•		We recorded a favorable property tax settlement of $7.2 million from the City of New York in our Pipeline Operations segment, which is reflected within the category “Total costs and expenses” in our consolidated statements of operations.

Consolidated Balance Sheet and Capital Structure

	•		We completed an acquisition in 2009 of certain refined petroleum product terminals and pipeline assets from ConocoPhillips for approximately $54.4 million that was financed with borrowings under our Credit Facility.
	•		We incurred capital expenditures for internal growth projects of $63.8 million.
	•		We sold $275.0 million aggregate principal amount of 5.500% Notes due 2019 for net proceeds of $271.4 million in an underwritten public offering.
	•		We issued approximately 3.0 million LP Units in 2009 for net proceeds of approximately $104.6 million in an underwritten public offering.
	•		We amended the BES Credit Agreement to increase the borrowing capacity from $175.0 million to $250.0 million. Our Credit Facility was also amended to reduce the borrowing capacity from $600.0 million to $580.0 million.

Results of Operations

Consolidated Summary

     Adjusted EBITDA (as defined below) increased during the year ended December 31, 2009 compared to the year ended December 31, 2008 and during the year ended December 31, 2008 compared to the year ended December 31, 2007. Our revenues, operating income, net income and earnings per LP Unit decreased during the year ended December 31, 2009 compared to the year ended December 31, 2008, primarily due to the recognition of expenses in connection with our organizational restructuring, a non-cash charge for an asset impairment and, in the case of our revenue decrease, lower overall pipeline and terminalling and storage volumes resulting in lower revenues. Our revenues, operating income, net income and earnings per LP Unit increased during the year ended December 31, 2008 compared to the year ended December 31, 2007, primarily due to the expansion of our operations through acquisitions and to increases in interstate pipeline tariff rates and terminalling throughput fees. Overall pipeline volumes declined by 5.2% during the year ended December 31, 2009 compared to the year ended December 31, 2008 and 4.5% during the year ended December 31, 2008 compared to the year ended December 31, 2007.

     Our summary operating results were as follows for the periods indicated (in thousands):

		Year Ended December 31,
		2009				2008				2007
Revenues		$	1,770,372			$	1,896,652			$	519,347
Costs and expenses			1,561,929				1,643,031				317,267
Operating income			208,443				253,621				202,080
Earnings from equity investments			12,531				7,988				7,553
Interest and debt expense			(74,851	)			(74,387	)			(50,378	)
Other income			777				1,429				1,362
Income from continuing operations			146,900				188,651				160,617
Income from discontinued operations			—				1,230				—
Net income			146,900				189,881				160,617
Less: net income attributable to noncontrolling interests (1)			(5,918	)			(5,492	)			(5,261	)
Net income attributable to Buckeye Partners, L.P.		$	140,982			$	184,389			$	155,356
Earnings per LP Unit — diluted (2)		$	1.84			$	3.00			$	2.91

Adjusted EBITDA

     In the first quarter of 2009, we revised our internal management reports to provide senior management, including the Chief Executive Officer, more information about Adjusted EBITDA (as defined below). Adjusted EBITDA is now the primary measure used by senior management to evaluate our operating results and to allocate our resources.

     We define EBITDA, a measure not defined under GAAP, as net income attributable to our Unitholders from continuing operations before interest expense, income taxes and depreciation and amortization. EBITDA should not be considered an alternative to net income, operating income, cash flow from operations or any other measure of financial performance presented in accordance with GAAP. The EBITDA measure eliminates the significant level of non-cash depreciation and amortization expense that results from the capital-intensive nature of our businesses and from intangible assets recognized in business combinations. In addition, EBITDA is unaffected by our capital structure due to the elimination of interest expense and income taxes. We define Adjusted EBITDA, which is also a non-GAAP measure, as EBITDA plus non-cash deferred lease expense, which is the difference between the estimated annual land lease expense for our natural gas storage facility in the Natural Gas Storage segment to be recorded under GAAP and the actual cash to be paid for such annual land lease. In addition, we have excluded the Buckeye NGL impairment expense of $59.7 million and the reorganization expense of $32.1 million from Adjusted EBITDA in order to evaluate our results of operations on a comparative basis over multiple periods.

     The EBITDA and Adjusted EBITDA data presented may not be comparable to similarly titled measures at other companies because EBITDA and Adjusted EBITDA exclude some items that affect net income attributable to our Unitholders, and these items may vary among other companies. Our senior management uses Adjusted EBITDA to evaluate consolidated operating performance and the operating performance of the business segments and to allocate resources and capital to the business segments. In addition, our senior management uses Adjusted EBITDA as a performance measure to evaluate the viability of proposed projects and to determine overall rates of return on alternative investment opportunities.

     We believe that investors benefit from having access to the same financial measures that we use. Further, we believe that these measures are useful to investors because they are one of the bases for comparing our operating performance with that of other companies with similar operations, although our measures may not be directly comparable to similar measures used by other companies.

     The following table presents Adjusted EBITDA by segment and on a consolidated basis for the periods indicated, and a reconciliation of EBITDA and Adjusted EBITDA to net income attributable to our Unitholders, which is the most comparable GAAP financial measure (in thousands).

		Year Ended December 31,
		2009				2008				2007
Adjusted EBITDA:
Pipeline Operations		$	230,172			$	196,852			$	192,236
Terminalling and Storage			72,518				60,410				49,363
Natural Gas Storage			42,214				42,374				—
Energy Services			19,419				9,818				—
Development and Logistics			6,607				8,785				9,549
Total Adjusted EBITDA		$	370,930			$	318,239			$	251,148
GAAP Reconciliation:
Net income		$	146,900			$	189,881			$	160,617
Less: net income attributable to noncontrolling interests			(5,918	)			(5,492	)			(5,261	)
Less: Income from discontinued operations			—				(1,230	)			—
Net income attributable to Buckeye Partners, L.P. unitholders from continuing operations			140,982				183,159				155,356
Interest and debt expense			74,851				74,387				50,378
Income tax expense (benefit)			(348	)			796				763
Depreciation and amortization			59,164				55,299				44,651
EBITDA			274,649				313,641				251,148
Non-cash deferred lease expense			4,500				4,598				—
Asset impairment expense			59,724				—				—
Reorganization expense			32,057				—				—
Adjusted EBITDA		$	370,930			$	318,239			$	251,148

Segment Results

     A summary of financial information by business segment follows for the periods indicated (in thousands):

		Year Ended December 31,
		2009				2008				2007
Revenues:
Pipeline Operations		$	392,667			$	387,267			$	379,345
Terminalling and Storage			136,576				119,155				103,782
Natural Gas Storage			99,163				61,791				—
Energy Services			1,125,013				1,295,925				—
Development and Logistics			34,136				43,498				36,220
Intersegment			(17,183	)			(10,984	)			—
Total revenues		$	1,770,372			$	1,896,652			$	519,347
Total costs and expenses: (1)
Pipeline Operations		$	295,984			$	234,017			$	229,050
Terminalling and Storage			74,626				65,451				60,939
Natural Gas Storage			68,415				29,099				—
Energy Services			1,111,492				1,289,886				—
Development and Logistics			28,595				35,562				27,278
Intersegment			(17,183	)			(10,984	)			—
Total costs and expenses		$	1,561,929			$	1,643,031			$	317,267
Depreciation and amortization:
Pipeline Operations		$	38,434			$	38,279			$	37,411
Terminalling and Storage			7,851				6,583				5,610
Natural Gas Storage			6,458				5,003				—
Energy Services			4,547				3,683				—
Development and Logistics			1,874				1,751				1,630
Total depreciation and amortization		$	59,164			$	55,299			$	44,651
Asset impairment expense:
Pipeline Operations		$	59,724			$	—			$	—
Reorganization expense:
Pipeline Operations		$	26,127			$	—			$	—
Terminalling and Storage			2,735				—				—
Natural Gas Storage			495				—				—
Energy Services			1,207				—				—
Development and Logistics			1,493				—				—
Total reorganization expense		$	32,057			$	—			$	—
Operating income:
Pipeline Operations		$	96,683			$	153,250			$	150,295
Terminalling and Storage			61,950				53,704				42,843
Natural Gas Storage			30,748				32,692				—
Energy Services			13,521				6,039				—
Development and Logistics			5,541				7,936				8,942
Total operating income		$	208,443			$	253,621			$	202,080

     The following table presents our product volumes transported in the Pipeline Operations segment and average daily throughput for the Terminalling and Storage segment in barrels per day and total volumes sold in gallons for the Energy Services segment for the periods indicated:

		Year Ended December 31,
		2009				2008				2007
Pipeline Operations: (average barrels per day)
Gasoline			650,100				673,500				717,900
Distillate			284,700				304,200				320,100
Jet Fuel			336,700				354,700				362,700
LPGs			16,500				17,500				19,300
NGLs			13,900				20,900				20,400
Other products			8,000				11,400				7,000
Total Pipeline Operations			1,309,900				1,382,200				1,447,400
Terminalling and Storage: (average barrels per day)
Products throughput (1)			444,900				457,400				482,300
Energy Services: (in thousands of gallons)
Sales volumes (2)			655,100				435,200				—

2009 Compared to 2008

Consolidated

     Adjusted EBITDA increased by $52.7 million or 16.6% to $370.9 million during the year ended December 31, 2009 from $318.2 million in the corresponding period in 2008. The Pipeline Operations segment, the Terminalling and Storage segment and the Energy Services segment contributed to this increase in Adjusted EBITDA. The Pipeline Operations segment’s Adjusted EBITDA increased $33.4 million despite lower transportation volumes in 2009 as compared to 2008. This shortfall in volumes was offset by increased tariffs, more favorable settlement experience and lower overall operating expenses. The Terminalling and Storage segment’s Adjusted EBITDA increased $12.1 million primarily due to terminals acquired at various times in 2008 and in November of 2009 and growth in other terminalling and storage revenues, partially offset by less favorable settlement experience. The Energy Services segment’s Adjusted EBITDA increased $9.6 million as a result of increased volumes and improved margins. The Natural Gas Storage segment’s Adjusted EBITDA decreased $0.2 million in 2009 as compared to 2008 due to increased expenses associated with certain hub services transactions stemming from delays in the start-up of the Kirby Hills Phase II expansion project and general market conditions. The Development and Logistics segment’s Adjusted EBITDA decreased $2.2 million as a result of reduced operating services and construction revenues. Further contributing to the increase in consolidated Adjusted EBITDA was the continued effectiveness of cost control measures we implemented in 2009. Largely as a result of these efforts, combined with the delay of certain non-critical maintenance activities, overall spending levels decreased $5.0 million in 2009 compared to 2008. Income from equity investments increased $4.5 million in 2009 compared to 2008. The revenue and expense factors affecting the variance in consolidated Adjusted EBITDA are more fully discussed below.

     Revenue was $1,770.4 million for the year ended December 31, 2009, which is a decrease of $126.3 million or 6.7% from the year ended December 31, 2008. This overall decrease was caused primarily by a decrease in revenues from the Energy Services segment of $170.9 million due to an overall reduction in refined petroleum product prices in 2009 as compared to 2008, and a decrease in the Development and Logistics segment’s revenue of $9.4 million primarily due to decreased construction activities. This decrease was partially offset by increased revenues from the Natural Gas Storage segment of $37.4 million from increased activity from the commencement of

operations of the Kirby Hills Phase II expansion project, increased revenues from the Terminalling and Storage segment of $17.4 million primarily from terminals acquired at various times in 2008 and in November of 2009, fees and storage and rental revenue growth and increased revenues from the Pipeline Operations segment of $5.4 million primarily due to increased tariffs and more favorable settlement experience, partially offset by lower volumes.

     Total costs and expenses were $1,561.9 million for the year ended December 31, 2009, which is a decrease of $81.2 million or 4.9% from the corresponding period in 2008. Total costs and expenses reflect a decrease in refined petroleum product prices, which resulted in a $178.4 million decrease in the Energy Services segment’s cost of product sales in 2009 as compared to 2008, partially offset by increased volumes in 2009. In addition, total costs and expenses reflect the effectiveness of overall cost management efforts we implemented in 2009. These decreases in total costs and expenses were partially offset by a $59.7 million asset impairment expense, a $32.1 million reorganization expense (see Notes 8 and 3, respectively, in the Notes to Consolidated Financial Statements) and a $3.9 million increase in depreciation and amortization, which are not components of Adjusted EBITDA as presented in the reconciliation above. Other factors impacting total costs and expenses include increased operating costs for terminals acquired at various times in 2008 and in November of 2009 in the Terminalling and Storage segment and increased expenses associated with certain hub services transactions stemming from delays in the Kirby Hills Phase II expansion project in the Natural Gas Storage segment and general market conditions.

     As described in Note 1 in the Notes to Consolidated Financial Statements, effective January 1, 2009, we and our Operating Subsidiaries began paying for all executive compensation and benefits earned by Buckeye GP’s four highest salaried officers in return for an annual fixed payment from BGH of $3.6 million. The $3.6 million annual fixed payment consists of the anticipated 2009 salaries, incentive compensation and benefits of these officers plus 15%. Salaries and benefits for 2009 include salaries, incentive compensation and benefits of these officers offset by the $3.6 million annual fixed payment.

     Consolidated income from continuing operations attributable to our Unitholders was $141.0 million for the year ended December 31, 2009 compared to $183.2 million for the year ended December 31, 2008. The current period results also include an increase of $0.5 million in interest and debt expense from $74.4 million in 2008 largely attributable to the issuance of the 5.500% Notes. In addition, depreciation and amortization increased by $3.9 million, primarily due to acquisitions made during 2008, the assets utilized with respect to the Kirby Hills Phase II expansion project which were placed in service in the second half of 2009 and software which was placed in service in the fourth quarter of 2009.

Pipeline Operations

     Adjusted EBITDA from the Pipeline Operations segment of $230.2 million increased during the year ended December 31, 2009 by $33.4 million or 16.9% from $196.8 million during the year ended December 31, 2008. The increase in Adjusted EBITDA was driven primarily by the benefit of increased tariffs and more favorable settlement experience of $37.3 million, partially offset by a $19.0 million decrease due to the impact of lower volumes and a $0.6 million decrease in miscellaneous revenue. Increased income from equity investments of $4.5 million, a favorable property tax settlement of $7.2 million and a decrease in maintenance and other expenses totaling $4.5 million also contributed to the Pipeline Operations segment’s improvement in Adjusted EBITDA. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $392.7 million for the year ended December 31, 2009, which is an increase of $5.4 million or 1.4% from the corresponding period in 2008. Net transportation revenues were up $20.4 million, primarily due to increased tariffs and settlement experience of $37.3 million, partially offset by a $19.0 million decrease due to a 5.2% decrease in transportation volumes. Tariff increases of 3.7% and 3.8% were implemented on January 1, 2009 and July 1, 2009, respectively. Revenues from a product supply arrangement, rentals and other incidental services decreased $15.1 million from the prior year period. The decrease in these revenues is primarily a result of reduced product volumes sold to a wholesale distributor and a decrease in contract service activities at customer facilities connected to our refined petroleum products pipelines.

     Total costs and expenses were $296.0 million for the year ended December 31, 2009, which is an increase of $62.0 million or 26.5% from the corresponding period in 2008. Total costs and expenses include $59.7 million of asset impairment expense and $26.2 million of reorganization expense (see Notes 8 and 3, respectively, in the Notes

to Consolidated Financial Statements), which are not components of Adjusted EBITDA as presented in the reconciliation above. Total costs and expenses also include decreases in (i) property taxes of $6.6 million primarily due to a favorable property tax settlement with the City of New York of $7.2 million (see Note 5 in the Notes to Consolidated Financial Statements); (ii) product costs of $12.0 million as a result of reduced product volumes sold to a wholesale distributor; (iii) contract service activities of $2.9 million at customer facilities connected to our refined petroleum products pipelines; (iv) operating power of $2.8 million due to a decrease in volumes; and (v) professional fees of $1.7 million. These decreases were partially offset by an increase of $2.7 million in integrity program expenditures.

     Operating income was $96.7 million for the year ended December 31, 2009 compared to operating income of $153.3 million for the year ended December 31, 2008. $59.7 million and $26.2 million of the decrease is due to the asset impairment expense and reorganization expense, respectively, discussed above. Depreciation and amortization of $38.4 million for the year ended December 31, 2009 was consistent with 2008. Other revenue and expense items impacting operating income are discussed above.

Terminalling and Storage

     Adjusted EBITDA from the Terminalling and Storage segment of $72.5 million increased during the year ended December 31, 2009 by $12.1 million or 20.0% from $60.4 million during the year ended December 31, 2008. The increase in Adjusted EBITDA reflects the contribution from terminals acquired in 2009 and 2008 of $9.6 million, including the terminals acquired from ConocoPhillips in November 2009 (see Note 4 in the Notes to Consolidated Financial Statements) and increased fees and storage and rental revenue growth of $14.1 million, offset by a $10.2 million reduction due to lower settlement experience and lower terminal volumes and higher expenses of $1.4 million. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $136.6 million for the year ended December 31, 2009, which is an increase of $17.4 million or 14.6% from the corresponding period in 2008. This increase resulted primarily from $13.5 million of revenue in 2009 from terminals that were acquired at various times in 2008 and in November of 2009 (see Note 4 in the Notes to Consolidated Financial Statements for terminal acquisitions) and increased fees and storage and rental revenue of $14.1 million. These increases were partially offset by a $7.9 million decrease in settlement experience and a 2.7% decrease in terminal volumes resulting in a $2.3 million decrease in revenues in 2009 as compared to 2008.

     Total costs and expenses were $74.6 million for the year ended December 31, 2009, which is an increase of $9.1 million or 14.0% from the corresponding period in 2008. Total costs and expenses include $2.7 million of reorganization expense (see Note 3 in the Notes to Consolidated Financial Statements) and an increase of $1.3 million in depreciation and amortization, which are not components of Adjusted EBITDA as presented in the reconciliation above. Total costs and expenses also include an increase of $4.5 million of operating expenses for terminals acquired at various times in 2008 and in November of 2009 and an increase in remediation expenses and integrity program expenditures totaling $2.3 million.

     Operating income was $62.0 million for the year ended December 31, 2009 compared to operating income of $53.7 million for the year ended December 31, 2008. Depreciation and amortization increased $1.3 million for the year ended December 31, 2009 as a result of terminals acquired at various times in 2008. Other revenue and expense items impacting operating income are discussed above.

Natural Gas Storage

     Adjusted EBITDA from the Natural Gas Storage segment of $42.2 million decreased during the year ended December 31, 2009 by $0.2 million or 0.4% from $42.4 million during the year ended December 31, 2008. The decrease in Adjusted EBITDA was primarily a result of increased expenses from certain hub services transactions stemming from delays in the Kirby Hills Phase II expansion project and general market conditions. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $99.2 million for the year ended December 31, 2009, which is an increase of $37.4 million or 60.5% from the corresponding period in 2008. This overall increase resulted primarily from increased hub services revenues in 2009 driven by increased activity from the operations of the Kirby Hills Phase II expansion project,

which was placed in service in June 2009, and the inclusion of a full year of revenue in 2009 compared to approximately eleven and one half months in the corresponding period in 2008, reflecting our purchase of Lodi Gas on January 18, 2008. Lease revenue increased $5.9 million and hub services and other revenue increased $31.5 million from the year ended December 31, 2008.

     Total costs and expenses were $68.4 million for the year ended December 31, 2009, which is an increase of $39.3 million or 135.1% from the corresponding period in 2008. Total costs and expenses include $0.5 million of reorganization expense (see Note 3 in the Notes to Consolidated Financial Statements) and an increase of $1.5 million in depreciation and amortization, which are not components of Adjusted EBITDA as presented in the reconciliation above. Total costs and expenses include expenses from certain hub services transactions stemming from delays in the Kirby Hills Phase II expansion project and from general market conditions, increased costs from the operations of the Kirby Hills Phase II expansion project for the second half of 2009 when it was placed into service and expenses related to the timing of the acquisition of Lodi Gas, which was included in our results for a full year of activity in 2009 versus eleven and one half months in 2008.

     Operating income was $30.7 million for the year ended December 31, 2009 compared to operating income of $32.7 million for the year ended December 31, 2008. Depreciation and amortization increased $1.5 million for 2009 from the corresponding period in 2008 due to depreciation expense on the assets utilized with respect to the Kirby Hills Phase II expansion project, which was placed in service in the second half of 2009. Other revenue and expense items impacting operating income are discussed above.

Energy Services

     Adjusted EBITDA from the Energy Services segment of $19.4 million increased during the year ended December 31, 2009 by $9.6 million or 97.8% from $9.8 million during the year ended December 31, 2008. This increase in Adjusted EBITDA was a result of a 50.5% increase in sales volume and improved margins. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $1,125.0 million for the year ended December 31, 2009, which is a decrease of $170.9 million or 13.2% from the corresponding period in 2008. This overall decrease was primarily due to a decline in refined petroleum product prices, which correspondingly lowers the cost of products sales, partially offset by a 50.5% increase in volumes due to increased sales activity and the inclusion of a full year in 2009 compared to approximately ten and one half months in the corresponding period in 2008 following the acquisition of Farm & Home.

     Total costs and expenses were $1,111.5 million for the year ended December 31, 2009, which is a decrease of $178.4 million or 13.8% from the corresponding period in 2008. Total costs and expenses include $1.2 million of reorganization expense (see Note 3 in the Notes to Consolidated Financial Statements) and an increase of $0.8 million in depreciation and amortization, which are not components of Adjusted EBITDA as presented in the reconciliation above. Total costs and expenses include a decrease of $182.7 million in cost of product sales primarily related to a decrease in commodity prices in 2009 as compared to the same period in 2008. This decrease in total costs and expenses was partially offset by the inclusion of a full year of operations in 2009 compared to approximately ten and one half months in the corresponding period in 2008 following the acquisition of Farm & Home.

     Operating income was $13.5 million for the year ended December 31, 2009 compared to operating income of $6.0 million for the year ended December 31, 2008. Depreciation and amortization increased $0.8 million for 2009 from the corresponding period in 2008 due to amortization of software that was placed in service in the fourth quarter of 2009. Other revenue and expense items impacting operating income are discussed above.

Development and Logistics

     Adjusted EBITDA from the Development and Logistics segment of $6.6 million decreased during the year ended December 31, 2009 by $2.2 million or 24.8% from $8.8 million during the year ended December 31, 2008. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue, which consists principally of our contract operations and engineering services for third-party pipelines, was $34.1 million for the year ended December 31, 2009, which is a decrease of $9.4 million or 21.5% from the corresponding period in 2008. The decrease in revenues resulted from reduced operating services and a reduction in construction contract revenues, reflecting a customer’s termination of a contract in the second quarter of 2008. These construction activities are principally conducted on a time and material basis.

     Total costs and expenses were $28.6 million for the year ended December 31, 2009, which is a decrease of $7.0 million or 19.6% from the corresponding period in 2008. Total costs and expenses include $1.5 million of reorganization expense (see Note 3 in the Notes to Consolidated Financial Statements), which is not a component of Adjusted EBITDA as presented in the reconciliation above. The decrease in total costs and expenses compared to 2008 are a result of reduced operating expenses associated with a terminated customer contract, reduced construction contract activity and reduced operating services activities.

     Operating income was $5.5 million for the year ended December 31, 2009 compared to operating income of $7.9 million for the year ended December 31, 2008. Depreciation and amortization of $1.9 million for the year ended December 31, 2009 was relatively consistent with the same period in 2008, and income taxes decreased $1.1 million for the year ended December 31, 2009 due to lower earnings in the 2009 period. Other revenue and expense items impacting operating income are discussed above.

2008 Compared to 2007

Consolidated

     Adjusted EBITDA increased by $67.1 million or 26.7% to $318.2 million for the year ended December 31, 2008 from $251.1 million for the year ended December 31, 2007. All of our business segments, except for the Development and Logistics segment, contributed to this increase in Adjusted EBITDA. Adjusted EBTIDA for the Natural Gas Storage and Energy Services segments, which include the Lodi Gas and Farm & Home acquisitions on January 18, 2008 and February 8, 2008, respectively, was $42.4 million and $9.8 million for the year ended December 31, 2008, respectively. The Terminalling and Storage segment’s Adjusted EBITDA increased $11.0 million for the year ended December 31, 2008 primarily due to terminals acquired at various times in 2008 and 2007 and growth in other terminalling and storage revenues. The Pipeline Operations segment’s Adjusted EBITDA increased $4.6 million despite lower transportation volumes for the year ended December 31, 2008 as compared to the year ended December 31, 2007. The shortfall in volumes was offset by increased tariffs and incidental revenues, partially offset by increases in operating expenses. The Development and Logistics segment’s Adjusted EBITDA decreased $0.7 million primarily due to increased operating expenses. Income from equity investments increased $0.4 million primarily due to increased equity income earned from our interest in WT LPG. The revenue and expense factors affecting the variance in consolidated Adjusted EBITDA are more fully discussed below.

     Revenue was $1,896.7 million for the year ended December 31, 2008, which is an increase of $1,377.3 million or 265.2% from the year ended December 31, 2007. This overall increase was caused primarily by revenues from our Energy Services and Natural Gas Storage segments of $1,295.9 million and $61.8 million due to the acquisitions of Farm & Home and Lodi Gas, respectively, in 2008. The Terminalling and Storage segment revenues increased $15.4 million from the acquisition of terminals in 2008 and 2007, and the Pipeline Operations segment revenues increased $7.9 million due to increased tariffs. The Development and Logistics segment reported higher revenue of $7.3 million due to increased construction activities.

     Total costs and expenses were $1,643.1 million for the year ended December 31, 2008, which is an increase of $1,325.8 million or 417.9% from the year ended December 31, 2007. Total costs and expenses include expenses of $1,289.9 million and $29.1 million due to the acquisitions for Farm & Home and Lodi Gas, respectively, in 2008 in the Energy Services segment and the Natural Gas Storage segment, respectively. Total costs and expenses also includes increased payroll and benefits expenses resulting primarily from an increase in the number of employees

due to our expanded operations, increased casualty losses due to an increase in the cost of remediating environmental incidents and increased construction management costs resulting from an increase in construction contracts that were substantially completed at December 31, 2008, partially offset by a decrease in pipeline and terminal maintenance activities, decreased operating power costs due to lower volumes transported in the Pipeline Operations segment, and decreased supplies expenses due to decreased throughput at our terminals in the Terminalling and Storage segment.

     Consolidated net income from continuing operations attributable to our Unitholders was $183.2 million for the year ended December 31, 2008 compared to $155.4 million for the year ended December 31, 2007. The 2008 period results also include an increase of $24.0 million in interest and debt expense from $50.4 million in 2007. Approximately $17.7 million of the increase was attributable to expenses associated with the 6.05% Notes, which were issued in January 2008. The remainder of the increase is due to interest expense related to working capital requirements of the Energy Services segment and amounts outstanding under our Credit Facility. In addition, depreciation and amortization increased by $10.6 million due to acquisitions made during 2008.

Pipeline Operations

     Adjusted EBITDA from the Pipeline Operations segment of $196.8 million increased during the year ended December 31, 2008 by $4.6 million or 2.4% from $192.2 million during the year ended December 31, 2007. The increase in Adjusted EBITDA was driven primarily by increased net transportation revenues and incidental revenues and lower pipeline terminal and maintenance expense and power costs, offset by reduced transportation volumes, increased fuel purchases related to a product supply arrangement and increased casualty losses. Income from equity investments increased $0.4 million. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $387.3 million for the year ended December 31, 2008, which is an increase of $7.9 million or 2.1% from the corresponding period in 2007. Net transportation revenues increased $1.2 million in 2008 compared to 2007 primarily as a result of tariff increases implemented on May 1, 2008 and July 1, 2008. The benefit of the tariff increases were substantially offset by reduced product volumes of 4.5% in 2008 as compared to 2007. We believe that the reduced volumes in 2008 were caused primarily by reduced demand for gasoline resulting from higher retail gasoline prices, reduced production at ConocoPhillip’s Wood River Refinery due to maintenance activities, and the continued introduction of ethanol into retail gasoline products as well as reduced demand for distillates resulting from higher retail distillate prices and the slowdown in the U.S. economy. Incidental revenues increased $4.7 million principally related to a product supply arrangement, and revenues from additional construction management and rental revenues increased $1.5 million from the corresponding period in 2007.

     Total costs and expenses were $234.0 million for the year ended December 31, 2008, which is an increase of $5.0 million or 2.2% from the corresponding period in 2007. Total costs and expenses include depreciation and amortization which is not a component of Adjusted EBITDA. The increase in total costs and expenses is primarily attributable to: (i) an increase of $4.6 million primarily associated with fuel purchases related to a product supply arrangement; (ii) an increase of $2.3 million in casualty losses, which is due to an increase in the cost of remediating environmental incidents compared to 2007, as well as $0.5 million related to a product contamination incident that occurred in the third quarter of 2008; and (iii) an increase of $1.2 million in payroll and payroll benefits primarily resulting from an increase in the number of employees due to our expanded operations. These increases were partially offset by a decrease of $2.8 million in pipeline maintenance activities compared to 2007 and a decrease of $1.0 million in operating power costs due to lower volumes transported.

     Operating income was $153.3 million for the year ended December 31, 2008 compared to operating income of $150.3 million for the year ended December 31, 2007. Depreciation and amortization increased $0.9 million for the year ended December 31, 2008 from the corresponding period in 2007 due to our ongoing expansion capital program. Other revenue and expense items impacting operating income are discussed above.

Terminalling and Storage

     Adjusted EBITDA from the Terminalling and Storage segment of $60.4 million increased during the year ended December 31, 2008 by $11.0 million or 22.4% from $49.4 million during the year ended December 31, 2007. The increase in Adjusted EBITDA reflects the contribution of revenues from terminals acquired during 2007 and 2008 of $6.5 million, partially offset by an increase of $2.1 million in operating expenses from those acquired terminals, an increase of $6.1 million in blending fees and a $2.8 million customer settlement, partially offset by increased salaries, wages and incentive compensation expenses due to our expanded operations. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $119.2 million for the year ended December 31, 2008, which is an increase of $15.4 million or 14.8% from the corresponding period in 2007. This overall increase resulted primarily from (i) $6.5 million of incremental revenue in 2008 from the acquisitions of the Niles, Michigan, Ferrysburg, Michigan, Wethersfield, Connecticut, and Albany, New York terminals in 2008, combined with the effect of having a full year of revenue in 2008 from the six terminals that were acquired in the first quarter of 2007; (ii) $6.1 million of revenue related to increases in blending fees for product additives and product recoveries from vapor recovery units, which were offset by an approximately 5.4% decline in throughput volumes, caused in part by increased commodity prices, in 2008 compared to 2007; and (iii) $2.8 million from the settlement of a dispute with a customer regarding product handling charges.

     Total costs and expenses were $65.5 million for the year ended December 31, 2008, which is an increase of $4.5 million or 7.4% from the corresponding period in 2007. Total costs and expenses include depreciation and amortization which is not a component of Adjusted EBITDA. The increase in total costs and expenses is primarily due to an increase of $2.1 million in operating expenses for the terminal acquisitions made at various times in 2007 and 2008 and an increase of $1.6 million in payroll and payroll benefits in 2008 resulting primarily from an increase in the number of employees due to our expanded operations, partially offset by a decrease of $1.2 million in terminal additive expense related to decreased throughput volumes at our terminals.

     Operating income was $53.7 million for the year ended December 31, 2008 compared to operating income of $42.8 million for the year ended December 31, 2007. Depreciation and amortization of $6.6 million increased during the year ended December 31, 2008 by $1.0 million from $5.6 million for the year ended December 31, 2007 as a result of terminals acquired at various times in 2008 and 2007. Other revenue and expense items impacting operating income are discussed above.

Natural Gas Storage

     Adjusted EBITDA from the Natural Gas Storage segment was $42.4 million for the year ended December 31, 2008. Revenue and expenses affecting Adjusted EBITDA are more fully discussed below.

     Revenue was $61.8 million for the year ended December 31, 2008. Approximately 70.2% of this revenue represented lease storage revenues and 29.8% represented hub services revenues. All of this revenue was derived from Lodi Gas’ operations, which we acquired on January 18, 2008.

     Total costs and expenses were $29.1 million for the year ended December 31, 2008. Costs and expenses were from Lodi Gas’ legacy operations, which we acquired on January 18, 2008, and included $5.0 million of depreciation and amortization and $4.6 million of non-cash deferred lease expense, which are not components of Adjusted EBITDA. The Natural Gas Storage segment incurred $4.1 million of payroll and payroll benefits expense, $4.2 million of outside services costs, of which $3.2 million related to well work-over costs, $2.4 million of property and other taxes, $2.7 million of rental expense, $0.9 million of insurance costs and $3.6 million of other costs in 2008.

     Operating income was $32.7 million for the year ended December 31, 2008. Depreciation and amortization was $5.0 million for the year ended December 31, 2008. Other revenue and expense items impacting operating income are discussed above.

Energy Services

     Adjusted EBITDA from the Energy Services segment was $9.8 million for the year ended December 31, 2008. Revenue and expenses affecting Adjusted EBITDA are more fully discussed below.

     Revenue was $1,295.9 million for the year ended December 31, 2008. Substantially all of this revenue was derived from Farm & Home’s legacy wholesale operations, which we acquired on February 8, 2008. During 2008, approximately 435.2 million gallons of products were sold. Products sold include gasoline, propane and petroleum distillates such as heating oil, diesel fuel and kerosene.

     Total costs and expenses were $1,289.9 million for the year ended December 31, 2008 and included $3.7 million of depreciation and amortization, which is not a component of Adjusted EBITDA. Substantially all of these costs and expenses were derived from Farm & Home’s legacy wholesale operations. Approximately $1,269.6 million was attributable to products sold by the Energy Services segment. Additionally, the Energy Services segment incurred $7.3 million of payroll and payroll benefits expense, $1.1 million of outside service costs, $0.7 million of property and other taxes, $0.6 million of rental expense, $0.4 million of insurance costs and $6.8 million of other costs in 2008.

     Operating income was $6.0 million for the year ended December 31, 2008. Depreciation and amortization was $3.7 million for the year ended December 31, 2008. Other revenue and expense items impacting operating income are discussed above.

Development and Logistics

     Adjusted EBITDA from the Development and Logistics segment of $8.8 million decreased during the year ended December 31, 2008 by $0.8 million or 8.0% from $9.5 million during the year ended December 31, 2007. The revenue and expense factors affecting the variance in Adjusted EBITDA are more fully discussed below.

     Revenue was $43.5 million for the year ended December 31, 2008, which is an increase of $7.3 million or 20.1% from the corresponding period in 2007. The increase in revenues in 2008 was primarily the result of an increase of $7.0 million in construction management revenue related to construction contracts that were substantially completed at December 31, 2008. These construction activities are principally conducted on a time and material basis.

     Total costs and expenses were $35.6 million for the year ended December 31, 2008, which is an increase of $8.3 million or 30.4% from the corresponding period in 2007. Total costs and expenses include depreciation and amortization which is not a component of Adjusted EBITDA. The increase in total costs and expenses is associated with increased construction contract activity. Construction management costs were $12.6 million in 2008, which is an increase of $5.3 million over 2007. The increase in 2008 was primarily the result of an increase in construction contracts that were substantially completed at December 31, 2008. Additionally, outside services costs increased $2.4 million and payroll and payroll benefits expense increased approximately $0.7 million due to the increased construction activities.

     Operating income was $7.9 million for the year ended December 31, 2008 compared to operating income of $8.9 million for the year ended December 31, 2007. Depreciation and amortization was $1.8 million for the year ended December 31, 2008, which is an increase of $0.2 million from the corresponding period in 2007. Income tax expense of $0.8 million was consistent with the same period in 2007. Other revenue and expense items impacting operating income are discussed above.

Liquidity and Capital Resources

General

     Our primary cash requirements, in addition to normal operating expenses and debt service, are for working capital, capital expenditures, business acquisitions and distributions to partners. Our principal sources of liquidity are cash from operations, borrowings under our Credit Facility and proceeds from the issuance of our LP Units. We will, from time to time, issue debt securities to permanently finance amounts borrowed under the Credit Facility. BES funds its working capital needs principally from operations and the BES Credit Agreement. Our financial policy has been to fund sustaining capital expenditures with cash from operations. Expansion and cost improvement capital expenditures, along with acquisitions, have typically been funded from external sources including the Credit Facility as well as debt and equity offerings. Our goal has been to fund at least half of these expenditures with proceeds from equity offerings in order to maintain our investment-grade credit rating.

     We continue to evaluate the conditions of the debt and equity capital markets, and in March 2009, we issued 2.6 million LP Units in an underwritten public offering at $35.08 per LP Unit. On April 29, 2009, the underwriters of the equity offering exercised their option to purchase an additional 390,000 LP Units at $35.08 per LP Unit. Total proceeds from the offering, including the overallotment option and after the underwriter’s discount of $1.17 per LP Unit and offering expenses, were approximately $104.6 million, and were used to reduce amounts outstanding under our Credit Facility. In August 2009, we sold 5.500% Notes in an underwritten public offering. The 5.500% Notes were issued at 99.35% of their principal amount. Total proceeds from the offering, after underwriters’ fees, expenses and debt issuance costs of $1.8 million, were approximately $271.4 million, and were used to reduce amounts outstanding under the Credit Facility and for general partnership purposes.

     As a result of our actions to minimize external financing requirements and the fact that no debt facilities mature prior to 2011, we believe that availabilities under our credit facilities, coupled with ongoing cash flows from operations, will be sufficient to fund our operations for 2010. We will continue to evaluate a variety of financing sources, including the debt and equity markets described above, throughout 2010. However, continuing volatility in the debt and equity markets will make the timing and cost of any such potential financing uncertain.

     At December 31, 2009, we had $34.6 million of cash and cash equivalents on hand and approximately $401.9 million of available credit under the Credit Facility, after application of the facility’s funded debt ratio covenant. In addition, BES had $10.2 million of available credit under the BES Credit Agreement, pursuant to certain borrowing base calculations under that agreement. See Note 13 in the Notes to Consolidated Financial Statements for further information about our credit facilities.

     At December 31, 2009, we had an aggregate face amount of $1,742.8 million of debt, which consisted of the following:

	•		$300.0 million of the 4.625% Notes due 2013 (the “4.625% Notes”);
	•		$275.0 million of the 5.300% Notes due 2014 (the “5.300% Notes”);
	•		$125.0 million of the 5.125% Notes due 2017 (the “5.125% Notes”);
	•		$300.0 million of the 6.050% Notes due 2018 (the “6.050% Notes”);
	•		$275.0 million of the 5.500% Notes due 2019;
	•		$150.0 million of the 6.750% Notes due 2033 (the “6.750% Notes”);
	•		$78.0 million outstanding under our Credit Facility; and
	•		$239.8 million outstanding under the BES Credit Agreement.

     See Note 13 in the Notes to Consolidated Financial Statements for more information about the terms of the debt discussed above.

     The fair values of our aggregate debt and credit facilities were estimated to be $1,762.1 million and $1,367.7 million at December 31, 2009 and 2008, respectively. The fair values of the fixed-rate debt at December 31, 2009 and 2008 were estimated by market-observed trading prices and by comparing the historic market prices of our publicly-issued debt with the market prices of other MLPs’ publicly-issued debt with similar credit ratings and

terms. The fair values of our variable-rate debt are their carrying amounts as the carrying amount reasonably approximates fair value due to the variability of the interest rate.

Registration Statement

     We may issue equity or debt securities to assist us in meeting our liquidity and capital spending requirements. We have a universal shelf registration statement on file with the SEC that would allow us to issue an unlimited amount of debt and equity securities for general partnership purposes.

Cash Flows from Operating, Investing and Financing Activities

     The following table summarizes our cash flows from operating, investing and financing activities for the periods indicated (in thousands):

		Year Ended December 31,
		2009				2008				2007
Cash provided by (used in):
Continuing operating activities		$	56,183			$	214,962			$	197,487
Operating activities			56,183				215,254				197,487
Investing activities			(144,203	)			(735,776	)			(108,605	)
Financing activities			63,776				486,167				(14,630	)

     Operating Activities

     2009 Compared to 2008. Net cash flow provided by operating activities was $56.2 million for the year ended December 31, 2009 compared to $215.3 million for the year ended December 31, 2008. The following were the principal factors resulting in the $159.1 million decrease in net cash flows provided by operating activities:

	•		We recognized $32.1 million of reorganization expenses in the 2009 period.
	•		The net change in fair values of derivatives was an increase of $20.5 million, resulting from the decrease in value related to fixed-price sales contracts compared to a lower level of opposite fluctuations in futures contracts purchased to hedge such fluctuations.
	•		The net impact of working capital changes was a decrease of $227.9 million to cash flows from operating activities for the year ended December 31, 2009. The principal factors affecting the working capital changes were:

	•		Inventories increased $177.3 million due to an increase in inventory purchases within the Energy Services segment which are hedged with futures contracts that expire primarily in the winter months. As a result of energy market conditions, we significantly increased our physical inventory purchases in 2009.
	•		Trade receivables increased $44.1 million primarily due to increased activity from our Energy Services segment due to higher volumes in the 2009 period.
	•		Prepaid and other current assets increased $31.6 million primarily due to increases in prepaid services and unbilled revenue within the Natural Gas Storage segment and an increase in receivables due to a favorable property tax settlement, partially offset by a decrease in a receivable related to ammonia purchases and a decrease in margin deposits on futures contracts in our Energy Services segment.
	•		Accrued and other current liabilities increased $2.6 million primarily due to costs related to the reorganization.

	•		Accounts payable increased $15.2 million due to activity within the Energy Services segment.
	•		Construction and pipeline relocation receivables decreased $7.4 million primarily due to a decrease in construction activity in the 2009 period.

     2008 Compared to 2007. Net cash flow provided by operating activities was $215.3 million for the year ended December 31, 2008 compared to $197.5 million for the year ended December 31, 2007. The following were the principal factors resulting in the $17.8 million increase in net cash flows provided by operating activities:

	•		Our income from continuing operations increased $28.0 million for the year ended December 31, 2008 compared with the year ended December 31 2007, primarily due to our acquisitions of Lodi Gas and Farm & Home in 2008.
	•		The net change in fair values of derivatives was a decrease of $24.2 million, resulting from the increase in value related to fixed-price sales contracts compared to a lower level of opposite fluctuations in futures contracts purchased to hedge such fluctuations. We did not utilize futures contracts to economically hedge a portion of the fixed-price sales contracts because we had purchased inventory to fulfill a portion of those commitments.
	•		The net impact of working capital changes was a decrease of $8.9 million to cash flows from operations for the year ended December 31, 2008. The principal factors affecting the working capital changes were:

	•		Prepaid and other current assets increased $25.7 million, primarily due to an increase in a receivable related to ammonia purchases as well as additional margin deposits associated with liabilities for derivative instruments.
	•		Construction and pipeline relocation receivables increased $8.9 million due to an increase in construction activity in the latter part of 2008.
	•		Inventories increased $4.4 million due to inventory purchases within the Energy Services segment.
	•		Accounts payable decreased $10.9 million due to activity within the Energy Services segment since the acquisition of Farm & Home.
	•		Trade receivables decreased $36.1 million due to an increase in collections within the Energy Services segment since the acquisition of Farm & Home.
	•		Accrued and other current liabilities increased $4.9 million primarily due to increases in accrued taxes, environmental liabilities and interest expense.

     Investing Activities

     2009 Compared to 2008. Net cash flow used in investing activities was $144.2 million for the year ended December 31, 2009 compared to $735.8 million for the year ended December 31, 2008. The following were the principal factors resulting in the $591.6 million decrease in net cash flows used in investing activities:

	•		Cash used for acquisitions and equity investments, net of cash acquired, was $58.3 million for the year ended December 31, 2009, of which $54.4 million was used for the acquisition of refined petroleum product terminals and pipeline assets from ConocoPhillips. We also invested an additional $3.9 million in WT LPG in 2009. Cash used for acquisitions and equity investments, net of cash acquired, was $667.5 million for the year ended December 31, 2008, of which $438.8 million was used for the acquisition of Lodi Gas, $143.3 million was used for the acquisition of Farm & Home and an aggregate of $75.6 million was used for the acquisitions of four terminals in Albany, New York, Niles and Ferrysburg, Michigan, and Wethersfield, Connecticut and the acquisition of the remaining 50% member interest in Wespac — San Diego that we did not already own. We also invested an additional $9.8 million in WT LPG in 2008. See Note 4 in the Notes to Consolidated Financial Statements for further information.
	•		Capital expenditures decreased $33.2 million for the year ended December 31, 2009 compared with the year ended December 31, 2008. See below for a discussion of capital spending.
	•		Cash proceeds from the sale of discontinued operations were $52.6 million for the year ended December 31, 2008, which related to the sale of the retail operations of Farm & Home.

     2008 Compared to 2007. Net cash flow used in investing activities was $735.8 million for the year ended December 31, 2008 compared to $108.6 million for the year ended December 31, 2007. The following were the principal factors resulting in the $627.2 million increase in net cash flows used in investing activities:

	•		Cash used for acquisitions and equity investments, net of cash acquired was $667.5 million for the year ended December 31, 2008 as discussed above. Cash used for acquisitions and equity investments, net of cash acquired was $40.7 million for the year ended December 31, 2007, of which $39.8 million was used for the acquisition of terminals and related assets and $0.9 million was used for an additional investment in WT LPG. See Note 4 in the Notes to Consolidated Financial Statements for further information.
	•		Capital expenditures increased $52.6 million for the year ended December 31, 2008 compared with the year ended December 31, 2007. See below for a discussion of capital spending.
	•		Cash proceeds from the sale of discontinued operations were $52.6 million for the year ended December 31, 2008, which related to the sale of the retail operations of Farm & Home.

     Capital expenditures are summarized below (net of non-cash changes in accruals for capital expenditures for the years ended December 31, 2009, 2008 and 2007) for the periods indicated (in thousands):

		Year Ended December 31,
		2009				2008				2007
Sustaining capital expenditures		$	23,496			$	28,936			$	33,838
Expansion and cost reduction			63,813				91,536				34,029
Total capital expenditures		$	87,309			$	120,472			$	67,867

     In 2009 and 2008, expansion and cost reduction projects included the Kirby Hills Phase II expansion project, ethanol and butane blending projects at certain of our terminals, the construction of three additional tanks with capacity of 0.4 million barrels in Linden, New Jersey and various other pipeline and terminal operating infrastructure projects. Construction costs of the Kirby Hills Phase II expansion project in 2009 and 2008 totaled approximately $17.0 million and $49.6 million, respectively. In 2007, expansion and cost reduction projects included a capacity expansion project in Illinois to handle additional liquefied petroleum gas volumes and ongoing capacity improvements at facilities to serve the Memphis International Airport.

     We expect to spend approximately $90.0 million to $110.0 million for capital expenditures in 2010, of which approximately $25.0 million to $35.0 million is expected to relate to sustaining capital expenditures and $65.0 million to $75.0 million is expected to relate to expansion and cost reduction projects. Sustaining capital expenditures include renewals and replacement of pipeline sections, tank floors and tank roofs and upgrades to station and terminalling equipment, field instrumentation and cathodic protection systems. Major expansion and cost reduction expenditures in 2010 will include the completion of additional product storage tanks in the Midwest, the construction of a 4.4 mile pipeline in central Connecticut to connect our pipeline in Connecticut to a third party electric generation plant currently under construction, various terminal expansions and upgrades and pipeline and terminal automation projects.

     Financing Activities

     2009 Compared to 2008. Net cash flow provided by financing activities was $63.8 million for the year ended December 31, 2009 compared to $486.2 million for the year ended December 31, 2008. The following were the principal factors resulting in the $422.4 million decrease in net cash flows provided by financing activities:

	•		We borrowed $317.1 million and $558.6 million and repaid $537.4 million and $260.3 million under the Credit Facility in 2009 and 2008, respectively.
	•		Net borrowings under the BES Credit Agreement were $143.8 million in 2009, while net repayments under the BES Credit Agreement (and its predecessor facility which was replaced in May 2008) were $4.0 million in 2008.

	•		We received $271.4 million (net of debt issuance costs of $1.8 million) from the issuance in August 2009 of $275.0 million in aggregate principal amount of the 5.500% Notes in an underwritten public offering. Proceeds from this offering were used to reduce amounts outstanding under the Credit Facility. We received $298.0 million from the issuance in January 2008 of $300.0 million in aggregate principal amount of the 6.050% Notes in an underwritten public offering. Proceeds from this offering were used to partially pre-fund the Lodi Gas acquisition. In connection with this debt offering, we settled two interest rate swaps associated with the 6.050% Notes, which resulted in a settlement payment of $9.6 million that is being amortized as interest expense over the ten-year term of the 6.050% Notes.
	•		We received $104.6 million in net proceeds from an underwritten equity offering in March 2009 from the public issuance of 3.0 million LP Units. In 2008, we received $113.1 million in net proceeds from the public issuance of 2.6 million LP Units.
	•		Cash distributions paid to our partners increased $27.0 million year-to-year due to an increase in the number of LP Units outstanding and an increase in our quarterly cash distribution rate per LP Unit. We paid cash distributions of $230.4 million ($3.63 per LP Unit) and $203.2 million ($3.43 per LP Unit) during the years ended December 31, 2009 and 2008, respectively.

     2008 Compared to 2007. Net cash flow provided by financing activities was $486.2 million for the year ended December 31, 2008 compared to net cash used in financing activities of $14.6 million for the year ended December 31, 2007. The following were the principal factors resulting in the $500.8 million increase in net cash flows provided by financing activities:

	•		We borrowed $558.6 million and $155.0 million and repaid $260.3 million and $300.0 million under the Credit Facility (and its predecessor facility) in 2008 and 2007, respectively.
	•		Net repayments under the BES Credit Agreement (and its predecessor facility which was replaced in May 2008) were $4.0 million in 2008.
	•		We received $298.1 million from the issuance in January 2008 of $300.0 million in aggregate principal amount of the 6.050% Notes in an underwritten public offering as discussed above.
	•		We received $113.1 million in net proceeds from an underwritten equity offering in March 2008 from the public issuance of 2.6 million LP Units. In 2007, we received $296.4 million in net proceeds from underwritten equity offerings in March, August and December 2007 from the public issuance of 6.2 million LP Units.
	•		Cash distributions paid to our partners increased $38.8 million year-to-year due to an increase in the number of LP Units outstanding and an increase in our quarterly cash distribution rate per LP Unit. We paid cash distributions of $203.2 million ($3.43 per LP Unit) and $164.3 million ($3.23 per LP Unit) during the years ended December 31, 2008 and 2007, respectively.

Derivatives

     See “Item 7A. Quantitative and Qualitative Disclosures About Market Risk — Market Risk — Non Trading Instruments” for a discussion of commodity derivatives used by our Energy Services segment.

Critical Accounting Policies

     The preparation of consolidated financial statements in conformity with GAAP requires management to select appropriate accounting principles from those available, to apply those principles consistently and to make reasonable estimates and assumptions that affect revenues and associated costs as well as reported amounts of assets and liabilities. The following describes the estimated risks underlying our critical accounting policies and estimates:

Depreciation Methods, Estimated Useful Lives and Disposals of Property, Plant and Equipment

     In general, depreciation is the systematic and rational allocation of an asset’s cost or fair value, less its residual value (if any), to the periods it benefits. Property, plant and equipment consist primarily of pipelines, wells, storage and terminal facilities, pad gas and pumping and compression equipment. Depreciation on pipelines and terminals is generally calculated using the straight-line method over the estimated useful lives ranging from 44 to 50 years. Plant and equipment associated with our natural gas storage business is generally depreciated over 44 years, except

for pad gas. The Natural Gas Storage segment maintains a level of natural gas in its underground storage facility generally known as pad gas, which is not routinely cycled but, instead, serves the function of maintaining the necessary pressure to allow routine injection and withdrawal to meet demand. Pad gas is considered to be a component of the facility and as such is not depreciated because it is expected to ultimately be recovered and sold. Other plant and equipment is generally depreciated on a straight-line basis over an estimated life of 5 to 50 years. Straight line depreciation results in depreciation expense being incurred evenly over the life of an asset.

     Additions to property, plant and equipment, including major replacements or betterments, are recorded at cost. We charge maintenance and repairs to expense in the period incurred. The cost of property, plant and equipment sold or retired and the related depreciation, except for certain pipeline system assets, are removed from our consolidated balance sheet in the period of sale or disposition, and any resulting gain or loss is included in income. For our pipeline system assets, we generally charge the original cost of property sold or retired to accumulated depreciation and amortization, net of salvage and cost of removal. When a separately identifiable group of assets, such as a stand-alone pipeline system, is sold, we will recognize a gain or loss in our consolidated statements of operations for the difference between the cash received and the net book value of the assets sold.

     The determination of an asset’s useful life requires assumptions regarding a number of factors including technological change, normal depreciation and actual physical usage. If any of these assumptions subsequently change, the estimated useful life of the asset could change and result in an increase or decrease in depreciation expense that could have a material impact on our consolidated financial statements.

     At both December 31, 2009 and 2008, the net book value of our property, plant and equipment was $2.2 billion. Property, plant and equipment is generally recorded at its original acquisition cost and its carrying value accounted for approximately 68.4% of our consolidated assets at December 31, 2009. Depreciation expense was $50.7 million, $47.2 million and $39.4 million for the years ended December 31, 2009, 2008 and 2007, respectively. We do not believe that there is a reasonable likelihood that there will be a material change in the future estimated useful life of our property, plant and equipment. In the past, we have generally not deemed it necessary to materially change the depreciable lives of our assets. An increase or decrease in the depreciable lives of these assets, for example a 5-year increase or decrease in the depreciable lives of our pipeline assets, currently estimated as 50 years, would decrease or increase, respectively, annual depreciation expense, and increase or decrease operating income, respectively, by approximately $5.0 million annually.

Reserves for Environmental Matters

     We are subject to federal, state and local laws and regulations relating to the protection of the environment. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to existing conditions caused by past operations, and which do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated based upon past experience and advice of outside engineering, consulting and law firms. Generally, the timing of these accruals coincides with our commitment to a formal plan of action. Accrued environmental remediation related expenses include estimates of direct costs of remediation and indirect costs related to the remediation effort, such as compensation and benefits for employees directly involved in the remediation activities and fees paid to outside engineering, consulting and law firms. Historically, our estimates of direct and indirect costs related to remediation efforts have generally not required material adjustments. However, the accounting estimates related to environmental matters are uncertain because (1) estimated future expenditures related to environmental matters are subject to cost fluctuations and can change materially, (2) unanticipated liabilities may arise in connection with environmental remediation projects and may impact cost estimates, and (3) changes in federal, state and local environmental laws and regulations can significantly increase the cost or potential liabilities related to environmental matters. None of our estimated environmental remediation liabilities are discounted to present value since the ultimate amount and timing of cash payments for such liabilities are not readily determinable. We maintain insurance that may cover certain environmental expenditures.

     During the years ended December 31, 2009, 2008 and 2007, we incurred environmental expenses, net of insurance recoveries, of $10.6 million, $10.1 million and $7.4 million, respectively. At December 31, 2009 and 2008, we had accrued $29.9 million and $27.0 million, respectively, for environmental matters. The environmental

accruals are revised as new matters arise, or as new facts in connection with environmental remediation projects require a revision of estimates previously made with respect to the probable cost of such remediation projects. Changes in estimates of environmental remediation for each remediation project will affect operating income on a dollar-for-dollar basis up to our self-insurance limit. Our self-insurance limit is currently $3.0 million per occurrence.

Fair Value of Derivatives

     Our Energy Services segment primarily uses exchange-traded refined petroleum product futures contracts to manage the risk of market price volatility on its refined petroleum product inventories and its fixed-price sales contracts. See Note 8 in the Notes to Consolidated Financial Statements for further discussion. The Energy Services segment has not used hedge accounting with respect to its fixed-price sales contracts. Therefore, its fixed-price sales contracts and the related futures contracts used to offset those fixed-price sales contracts are all marked-to-market on our balance sheet with gains and losses being recognized in earnings during the period. At December 31, 2009, we included in our consolidated financial statements as assets fixed-price sales contracts with asset values of approximately $2.4 million. We have entered into futures contracts to hedge against changes in value of these fixed price sales contracts. These futures contracts have a net value of approximately $7.1 million at December 31, 2009 and have been recognized as assets on our balance sheet. We have determined that the exchange-traded futures contracts represent Level 1 fair value measurements because the prices for such futures contracts are established on liquid exchanges with willing buyers and sellers and with prices which are readily available on a daily basis.

     We have determined that the fixed-price sales contracts represent Level 2 fair value measurements because their value is derived from similar contracts for similar delivery and settlement terms which are traded on established exchanges. However, because the fixed-price sales contracts are privately negotiated with customers of the Energy Services segment who are generally smaller, private companies that may not have established credit ratings, the determination of an adjustment to fair value to reflect counterparty credit risk (a “credit valuation adjustment”) requires significant management judgment. At December 31, 2009, we had reduced the fair value of the fixed-price sales contracts by a $0.9 million credit valuation adjustment to reflect this counterparty credit risk. The delivery periods for the contracts range from one to 13 months, with the substantial majority of deliveries concentrated in the first four months of 2010.

     Because little or no public credit information is available for the Energy Services segment’s customers who have fixed-price sales contracts, we specifically analyzed each customer and contract to evaluate (i) the historical payment patterns of the customer, (ii) the current outstanding receivables balances for each customer and contract and (iii) the level of performance of each customer with respect to volumes called for in the contract. We then evaluated the specific risks and expected outcomes of nonpayment or nonperformance by each customer and contract. Based on our credit and performance risk evaluation, we recorded the credit valuation adjustment of $0.9 million. If actual customer performance under these fixed-price sales contracts deteriorates (either through nonperformance with respect to contracted volumes or nonpayment of amounts due), then the fair value of these contracts could be materially less. For example, a 10% shortfall in delivered volumes over the average life of the contracts would reduce the fair value of the contracts and, accordingly, net income, by $0.2 million. We continue to monitor and evaluate performance and collections with respect to these fixed-price sales contracts.

Measuring the Fair Value of Goodwill

     Goodwill represents the excess of purchase prices paid by us in certain business combinations over the fair values assigned to the respective net tangible and identifiable intangible assets. We do not amortize goodwill; rather, we test our goodwill (at the reporting unit level) for impairment on January 1 of each fiscal year, and more frequently if circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. A reporting unit is a business segment or one level below a business segment for which discrete financial information is available and regularly reviewed by segment management. Our reporting units are our business segments. An estimate of the fair value of a reporting unit is determined using a combination of a market multiple valuation method and an expected present value of future cash flows valuation method. The principal assumptions utilized in this valuation model include: (1) discrete financial forecasts for the assets contained within the reporting unit, which rely on management’s estimates of revenue, operating expenses and volumes; (2) long-term growth rates for cash

flows beyond the discrete forecast period; (3) appropriate discount rates; and (4) determination of appropriate market multiples from comparable companies.

     If the fair value of the reporting unit (including its inherent goodwill) is less than its carrying value, a charge to earnings is required to reduce the carrying value of the goodwill to its implied fair value. At December 31, 2009 and 2008, the carrying value of our goodwill was $208.9 million and $210.6 million, respectively. Goodwill decreased by $1.8 million as of December 31, 2009 from December 31, 2008 due to the finalization of the purchase price allocation relating to the acquisition of a terminal in Albany, New York in 2008; this $1.8 million was allocated to property, plant and equipment. We did not record any goodwill impairment charges during the years ended December 31, 2009, 2008 and 2007. A 10% decrease in the estimated fair value of any of our reporting units would have had no impact on the carrying value of goodwill at the annual measurement date.

Measuring Recoverability of Long-Lived Assets and Equity Method Investments

     In general, long-lived assets (including intangible assets with finite useful lives and property, plant and equipment) are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Such events or changes include, among other factors: operating losses, unused capacity; market value declines; technological developments resulting in obsolescence; changes in demand for products in a market area; changes in competition and competitive practices; and changes in governmental regulations or actions. Recoverability of the carrying amount of assets to be held and used is measured by a comparison of the carrying amount of the asset to estimated future undiscounted net cash flows expected to be generated by the asset. Estimates of future undiscounted net cash flows include anticipated future revenues, expected future operating costs and other estimates. Such estimates of future undiscounted net cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or estimated fair value less costs to sell. We recorded an impairment of $59.7 million during the year ended December 31, 2009 related to an impairment of Buckeye NGL. A significant loss in the customer base utilizing Buckeye’s NGL pipeline, in conjunction with the authorization by the Board of Directors of Buckeye GP to pursue the sale of Buckeye NGL, triggered an evaluation of a potential asset impairment that resulted in a non-cash charge to earnings of $72.5 million in the Pipeline Operations segment in the second quarter of 2009. Effective January 1, 2010, we sold our ownership interest in Buckeye NGL for $22.0 million. The sales proceeds exceeded the previously impaired carrying value of the assets of Buckeye NGL by $12.8 million resulting in the reversal of $12.8 million of the previously recorded asset impairment expense in the fourth quarter of 2009. See Note 8 in the Notes to Consolidated Financial Statements for further discussion.

     An equity method investment is evaluated for impairment whenever events or changes in circumstances indicate that there is a possible other than temporary loss in value of the investment. Examples of such events include sustained operating losses of the investee or long-term negative changes in the investee’s industry. The carrying value of an equity method investment is not recoverable if it exceeds the sum of discounted estimated cash flow expected to be derived from the investment. This estimate of discounted cash flows is based on a number of assumptions including discount rates; probabilities assigned to different cash flow scenarios; anticipated margins and volumes and estimated useful life of the investment. A significant change in these underlying assumptions could result in our recording an impairment charge.

Other Considerations

Contractual Obligations

     The following table summarizes our contractual obligations as of December 31, 2009 (in thousands):

		Payments Due by Period
						Less than 1												More than 5
		Total				year				1-3 years				3-5 years				years
Long-term debt (1)		$	1,503,000			$	—			$	78,000			$	575,000			$	850,000
Interest payments (2)			709,646				78,256				156,512				133,139				341,739
Operating leases: (3)
Office space and other			18,978				1,528				3,075				3,178				11,197
Land leases (4)			311,747				2,945				6,341				6,951				295,510
Purchase obligations (5)			32,480				32,480				—				—				—
Capital expenditure obligations (6)			1,611				1,611				—				—				—
Total		$	2,577,462			$	116,820			$	243,928			$	718,268			$	1,498,446

     In addition, our obligations related to our pension and postretirement benefit plans are discussed in Note 17 in the Notes to Consolidated Financial Statements.

Employee Stock Ownership Plan

     Services Company provides an employee stock ownership plan (the “ESOP”) to the majority of its employees hired before September 16, 2004. Employees hired by Services Company after September 15, 2004, and certain employees covered by a union multiemployer pension plan do not participate in the ESOP. The ESOP owns all of the outstanding common stock of Services Company.

     At December 31, 2009, the ESOP was directly obligated to a third-party lender for $7.7 million with respect to the 3.60% Notes due 2011 (the “3.60% ESOP Notes”). The 3.60% ESOP Notes were issued on May 4, 2004 to refinance Services Company’s 7.24% ESOP Notes which were originally issued to purchase Services Company common stock. The 3.60% ESOP Notes are collateralized by Services Company common stock and are guaranteed by Services Company. We have committed that, in the event that the value of our LP Units owned by Services Company falls to less than 125% of the balance payable under the 3.60% ESOP Notes, we will fund an escrow account with sufficient assets to bring the value of the total collateral (the value of LP Units owned by Services Company and the escrow account) up to the 125% minimum. Amounts deposited in the escrow account are returned to us when the value of the LP Units owned by Services Company returns to an amount which exceeds the 125% minimum. At December 31, 2009, the value of the LP Units owned by Services Company was approximately $89.3 million, which exceeded the 125% requirement.

     Services Company stock is released to employee accounts in the proportion that current payments of principal and interest on the 3.60% ESOP Notes bear to the total of all principal and interest payments due under the 3.60% ESOP Notes. Individual employees are allocated shares based upon the ratio of their eligible compensation to total eligible compensation. See Note 19 in the Notes to Consolidated Financial Statements for further information.

Off-Balance Sheet Arrangements

     We have no off-balance sheet arrangements except for operating leases and outstanding letters of credit (see Note 13 in the Notes to Consolidated Financial Statements).

Related Party Transactions

     With respect to related party transactions, see Note 20 in the Notes to Consolidated Financial Statements and Item 13, “Certain Relationships and Related Transactions and Director Independence.”

Recent Accounting Pronouncements

     See Note 2 in the Notes to Consolidated Financial Statements for a description of certain new accounting pronouncements that will or may affect our consolidated financial statements.

PART IV

Item 15.		Exhibits, Financial Statement Schedules

     (a) The following documents are filed as a part of this Report:

	(1)		Financial Statements — see Index to Consolidated Financial Statements.
	(2)		Financial Statement Schedules — None.
	(3)		Exhibits, including those incorporated by reference. The following is a list of exhibits filed as part of this Report.

Exhibit
Number		Description
2.1		Purchase and Sale Agreement, dated as of July 24, 2007, by and between Lodi Holdings, L.L.C., as seller, and Buckeye Gas Storage LLC, as buyer (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on July 24, 2007).
2.2		Amendment No. 1 to the Purchase and Sale Agreement, dated as of October 31, 2007, by and between Lodi Holdings, L.L.C. and Buckeye Gas Storage LLC (Incorporated by reference to Exhibit 2.2 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on January 18, 2008).
2.3		Amendment No. 2 to the Purchase and Sale Agreement, dated as of November 13, 2007, by and between Lodi Holdings, L.L.C. and Buckeye Gas Storage LLC (Incorporated by reference to Exhibit 2.3 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on January 18, 2008).
2.4		Purchase Agreement, dated as of December 21, 2007, by and among Farm & Home Oil Company, Richard A. Longacre, as sellers’ representative and Buckeye Energy Holdings LLC (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on December 21, 2007).
3.1		Amended and Restated Agreement of Limited Partnership of Buckeye Partners, L.P., dated as of April 14, 2008, effective as of January 1, 2007 (Incorporated by reference to Exhibit 3.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on April 15, 2008).
3.2		Amended and Restated Certificate of Limited Partnership of the Partnership, dated as of February 4, 1998 (Incorporated by reference to Exhibit 3.2 of Buckeye Partners, L.P.’s Annual Report on Form 10-K for the year ended December 31, 1997).
3.3		Certificate of Amendment to Amended and Restated Certificate of Limited Partnership of the Partnership, dated as of April 26, 2002 (Incorporated by reference to Exhibit 3.2 of Buckeye Partners, L.P.’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2002).
3.4		Certificate of Amendment to Amended and Restated Certificate of Limited Partnership of the Partnership, dated as of June 1, 2004, effective as of June 3, 2004 (Incorporated by reference to Exhibit 3.3 of the Buckeye Partners, L.P.’s Registration Statement on Form S-3 filed June 16, 2004).
3.5		Certificate of Amendment to Amended and Restated Certificate of Limited Partnership of the Partnership, dated as of December 15, 2004 (Incorporated by reference to Exhibit 3.5 of Buckeye Partners, L.P.’s Annual Report on Form 10-K for the year ended December 31, 2004).
4.1		Indenture dated as of July 10, 2003, between Buckeye Partners, L.P. and SunTrust Bank, as Trustee (Incorporated by reference to Exhibit 4.1 of Buckeye Partners, L.P.’s Registration Statement on Form S-4 filed September 19, 2003).

4.2		First Supplemental Indenture dated as of July 10, 2003, between Buckeye Partners, L.P. and SunTrust Bank, as Trustee (Incorporated by reference to Exhibit 4.2 of Buckeye Partners, L.P.’s Registration Statement on Form S-4 filed September 19, 2003).
4.3		Second Supplemental Indenture dated as of August 19, 2003, between Buckeye Partners, L.P. and SunTrust Bank, as Trustee (Incorporated by reference to Exhibit 4.3 of Buckeye Partners, L.P.’s Registration Statement on Form S-4 filed September 19, 2003).
4.4		Third Supplemental Indenture dated as of October 12, 2004, between Buckeye Partners, L.P. and SunTrust Bank, as Trustee (Incorporated by reference to Exhibit 4.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on October 14, 2004).
4.5		Fourth Supplemental Indenture dated as of June 30, 2005, between Buckeye Partners, L.P. and SunTrust Bank, as Trustee (Incorporated by reference to Exhibit 4.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on June 30, 2005).
4.6		Fifth Supplemental Indenture dated as of January 11, 2008, between Buckeye Partners, L.P. and U.S. Bank National Association (successor to SunTrust Bank), as Trustee (Incorporated by reference to Exhibit 4.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on January 11, 2008).
4.7		Sixth Supplemental Indenture dated as of August 18, 2009, between Buckeye Partners, L.P. and U.S. Bank National Association (successor-in-interest to SunTrust Bank), as Trustee (Incorporated by reference to Exhibit 4.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on August 24, 2009).
10.1		Amended and Restated Agreement of Limited Partnership of Buckeye Pipe Line Company, L.P., as amended and restated as of August 9, 2006 (Incorporated by reference to Exhibit 10.2 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on August 14, 2006). (1)
10.2		Amended and Restated Management Agreement of Buckeye Pipe Line Company, L.P., as amended and restated as of August 9, 2006 (Incorporated by reference to Exhibit 10.3 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on August 14, 2006). (2)
10.3		Limited Liability Company Agreement of Wood River Pipe Lines LLC, dated as of September 27, 2004 (Incorporated by reference to Exhibit 10.3 of Buckeye Partners, L.P.’s Annual Report on Form 10-K for the year ended December 31, 2004).
10.4		Services Agreement dated as of December 15, 2004, among Buckeye Partners, L.P., the Operating Subsidiaries and Services Company (Incorporated by reference to Exhibit 10.3 of Buckeye Partners, L.P.’s Current Report on Form 8-K dated December 20, 2004).
10.5		First Amendment to Services Agreement, dated as of October 15, 2008, among Buckeye Partners, L.P., Buckeye Pipe Line Services Company, and the subsidiary partnerships and limited liability companies of Buckeye set forth on the signature pages thereto. (Incorporated by reference to Exhibit 10.2 of Buckeye Partners, L.P.’s Current Report on Form 8-K dated October 16, 2008).
10.6		Fifth Amended and Restated Exchange Agreement, dated as of October 15, 2008, among Buckeye GP Holdings L.P., Buckeye GP LLC, Buckeye Partners, L.P., MainLine L.P., Buckeye Pipe Line Company, L.P., Laurel Pipe Line Company, L.P., Everglades Pipe Line Company, L.P., and Buckeye Pipe Line Holdings, L.P. (Incorporated by reference to Exhibit 10.6 of Buckeye Partners, L.P.’s Annual Report on Form 10-K for the year ended December 31, 2008).
*10.7		Amended and Restated Employment and Severance Agreement, dated as of October 25, 2007, by and among Stephen C. Muther, Buckeye GP Holdings L.P. and Buckeye Pipe Line Services Company (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on October 26, 2007).

*10.8		Severance Agreement, dated as of November 10, 2008, by and among Buckeye Partners, L.P., Buckeye GP Holdings L.P., Buckeye Pipe Line Services Company, and Keith E. St.Clair (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on November 10, 2008).
*10.9		Severance Agreement, dated as of February 17, 2009, by and among Buckeye Partners, L.P., Buckeye Pipe Line Services Company, and Clark C. Smith (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on February 17, 2009).
*10.10		Amended and Restated Unit Option and Distribution Equivalent Plan of Buckeye Partners, L.P., dated as of April 1, 2005 (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on April 4, 2005).
*10.11		Fifth Amended and Restated Incentive Compensation Agreement, dated as of August 9, 2006, between Buckeye Partners, L.P. and Buckeye GP LLC (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on August 14, 2006).
*10.12		Buckeye Partners, L.P. 2009 Long-Term Incentive Plan, as amended (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2009).
*/***10.13		Buckeye Partners, L.P. Annual Incentive Compensation Plan, as amended and restated, effective as of January 1, 2010.
*10.14		Deferral Unit and Incentive Plan (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on December 17, 2009).
*10.15		Full Waiver and Release of Claims, dated as of Mary 8, 2009, by Vance E. Powers (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2009).
10.16		Credit Agreement, dated November 13, 2006, among Buckeye Partners, L.P., as borrower, SunTrust Bank, as administrative agent, and the lenders signatory thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on November 16, 2006).
10.17		First Amendment to Credit Agreement, dated as of May 18, 2007, by and among Buckeye Partners, L.P., as borrower, SunTrust Bank, as administrative agent, and the lenders signatory thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2007).
10.18		Second Amendment to Credit Agreement, dated August 24, 2007, among Buckeye Partners, L.P., SunTrust Bank, as administrative agent, and the lenders signatory thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Form Current Report on 8-K filed on August 28, 2007).
10.19		Third Amendment to Credit Agreement, dated January 23, 2008, among Buckeye Partners, L.P., SunTrust Bank, as administrative agent, and the lenders signatory thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on January 28, 2008).
10.20		Fourth Amendment to Credit Agreement, dated August 21, 2009, among Buckeye Partners, L.P., SunTrust Bank, as administrative agent, and the lenders signatory thereto (Incorporated by reference to Exhibit 10.2 of Buckeye Partners, L.P.’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2009).
10.21		Credit Agreement, dated as of May 20, 2008, by and among Farm & Home Oil Company LLC, Buckeye Energy Services LLC, BNP Paribas and other lenders party thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on May 23, 2008).
10.22		First Amendment, dated as of July 18, 2008, to the Credit Agreement, dated as of May 20, 2008, among Farm & Home Oil Company LLC, Buckeye Energy Services LLC, BNP Paribas and other lenders party thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on July 22, 2008).

10.23		Second Amendment and Increase Agreement, dated as of September 15, 2008, to the Credit Agreement, dated as of May 20, 2008, among Farm & Home Oil Company LLC, Buckeye Energy Services LLC, BNP Paribas and other lenders party thereto (Incorporated by reference to Exhibit 10.20 of Buckeye Partners, L.P.’s Annual Report on Form 10-K for the year ended December 31, 2008).
10.24		Third Increase Agreement and Waiver, dated as of August 12, 2009, to the Credit Agreement, dated as of May 20, 2008, among Buckeye Energy Services LLC, BNP Paribas and other lenders party thereto (Incorporated by reference to Exhibit 10.1 of Buckeye Partners, L.P.’s Current Report on Form 8-K filed on August 14, 2009).
***12.1		Computation of Ratio of Earnings to Fixed Charges.
***21.1		List of Subsidiaries of Buckeye Partners, L.P.
***23.1		Consent of Deloitte & Touche LLP
**31.1		Certification of Chief Executive Officer pursuant to Rule 13a-14 (a) under the Securities Exchange Act of 1934.
**31.2		Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
***32.1		Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350.
***32.2		Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350.

SIGNATURES

     Pursuant to the requirements of Section 13 of 15(d) 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.