Edgar Filing: SUNOCO LOGISTICS PARTNERS LP

Sunoco Logistics Partners LP--Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2008

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

For the transition period from __________ to ________

Commission file number 1-31219

SUNOCO LOGISTICS PARTNERS L.P.

(Exact name of registrant as specified in its charter)


Delaware		23-3096839
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Mellon Bank Center 1735 Market Street, Suite LL, Philadelphia, PA		19103-7583
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (866) 248-4344

Former name, former address and formal fiscal year, if changed since last report: Not Applicable

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ¨ No x

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act.: Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨

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

At August 5, 2008, the number of the registrant’s Common Units outstanding was 28,657,485.

SUNOCO LOGISTICS PARTNERS L.P.

INDEX


		Page No.
PART I. FINANCIAL INFORMATION

Item 1.	Financial Statements

	Condensed Consolidated Statements of Income for the Three Months Ended June 30, 2008 and 2007 (unaudited)	3

	Condensed Consolidated Statements of Income for the Six Months Ended June 30, 2008 and 2007 (unaudited)	4

	Condensed Consolidated Balance Sheets at June 30, 2008 (unaudited) and December 31, 2007	5

	Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2008 and 2007 (unaudited)	6

	Notes to Condensed Consolidated Financial Statements (unaudited)	7

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	30

Item 4.	Controls and Procedures	33

PART II. OTHER INFORMATION

Item 1.	Legal Proceedings	33

Item 1A.	Risk Factors	33

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	33

Item 3.	Defaults Upon Senior Securities	33

Item 4.	Submission of Matters to a Vote of Security Holders	33

Item 5.	Other Information	33

Item 6.	Exhibits	34

SIGNATURE		35

PART I

FINANCIAL INFORMATION

Item 1.

Financial Statements

SUNOCO LOGISTICS PARTNERS L.P.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

(in thousands, except unit and per unit amounts)


	Three Months Ended June 30,
	2008			2007
Revenues
Sales and other operating revenue:
Affiliates (Note 3)	$	756,718		$	391,370
Unaffiliated customers		2,558,703			1,238,910
Other income		8,783			7,698

Total Revenues		3,324,204			1,637,978

Costs and Expenses
Cost of products sold and operating expenses		3,240,861			1,580,330
Depreciation and amortization		9,830			9,407
Selling, general and administrative expenses		14,126			13,487

Total Costs and Expenses		3,264,817			1,603,224

Operating Income		59,387			34,754
Net interest with affiliates (Note 3)		523			1,059
Other interest cost and debt expense, net		8,405			9,386
Capitalized interest		(864	)		(945	)

Net Income	$	51,323		$	25,254

Calculation of Limited Partners’ interest in Net Income (Note 4):
Net Income	$	51,323		$	25,254
Less: General Partner’s interest in Net Income		(16,565	)		(3,552	)

Limited Partners’ interest in Net Income	$	34,758		$	21,702

Net Income per Limited Partner unit:
Basic	$	1.21		$	0.76

Diluted	$	1.21		$	0.76

Weighted average Limited Partners’ units outstanding (Note 4):
Basic		28,657,485			28,586,280

Diluted		28,840,262			28,723,884

(See Accompanying Notes)

SUNOCO LOGISTICS PARTNERS L.P.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

(in thousands, except unit and per unit amounts)


	Six Months Ended June 30,
	2008			2007
Revenues
Sales and other operating revenue:
Affiliates (Note 3)	$	1,393,104		$	843,439
Unaffiliated customers		4,316,706			2,336,411
Other income		13,609			12,737

Total Revenues		5,723,419			3,192,587

Costs and Expenses
Cost of products sold and operating expenses		5,564,111			3,079,588
Depreciation and amortization		19,489			18,311
Selling, general and administrative expenses		29,557			29,006
Impairment charge (Note 5)		5,674			—

Total Costs and Expenses		5,618,831			3,126,905

Operating Income		104,588			65,682
Net interest cost paid to affiliates (Note 3)		417			1,594
Other interest cost and debt expense, net		16,981			18,025
Capitalized interest		(1,636	)		(1,498	)

Net Income	$	88,826		$	47,561

Calculation of Limited Partners’ interest in Net Income (Note 4):
Net Income	$	88,826		$	47,561
Less: General Partner’s interest in Net Income		(26,219	)		(5,631	)

Limited Partners’ interest in Net Income	$	62,607		$	41,930

Net Income per Limited Partner unit:
Basic	$	2.19		$	1.47

Diluted	$	2.17		$	1.46

Weighted average Limited Partners’ units outstanding (Note 4):
Basic		28,642,571			28,575,697

Diluted		28,823,146			28,713,365

(See Accompanying Notes)

SUNOCO LOGISTICS PARTNERS L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)


	June 30, 2008			December 31, 2007
	(UNAUDITED)
Assets
Current Assets
Cash and cash equivalents	$	2,000		$	2,000
Advances to affiliates (Note 3)		14,234			8,060
Accounts receivable, affiliated companies (Note 3)		279,072			62,167
Accounts receivable, net		1,977,472			1,200,782
Inventories:
Crude oil		37,647			29,145
Refined product additives		424			682
Materials, supplies and other		842			842

Total Current Assets		2,311,691			1,303,678

Properties, plants and equipment		1,672,338			1,625,782
Less accumulated depreciation and amortization		(555,418	)		(536,520	)

Properties, plants and equipment, net		1,116,920			1,089,262

Investment in affiliates (Note 6)		85,623			84,985
Deferred charges and other assets		36,094			26,717

Total Assets	$	3,550,328		$	2,504,642

Liabilities and Partners’ Capital
Current Liabilities
Accounts payable	$	2,294,493		$	1,289,402
Accrued liabilities		48,113			45,159
Accrued taxes other than income taxes		46,807			34,277

Total Current Liabilities		2,389,413			1,368,838
Long-term debt (Note 7)		514,201			515,104
Other deferred credits and liabilities		28,683			29,655
Commitments and contingent liabilities (Note 8)

Total Liabilities		2,932,297			1,913,597

Partners’ Capital:
Limited partners’ interest		597,186			582,357
General partner’s interest		20,845			8,688

Total Partners’ Capital		618,031			591,045

Total Liabilities and Partners’ Capital	$	3,550,328		$	2,504,642

(See Accompanying Notes)

SUNOCO LOGISTICS PARTNERS L.P.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

(in thousands)


	Six Months Ended June 30,
	2008			2007
Cash Flows from Operating Activities:
Net Income	$	88,826		$	47,561
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		19,489			18,311
Impairment charge		5,674			—
Restricted unit incentive plan expense		2,280			3,389
Changes in working capital pertaining to operating activities:
Accounts receivable, affiliated companies		(216,905	)		23,026
Accounts receivable, net		(776,690	)		(145,799	)
Inventories		(8,244	)		(21,351	)
Accounts payable and accrued liabilities		1,007,970			124,153
Accrued taxes other than income		12,530			(2,916	)
Other		(754	)		6,978

Net cash provided by operating activities		134,176			53,352

Cash Flows from Investing Activities:
Capital expenditures		(52,495	)		(50,642	)
Completed Acquisitions		—			(13,173	)
MagTex Acquisition deposit		(10,462	)		—

Net cash used in investing activities		(62,957	)		(63,815	)

Cash Flows from Financing Activities:
Distributions paid to Limited Partners and General Partner		(64,694	)		(57,271	)
Payments of statutory withholding on net issuance of Limited Partner units under restricted unit incentive plan		(1,278	)		(1,479	)
Contributions from General Partner for Limited Partner unit transactions		76			58
Advances to affiliates, net		(6,174	)		(3,874	)
Borrowings under credit facility		85,000			91,900
Repayments under credit facility		(86,000	)		(20,000	)
Contributions from affiliate		1,851			752

Net cash (used in) provided by financing activities		(71,219	)		10,086

Net change in cash and cash equivalents		—			(377	)
Cash and cash equivalents at beginning of year		2,000			9,412

Cash and cash equivalents at end of period	$	2,000		$	9,035

(See Accompanying Notes)

SUNOCO LOGISTICS PARTNERS L.P.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1.	Basis of Presentation

Sunoco Logistics Partners L.P. (the “Partnership”) is a Delaware limited partnership formed by Sunoco, Inc. (“Sunoco”) in October 2001 to acquire, own and operate a substantial portion of Sunoco’s logistics business, consisting of refined product pipelines, terminalling and storage assets, crude oil pipelines, and crude oil acquisition and marketing assets located in the Northeast, Midwest and South Central United States. Sunoco, Inc. and its wholly-owned subsidiaries including Sunoco, Inc. (R&M) are collectively referred to as “Sunoco”. The financial statements of the Partnership contain the accounts of the Partnership and its subsidiaries. Equity ownership interests in corporate joint ventures, which are not consolidated, are accounted for under the equity method.

The consolidated financial statements reflect the results of Sunoco Logistics Partners L.P. and its wholly-owned partnerships, including Sunoco Logistics Partners Operations L.P. (the “Operating Partnership”). Equity ownership interests in corporate joint ventures, which are not consolidated, are accounted for under the equity method.

The accompanying condensed consolidated financial statements are presented in accordance with the requirements of Form 10-Q and accounting principles generally accepted in the United States for interim financial reporting. They do not include all disclosures normally made in financial statements contained in Form 10-K. In management’s opinion, all adjustments necessary for a fair presentation of the results of operations, financial position and cash flows for the periods shown have been made. All such adjustments are of a normal recurring nature, except for the impairment charge (Note 5). Results for the six months ended June 30, 2008 are not necessarily indicative of results for the full year 2008.

2.	Acquisitions

Syracuse Terminal Acquisition

On June 4, 2007, the Partnership purchased a 50% undivided interest in a refined products terminal located in Syracuse, New York from Mobil Pipe Line Company, an affiliate of Exxon Mobil Corporation for approximately $13.4 million. Total terminal storage capacity is approximately 550,000 barrels. The purchase price of the acquisition was funded with borrowings under the Partnership’s Credit Facility, and has been preliminarily allocated to property, plants and equipment based on the relative fair value of the assets acquired on the acquisition date. The results of the acquisition are included in the financial statements within the Terminal Facilities business segment from the date of acquisition.

MagTex Refined Products Pipeline System Acquisition

On April 28, 2008, Sunoco Pipeline L.P., a subsidiary of the Partnership, entered into a definitive agreement to acquire a refined products pipeline system and certain other real and personal property interests and assets from Mobil Pipe Line Company, an affiliate of Exxon Mobil Corporation. The pipeline system consists of approximately 275 miles of refined products pipeline originating in Beaumont and Port Arthur, Texas and terminating in Hearne, Texas and an additional 197 miles of refined products pipeline extending from Beaumont, Texas and terminating in Waskom, Texas. In addition to the pipeline system, Sunoco Partners Marketing &Terminals L.P., a subsidiary of the Partnership, entered into definitive agreements with Exxon Mobil Corporation, Mobil Pipe Line Company and ExxonMobil Oil Corporation, also affiliates of Exxon Mobil Corporation, to acquire six refined products terminal facilities. The terminal facilities are located in Hearne, Hebert, Waco, Center and Waskom, Texas and Arcadia, Louisiana and have combined storage capacity of approximately 1.2 million shell barrels. The acquisitions are subject to certain closing conditions. The transactions, with a combined purchase price of approximately $200.0 million, are expected to be completed in the third quarter of 2008.

3.	Related Party Transactions

Advances to/from Affiliate

The Partnership has a treasury services agreement with Sunoco pursuant to which it, among other things, participates in Sunoco’s centralized cash management program. Under this program, all of the Partnership’s cash receipts and cash disbursements are processed, together with those of Sunoco and its other subsidiaries, through Sunoco’s cash accounts with a corresponding credit or charge to an intercompany account. The intercompany balances are settled periodically, but no less frequently than monthly. Amounts due from Sunoco earn interest at a rate equal to the average rate of the Partnership’s third-party money market investments, while amounts due to Sunoco bear interest at a rate equal to the interest rate provided in the Partnership’s $400 million revolving credit facility (see Note 7).

Administrative Services

Selling, general and administrative expenses in the condensed consolidated statements of income include costs incurred by Sunoco for the provision of certain centralized corporate functions such as legal, accounting, treasury, engineering, information technology, insurance and other corporate services, including the administration of employee benefit plans. These are provided to the Partnership under an omnibus agreement (“Omnibus Agreement”) with Sunoco for an annual administrative fee. The fee for the annual period ended December 31, 2007 was $6.5 million. In January 2008, the parties extended the term of Section 4.1 of the Omnibus Agreement (which concerns the Partnership’s obligation to pay the annual fee for provision of certain general and administrative services) by one year. The annual administrative fee applicable to this one-year extension is $6.0 million, which reflects the Partnership directly incurring some of these general and administrative costs. These costs may be increased if the acquisition or construction of new assets or businesses requires an increase in the level of general and administrative services received by the Partnership. There can be no assurance that Section 4.1 of the Omnibus Agreement will be extended beyond 2008, or that, if extended, the administrative fee charged by Sunoco will be at or below the current administrative fee. In the event that the Partnership is unable to obtain such services from Sunoco or third parties at or below the current cost, the Partnership’s financial condition and results of operations may be adversely impacted.

The annual administrative fee does not include the costs of shared insurance programs, which are allocated to the Partnership based upon its share of the cash premiums incurred. This fee also does not include salaries of pipeline and terminal personnel or other employees of the general partner, or the cost of their employee benefits. These employees are employees of the Partnership’s general partner or its affiliates, which are wholly-owned subsidiaries of Sunoco. The Partnership has no employees. Allocated Sunoco employee benefit plan expenses for employees who work in the pipeline, terminalling, storage and crude oil gathering operations, including senior executives, include non-contributory defined benefit retirement plans, defined contribution 401(k) plans, employee and retiree medical, dental and life insurance plans, incentive compensation plans, and other such benefits. The Partnership is reimbursing Sunoco for these costs and other direct expenses incurred on its behalf. These expenses are reflected in cost of products sold and operating expenses and selling, general and administrative expenses in the condensed consolidated statements of income.

Affiliated Revenues and Accounts Receivable, Affiliated Companies

Affiliated revenues in the statements of income consist of sales of crude oil as well as the provision of crude oil and refined product pipeline transportation, terminalling and storage services to Sunoco. Sales of crude oil are priced using market based rates. Pipeline revenues are generally determined using posted tariffs. In 2002, the Partnership entered into a pipelines and terminals storage and throughput agreement and various other agreements with Sunoco under which the Partnership is charging Sunoco fees for services provided under these agreements that, in management’s opinion, are comparable to those charged in arm’s-length, third-party transactions. Under the pipelines and terminals storage and throughput agreement, Sunoco has agreed to pay the Partnership a minimum level of revenues for transporting refined products. Sunoco also has agreed to minimum throughputs of crude oil and liquefied petroleum gas in the Partnership’s Inkster Terminal, Fort Mifflin Terminal Complex and certain crude oil pipelines. During the first quarter of 2007, the agreement to throughput at the Partnership’s refined product terminals and to receive and deliver refined product into the Partnership’s Marcus Hook Tank Farm expired. On March 1, 2007 the Partnership entered into new five year agreements with Sunoco to provide these services. These new agreements contain no minimum throughput obligations for Sunoco.

Under various other agreements entered into in 2002, Sunoco is, among other things, purchasing from the Partnership, at market-based rates, particular grades of crude oil that the Partnership’s crude oil acquisition and marketing business purchases for delivery to certain pipelines. These agreements automatically renew on a monthly basis unless terminated by either party on 30 days’ written notice. Sunoco has also leased the Partnership’s 58 miles of interrefinery pipelines between Sunoco’s Philadelphia and Marcus Hook refineries for a term of 20 years.

Capital Contributions

The Partnership has agreements with Sunoco which requires Sunoco to, among other things, reimburse the Partnership for certain expenditures. These agreements include:

•

the Interrefinery Lease Agreement, which requires Sunoco to reimburse the Partnership for any non-routine maintenance expenditures incurred, as defined through February 2022; and

•

the Eagle Point purchase agreements, which requires Sunoco to reimburse the Partnership for certain capital improvement projects incurred regarding the assets acquired. On January 24, 2008 Sunoco and the Partnership entered into an Amended and Restated Dock and Terminal Throughput Agreement for the Eagle Point logistics assets. Pursuant to the amended agreement the Partnership is obligated to make certain capital improvements to the Eagle Point docks. The term for the parties’ obligations with respect to the docks has been extended from March 31, 2016 to December 31, 2026. The rates to be paid by Sunoco for throughput across the docks have been modified to reflect the capital improvements, and the rates escalate annually based on the Consumer Price Index. Sunoco’s throughput obligations across the docks remain unchanged.

The parties’ obligations with respect to the Eagle Point terminal remain unchanged except that the throughput rates escalate annually based on the increase in the Consumer Price Index.

During the six months ended June 30, 2008 and 2007, the Partnership was reimbursed $1.9 million and $0.8 million, respectively, associated with these agreements. The reimbursement of these amounts was recorded by the Partnership as capital contributions to Partners’ Capital within the condensed consolidated balance sheet at June 30, 2008.

In February 2008 and 2007 the Partnership issued 0.1 million common units in each period to participants in the Sunoco Partners LLC Long-Term Incentive Plan (“LTIP”) upon completion of award vesting requirements. As a result of these issuances of common units, the general partner contributed $0.1 million in each period to the Partnership to maintain its 2.0 percent general partner interest. The Partnership recorded these amounts as capital contributions to Partners’ Capital within its condensed consolidated balance sheets.

4.	Net Income Per Unit Data

Basic and diluted net income per limited partner unit is calculated by dividing net income, after deducting the amount allocated to the general partner’s interest, by the weighted-average number of limited partner common and subordinated units outstanding during the period.

The general partner’s interest in net income consists of its 2.0 percent general partner interest and “incentive distributions”, which are increasing percentages, up to 50 percent of quarterly distributions in excess of $0.50 per limited partner unit (see Note 11). The general partner was allocated net income of $16.6 million (representing 32.3 percent of total net income for the period) and $3.6 million (representing 14.1 percent of total net income for the period) for the three months ended June 30, 2008 and 2007, respectively, and $26.2 million (representing 29.5 percent of total net income for the period) and $5.6 million (representing 11.8 percent of total net income for the period) for the six months ended June 30, 2008 and 2007, respectively diluted net income per limited partner unit is calculated by dividing net income applicable to limited partners’ by the sum of the weighted-average number of common and subordinated units outstanding and the dilutive effect of incentive unit awards, as calculated by the treasury stock method.

The following table sets forth the reconciliation of the weighted average number of limited partner units used to compute basic net income per limited partner unit to those used to compute diluted net income per limited partner unit for the three and six months ended June 30, 2008 and 2007:


	Three Months Ended June 30,		Six Months Ended June 30,
	2008	2007	2008	2007
Weighted average number of limited partner units outstanding – basic	28,657,485	28,586,280	28,642,571	28,575,697
Add effect of dilutive unit incentive awards	182,777	137,604	180,575	137,668

Weighted average number of limited partner units – diluted	28,840,262	28,723,884	28,823,146	28,713,365

5.	Impairment Charge

Long-lived assets other than those held for sale are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. In the first quarter of 2008, the Partnership recognized an impairment of $5.7 million related to Management’s decision to discontinue efforts to expand liquefied petroleum gas storage capacity at its Inkster, Michigan facility. The impairment charge reflects the entire cost associated with the project.

6.	Investment in Affiliates

The Partnership’s ownership percentages in corporate joint ventures as of June 30, 2008 and December 31, 2007 were as follows:


	Partnership Ownership Percentage
Explorer Pipeline Company	9.4	%
West Shore Pipe Line Company	12.3	%
Yellowstone Pipe Line Company	14.0	%
Wolverine Pipe Line Company	31.5	%
West Texas Gulf Pipe Line Company	43.8	%
Mid-Valley Pipeline Company⁽¹⁾	55.3	%

⁽¹⁾	The Partnership’s interest in the Mid-Valley Pipeline Company includes 50 percent voting rights.

The following table provides summarized combined statement of income data on a 100 percent basis for the Partnership’s corporate joint venture interests for the three and six months ended June 30, 2008 and 2007 (in thousands of dollars):


	Three Months Ended June 30,				Six Months Ended June 30,
	2008		2007		2008		2007
Income Statement Data:
Total revenues	$	123,870	$	133,564	$	232,173	$	243,253
Net income	$	30,741	$	40,573	$	56,152	$	70,545

The following table provides summarized combined balance sheet data on a 100 percent basis for the Partnership’s corporate joint venture interests as of June 30, 2008 and December 31, 2007 (in thousands of dollars):


	June 30, 2008		December 31, 2007
Balance Sheet Data:
Current assets	$	133,770	$	181,683
Non-current assets	$	667,483	$	692,331
Current liabilities	$	126,108	$	122,229
Non-current liabilities	$	591,213	$	661,777
Net equity	$	83,932	$	90,008

The Partnership’s investments in Wolverine, West Shore, Yellowstone, and West Texas Gulf at June 30, 2008 include an excess investment amount of approximately $54.0 million, net of accumulated amortization of $3.6 million. The excess investment is the difference between the investment balance and the Partnership’s proportionate share of the net assets of the entities. The excess investment was allocated to the underlying tangible and intangible assets. Other than land and indefinite-lived intangible assets, all amounts allocated, principally to pipeline and related assets, are amortized using the straight-line method over their estimated useful life of 40 years and included within depreciation and amortization in the condensed consolidated statements of income.

7.	Long-Term Debt

The components of long-term debt are as follows (in thousands of dollars):


	June 30, 2008			December 31, 2007
Credit Facility – due November 2012	$	90,000		$	91,000
Credit Facility – due May 2009		—			—
Senior Notes – 7.25%, due February 15, 2012		250,000			250,000
Senior Notes – 6.125%, due May 15, 2016		175,000			175,000
Less unamortized bond discount		(799	)		(896	)

	$	514,201		$	515,104

$400 Million Credit Facility

Sunoco Logistics Partners Operations L.P. (the “Operating Partnership”), a wholly-owned entity of the Partnership, has a five-year $400 million credit facility (“Credit Facility”). The Credit Facility is available to fund the Operating Partnership’s working capital requirements, to finance future acquisitions, to finance future capital projects and for general partnership purposes. The Credit Facility matures in November 2012 and may be prepaid at any time. It bears interest at the Operating Partnership’s option, at either (i) LIBOR plus an applicable margin, (ii) the higher of the federal funds rate plus 0.50 percent or the Citibank prime rate (each plus the applicable margin) or (iii) the federal funds rate plus an applicable margin. The Credit Facility contains various covenants limiting the Operating Partnership’s ability to incur indebtedness; grant certain liens; make certain loans, acquisitions and investments; make

any material change to the nature of its business; acquire another company; or enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership’s subsidiaries. The Credit Facility also limits the Operating Partnership, on a rolling four-quarter basis, to a maximum total debt to EBITDA ratio of 4.75 to 1, which can generally be increased to 5.25 to 1 during an acquisition period. The Operating Partnership is in compliance with this requirement as of June 30, 2008. The Partnership’s ratio of total debt to EBITDA was 2.5 to 1 at June 30, 2008.

$100 Million Credit Facility

In anticipation of the pending MagTex Acquisition, the Operating Partnership, entered into a $100 million 364 day revolving credit facility (“$100 million Credit Facility”) on May 28, 2008. The $100 million Credit Facility is available to fund the same activities as the Credit Facility described above. If the MagTex Acquisition is terminated, this new revolver will be terminated. The $100 million Credit Facility matures in May 2009 and can be prepaid at any time. Interest on outstanding borrowings is calculated, at the Operating Partnership’s option, using either (i) LIBOR plus an applicable margin or (ii) the higher of (a) the Federal funds rates plus 0.50 percent plus an applicable margin, and (b) the Citibank prime rate plus an applicable margin. The $100 million Credit Facility contains the same covenant requirements as the Credit Facility described above. As of June 30, 2008 there were no borrowings outstanding under the $100 million Credit Facility.

Letters of Credit

The Partnership entered into two standby letters of credit totaling $130.4 million. The letters of credit, which were effective January 1, 2008, are required in connection with certain crude oil exchange contracts in which the Partnership is a party. During the quarter, the Partnership met certain performance requirements defined within these contracts which reduced the letters of credit to $88.0 million. The letters of credit, which will expire in September 2008, are subject to commitment fees, which are not material.

Interest Rate Swap

The Partnership uses interest rate swaps, a type of derivative financial instrument, to manage interest costs and minimize the effects of interest rate fluctuations on cash flows associated with its credit facility. The Partnership does not use derivatives for trading or speculative purposes. While interest rate swaps are subject to fluctuations in value, these fluctuations are generally offset by the value of the underlying exposures being hedged. The Partnership minimizes the risk of credit loss by entering into these agreements with major financial institutions that have high credit ratings. The Partnership accounts for its interest rate swaps in accordance with SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities” (“SFAS 133”), which requires that all derivatives be recorded on the balance sheet at fair value. SFAS 133 also requires that changes in the fair value be recorded each period in current earnings or other comprehensive income, depending on whether a derivative has been designated as part of a hedge transaction and, if it is, depending on the type of hedge transaction. Interest rate swaps are designated as cash flow hedges. Changes in the fair value of a cash flow hedge, to the extent the hedge is effective, are recorded, net of tax, in other comprehensive income (loss), a component of Partners’ capital, until earnings are affected by the variability of the hedged cash flows. Cash flow hedge ineffectiveness, defined as the extent that the changes in the fair value of the derivative exceed the variability of cash flows of the forecasted transaction, is recorded currently in earnings.

In January 2008, the Partnership entered into a $50.0 million floating to fixed interest rate swap agreement (the “Swap”), maturing January 2010. Under the Swap, the Partnership receives interest equivalent to the three-month LIBOR and pays a fixed rate of interest of 3.489 percent with settlements occurring quarterly. The objective of the hedge is to eliminate the variability of cash flows in interest payments for $50.0 million of floating rate debt. To maintain hedge accounting for the Swap, the Partnership is committed to maintaining at least $50.0 million in borrowings at an interest rate based on the three-month LIBOR, plus an applicable margin, through January 2010. The Swap’s fair value of ($0.1) million as of June 30, 2008, is included in accrued liabilities on the condensed consolidated balance sheet and the corresponding change in fair value is included in other comprehensive income, a component of Partners’ equity.

8.	Commitments and Contingent Liabilities

The Partnership is subject to numerous federal, state and local laws which regulate the discharge of materials into the environment or that otherwise relate to the protection of the environment. These laws and regulations result in liabilities and loss contingencies for remediation at the Partnership’s facilities and at third-party or formerly owned sites. At June 30, 2008 and December 31, 2007, there were accrued liabilities for environmental remediation in the condensed consolidated balance sheets of $0.9 million and $1.1 million, respectively. The accrued liabilities for environmental remediation do not include any amounts attributable to unasserted claims, nor have any recoveries from insurance been assumed. Charges against income for environmental remediation totaled $0.3 million and $1.9 million for the three month periods ended June 30, 2008 and 2007, respectively, and $0.5 million and $2.3 million for the six month periods ended June 30, 2008 and 2007, respectively.

Total future costs for environmental remediation activities will depend upon, among other things, the identification of any additional sites, the determination of the extent of the contamination at each site, the timing and nature of required remedial actions, the technology available and needed to meet the various existing legal requirements, the nature and extent of future environmental laws, inflation rates and the determination of the Partnership’s liability at multi-party sites, if any, in light of uncertainties with respect to joint and several liability, and the number, participation levels and financial viability of other parties. As discussed below, the Partnership’s current and future costs have been and will be impacted by an indemnification from Sunoco.

The Partnership is a party to certain pending and threatened claims. Although the ultimate outcome of these claims cannot be ascertained at this time, it is reasonably possible that some portion of them could be resolved unfavorably to the Partnership and its predecessor. Management does not believe that any liabilities which may arise from such claims and the environmental matters discussed above would be material in relation to the financial position of the Partnership at June 30, 2008. Furthermore, Management does not believe that the overall costs for such matters will have a material impact, over an extended period of time, on the Partnership’s operations, cash flows or liquidity.

Sunoco has indemnified the Partnership for 30 years from environmental and toxic tort liabilities related to the assets contributed to the Partnership that arise from the operation of such assets prior to the closing of the February 2002 IPO. Sunoco has indemnified the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the February 2002 IPO. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent a year. For example, for a claim asserted during the twenty-third year after closing of the February 2002 IPO, Sunoco would be required to indemnify the Partnership for 80 percent of its loss. There is no monetary cap on the amount of indemnity coverage provided by Sunoco. The Partnership has agreed to indemnify Sunoco for events and conditions associated with the operation of the Partnership’s assets that occur on or after the closing of the February 2002 IPO and for environmental and toxic tort liabilities to the extent Sunoco is not required to indemnify the Partnership.

Sunoco also has indemnified the Partnership for liabilities, other than environmental and toxic tort liabilities related to the assets contributed to the Partnership, that arise out of Sunoco’s ownership and operation of the assets prior to the closing of the February 2002 IPO and that are asserted within 10 years after closing of the February 2002 IPO. In addition, Sunoco has indemnified the Partnership from liabilities relating to certain defects in title to the assets contributed to the Partnership and associated with failure to obtain certain consents and permits necessary to conduct its business that arise within 10 years after closing of the February 2002 IPO as well as from liabilities relating to legal actions currently pending against Sunoco or its affiliates and events and conditions associated with any assets retained by Sunoco or its affiliates.

Management of the Partnership does not believe that any liabilities which may arise from claims indemnified by Sunoco would be material in relation to the financial position of the Partnership at June 30, 2008. There are certain other pending legal proceedings related to matters arising after the February 2002 IPO that are not indemnified by Sunoco. Management believes that any liabilities that may arise from these legal proceedings will not be material in relation to the financial position of the Partnership at June 30, 2008.

Sunoco Partners Marketing & Terminals L.P. (“SPMT”), which is wholly owned by the Partnership, has received a proposed penalty assessment from the Internal Revenue Service (“IRS”) in the aggregate amount of $5.1 million based on a failure to timely file excise tax information returns relating to its terminal operations during the calendar years 2004 and 2005. SPMT became current on its information return filings with the IRS in July of 2006. SPMT believes it had reasonable cause for the failure to not file the information returns on a timely basis, and provided this information to the IRS on October 19, 2007 in a formal filing. SPMT is currently awaiting a response from the IRS. The proposed penalties are for the failure to file information returns rather than any failure to pay taxes due, as no taxes were owed by SPMT in connection with such information. The timing or outcome of this claim, and the total costs to be incurred by SPMT in connection therewith, cannot be reasonably estimated at this time.

9.	Fair Value Measurements

Effective January 1, 2008, the Partnership adopted the provisions of Statement of Financial Accounting Standards No. 157, “Fair Value Measurements” (“SFAS No. 157”) which pertain to certain balance sheet items measured at fair value on a recurring basis. SFAS No. 157 defines fair value, establishes a framework for measuring fair value and expands disclosures about such measurements that are permitted or required under other accounting pronouncements. While SFAS No. 157 may change the method of calculating fair value, it does not require any new fair value measurements.

In accordance with SFAS No. 157, the Partnership determines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As required, the Partnership utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy established by SFAS No. 157. The Partnership generally applies the “market approach” to determine fair value. This method uses pricing and other information generated by market transactions for identical or comparable assets and liabilities. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety. The Partnership’s financial instruments recorded at fair value were not material at June 30, 2008. The Partnership is currently evaluating the impact on its financial statements of the remaining provisions of SFAS No. 157, which must be adopted by January 1, 2009.

In addition, in February 2007, Statement of Financial Accounting Standards No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS No. 159”) was issued and became effective January 1, 2008. SFAS No. 159 permits entities to choose to measure many financial instruments and certain other eligible items at fair value that were not previously required to be measured at fair value, with unrealized gains and losses on such items reported in earnings. The Partnership did not adopt the use of fair value measurements for any new items as of the January 1, 2008 effective date of this new standard.

10.

Management Incentive Plan

Sunoco Partners LLC, the general partner of the Partnership, participates in the Sunoco Partners LLC Long-Term Incentive Plan (“LTIP”) for employees and directors of the general partner who perform services for the Partnership. The LTIP is administered by the independent directors of the Compensation Committee of the general partner’s board of directors with respect to employee awards, and by the non-independent members of the general partners’ board of directors with respect to awards granted to the independent members. The LTIP currently permits the grant of restricted units and unit options covering an aggregate of 1,250,000 common units. There have been no grants of unit options since the inception of the LTIP. Restricted unit awards may also include tandem distribution equivalent rights (“DER’s”) at the discretion of the Compensation Committee.

The Partnership issued 71,205 and 50,410 common units under the LTIP for the six month periods ended June 30, 2008 and 2007, respectively, and recognized share-based compensation expense of $3.4 million in both of the six month periods ended June 30, 2008 and 2007. Each of the restricted unit grants also have tandem DER’s which are recognized as a reduction of Partners’ Capital when earned.

11.

Cash Distributions

Within 45 days after the end of each quarter, the Partnership distributes all cash on hand at the end of the quarter, less reserves established by the general partner in its discretion. This is defined as “available cash” in the partnership agreement. The general partner has broad discretion to establish cash reserves that it determines are necessary or appropriate to properly conduct the Partnership’s business. The Partnership will make quarterly distributions to the extent there is sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner.

The Partnership issued 11,383,639 subordinated units to its general partner in connection with the initial public offering in February 2002. These subordinated units were convertible to common units on a one-for-one basis provided the Partnership met applicable financial tests set forth in the partnership agreement. The Partnership met the minimum quarterly distribution requirements on all outstanding units for each of the four-quarter periods ended December 31, 2005 and 2006. As a result, subordinated units converted to common units in February 2005 and 2006 with the balance converting in February, 2007.

If cash distributions exceed $0.50 per unit in a quarter, the general partner will receive increasing percentages, up to 50 percent, of the cash distributed in excess of $0.70 per unit. These distributions are referred to as “incentive distributions”.

Distributions paid by the Partnership for the period from January 1, 2007 through June 30, 2008 were as follows:


Date Cash Distribution Paid	Cash Distribution per Limited Partner Unit		Total Cash Distribution to Limited Partners		Total Cash Distribution to the General Partner
			($ in millions)		($ in millions)
February 14, 2007	$	0.8125	$	23.2	$	5.1
May 15, 2007	$	0.8250	$	23.6	$	5.4
August 14, 2007	$	0.8375	$	23.9	$	5.8
November 14, 2007	$	0.8575	$	24.3	$	6.1
February 14, 2008	$	0.8700	$	24.9	$	6.7
May 15, 2008	$	0.8950	$	25.6	$	7.5

On July 22, 2008, Sunoco Partners LLC, the general partner of Sunoco Logistics Partners L.P., declared a cash distribution of $0.9350 per common partnership unit ($3.74 annualized), representing the distribution for the second quarter 2008. The $35.4 million distribution, including $8.6 million to the general partner, will be paid on August 14, 2008 to unitholders of record at the close of business on August 7, 2008.

12.

Business Segment Information

The following table sets forth condensed statement of income information concerning the Partnership’s business segments and reconciles total segment operating income to net income for the three months ended June 30, 2008 and 2007, respectively (in thousands of dollars):


	Three Months Ended June 30,
	2008		2007
Segment Operating Income
Eastern Pipeline System:
Sales and other operating revenue:
Affiliates	$	20,875	$	19,455
Unaffiliated customers		8,076		8,461
Other income		2,971		3,796

Total Revenues		31,922		31,712

Operating expenses		10,034		13,627
Depreciation and amortization		2,465		2,249
Selling, general and administrative expenses		4,866		5,021

Total Costs and Expenses		17,365		20,897

Operating Income	$	14,557	$	10,815

Terminal Facilities:
Sales and other operating revenue:
Affiliates	$	24,966	$	23,038
Unaffiliated customers		14,306		12,241
Other income		825		—

Total Revenues		40,097		35,279

Operating expenses		13,913		12,797
Depreciation and amortization		4,056		3,815
Selling, general and administrative expenses		4,218		3,139

Total Costs and Expenses		22,187		19,751

Operating Income	$	17,910	$	15,528

Western Pipeline System:
Sales and other operating revenue:
Affiliates	$	710,877	$	348,870
Unaffiliated customers		2,536,321		1,218,208
Other income		4,987		3,909

Total Revenues		3,252,185		1,570,987

Cost of products sold and operating expenses		3,216,914		1,553,906
Depreciation and amortization		3,309		3,343
Selling, general and administrative expenses		5,042		5,327

Total Costs and Expenses		3,225,265		1,562,576

Operating Income	$	26,920	$	8,411

Reconciliation of Segment Operating Income to Net Income:
Operating Income:
Eastern Pipeline System	$	14,557	$	10,815
Terminal Facilities		17,910		15,528
Western Pipeline System		26,920		8,411

Total segment operating income		59,387		34,754
Net interest expense		8,064		9,500

Net Income	$	51,323	$	25,254

The following table sets forth condensed statement of income information concerning the Partnership’s business segments and reconciles total segment operating income to net income for the six months ended June 30, 2008 and 2007, respectively (in thousands of dollars):


	Six Months Ended June 30,
	2008		2007
Segment Operating Income
Eastern Pipeline System:
Sales and other operating revenue:
Affiliates	$	41,114	$	38,299
Unaffiliated customers		16,729		16,591
Other income		4,250		6,332

Total Revenues		62,093		61,222

Operating expenses		21,985		25,583
Depreciation and amortization		4,879		4,556
Selling, general and administrative expenses		9,936		10,580

Total Costs and Expenses		36,800		40,719

Operating Income	$	25,293	$	20,503

Terminal Facilities:
Sales and other operating revenue:
Affiliates	$	49,676	$	44,474
Unaffiliated customers		28,980		23,685
Other income		825		—

Total Revenues		79,481		68,159

Operating expenses		27,601		25,278
Depreciation and amortization		7,993		7,490
Selling, general and administrative expenses		9,093		7,608
Impairment charge		5,674		—

Total Costs and Expenses		50,361		40,376

Operating Income	$	29,120	$	27,783

Western Pipeline System:
Sales and other operating revenue:
Affiliates	$	1,302,314	$	760,651
Unaffiliated customers		4,270,997		2,296,135
Other income		8,534		6,420

Total Revenues		5,581,845		3,063,206

Cost of products sold and operating expenses		5,514,525		3,028,727
Depreciation and amortization		6,617		6,265
Selling, general and administrative expenses		10,528		10,818

Total Costs and Expenses		5,531,670		3,045,810

Operating Income	$	50,175	$	17,396

Reconciliation of Segment Operating Income to Net Income:
Operating Income:
Eastern Pipeline System	$	25,293	$	20,503
Terminal Facilities		29,120		27,783
Western Pipeline System		50,175		17,396

Total segment operating income		104,588		65,682
Net interest expense		15,762		18,121

Net Income	$	88,826	$	47,561

The following table provides the identifiable assets for each segment as of June 30, 2008 and December 31, 2007 (in thousands):


	June 30, 2008		December 31, 2007
Eastern Pipeline System	$	378,820	$	370,278
Terminal Facilities		417,187		400,509
Western Pipeline System		2,720,731		1,710,093
Corporate and other		33,590		23,762

Total identifiable assets	$	3,550,328	$	2,504,642

Corporate and other assets consist primarily of cash and cash equivalents, advances to affiliates and deferred charges.

13.

Supplemental Condensed Consolidating Financial Information

The Partnership and the operating partnerships of the Operating Partnership served as joint and several guarantors of the Senior Notes and of any obligations under the previous credit facility. The Partnership continues to serve as guarantor of the Senior Notes and of any obligations under the new credit facilities. These guarantees are full and unconditional. In connection with the Partnership’s $400 million Credit Facility, the Subsidiary Guarantors were released from their obligations both under the previous credit facility, and the 7.25 percent and 6.125 percent Senior Notes in August 2007. Given that certain, but not all subsidiaries of the Partnership were guarantors, the Partnership was required to present the following supplemental condensed consolidating financial information. For purposes of the following footnote, Sunoco Logistics Partners, L.P. is referred to as “Parent” and Sunoco Logistics Partners Operations L.P. is referred to as “Subsidiary Issuer.” In the 2008 schedules and 2007 balance sheet schedule, Sunoco Partners Marketing and Terminals L.P., Sunoco Pipeline L.P., Sun Pipeline Company of Delaware LLC, Sunoco Pipeline Acquisition LLC, Sunoco Logistics Partners GP LLC, Sunoco Logistics Partners Operations GP LLC and Sunoco Partners Lease Acquisition & Marketing LLC, are collectively referred to as “Non-Guarantor Subsidiaries.” In the 2007 schedules of income and cash flows, Sunoco Partners Marketing and Terminals L.P., Sunoco Pipeline L.P., Sun Pipeline Company of Delaware LLC and Sunoco Pipeline Acquisition LLC are collectively referred to as the “Subsidiary Guarantors”, and Sunoco Logistics Partners GP LLC, Sunoco Logistics Partners Operations GP LLC and Sunoco Partners Lease Acquisition & Marketing LLC, are referred to as “Non-Guarantor Subsidiaries.”

The following supplemental condensed consolidating financial information (in thousands) reflects the Parent’s separate accounts, the Subsidiary Issuer’s separate accounts, the combined accounts of the Subsidiary Guarantors, the combined accounts of the Non-Guarantor Subsidiaries, the combined consolidating adjustments and eliminations and the Parent’s consolidated accounts for the dates and periods indicated. For purposes of the following condensed consolidating information, the Parent’s investments in its subsidiaries and the Subsidiary Issuer’s investments in its subsidiaries are accounted for under the equity method of accounting.

Condensed Consolidating Statement of Income

Three Months Ended June 30, 2008

(unaudited)


	Parent		Subsidiary Issuer			Non- Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	756,718	$	—		$	756,718
Unaffiliated customers		—		—			2,558,703		—			2,558,703
Equity in earnings of subsidiaries		51,321		58,560			6		(109,887	)		—
Other income		—		—			8,783		—			8,783

Total Revenues		51,321		58,560			3,324,210		(109,887	)		3,324,204

Costs and Expenses
Cost of products sold and operating expenses		—		—			3,240,861		—			3,240,861
Depreciation and amortization		—		—			9,830		—			9,830
Selling, general and administrative expenses		—		—			14,126		—			14,126

Total Costs and Expenses		—		—			3,264,817		—			3,264,817

Operating Income		51,321		58,560			59,393		(109,887	)		59,387
Net interest cost paid to (received from) affiliates		—		(302	)		825		—			523
Other interest cost and debt expenses, net		—		8,405			—		—			8,405
Capitalized interest		—		(864	)		—		—			(864	)

Net Income (Loss)	$	51,321	$	51,321		$	58,568	$	(109,887	)	$	51,323

Condensed Consolidating Statement of Income

Three Months Ended June 30, 2007

(unaudited)


	Parent		Subsidiary Issuer			Subsidiary Guarantors		Non- Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	391,370	$	—		$	—		$	391,370
Unaffiliated customers		—		—			1,238,910		—			—			1,238,910
Equity in earnings of subsidiaries		25,257		33,932			—		3			(59,192	)		—
Other income		—		—			7,698		—			—			7,698

Total Revenues		25,257		33,932			1,637,978		3			(59,192	)		1,637,978

Costs and Expenses
Cost of products sold and operating expenses		—		—			1,580,324		6			—			1,580,330
Depreciation and amortization		—		—			9,407		—			—			9,407
Selling, general and administrative expenses		—		—			13,487		—			—			13,487

Total Costs and Expenses		—		—			1,603,218		6			—			1,603,224

Operating Income		25,257		33,932			34,760		(3	)		(59,192	)		34,754
Net interest cost paid to affiliates		—		234			825		—			—			1,059
Other interest cost and debt expenses, net		—		9,386			—		—			—			9,386
Capitalized interest		—		(945	)		—		—			—			(945	)

Net Income (Loss)	$	25,257	$	25,257		$	33,935	$	(3	)	$	(59,192	)	$	25,254

Condensed Consolidating Statement of Income

Six Months Ended June 30, 2008

(unaudited)


	Parent		Subsidiary Issuer			Non- Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	1,393,104	$	—		$	1,393,104
Unaffiliated customers		—		—			4,316,706		—			4,316,706
Equity in earnings of subsidiaries		88,825		102,937			10		(191,772	)		—
Other income		—		—			13,609		—			13,609

Total Revenues		88,825		102,937			5,723,429		(191,772	)		5,723,419

Costs and Expenses
Cost of products sold and operating expenses		—		—			5,564,111		—			5,564,111
Depreciation and amortization		—		—			19,489		—			19,489
Selling, general and administrative expenses		—		—			29,557		—			29,557
Impairment charge		—		—			5,674		—			5,674

Total Costs and Expenses		—		—			5,618,831		—			5,618,831

Operating Income		88,825		102,937			104,598		(191,772	)		104,588
Net interest cost paid to / (received from) affiliates		—		(1,233	)		1,650		—			417
Other interest cost and debt expenses, net		—		16,981			—		—			16,981
Capitalized interest		—		(1,636	)		—		—			(1,636	)

Net Income	$	88,825	$	88,825		$	102,948	$	(191,772	)	$	88,826

Condensed Consolidating Statement of Income

Six Months Ended June 30, 2007

(unaudited)


	Parent		Subsidiary Issuer			Subsidiary Guarantors		Non- Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	843,439	$	—	$	—		$	843,439
Unaffiliated customers		—		—			2,336,411		—		—			2,336,411
Equity in earnings of subsidiaries		47,561		64,032			—		6		(111,599	)		—
Other income		—		—			12,737		—		—			12,737

Total Revenues		47,561		64,032			3,192,587		6		(111,599	)		3,192,587

Costs and Expenses
Cost of products sold and operating expenses		—		—			3,079,582		6		—			3,079,588
Depreciation and amortization		—		—			18,311		—		—			18,311
Selling, general and administrative expenses		—		—			29,006		—		—			29,006

Total Costs and Expenses		—		—			3,126,899		6		—			3,126,905

Operating Income		47,561		64,032			65,688		—		(111,599	)		65,682
Net interest cost paid to / (received from) affiliates		—		(56	)		1,650		—		—			1,594
Other interest cost and debt expenses, net		—		18,025			—		—		—			18,025
Capitalized interest		—		(1,498	)		—		—		—			(1,498	)

Net Income	$	47,561	$	47,561		$	64,038	$	—	$	(111,599	)	$	47,561

Condensed Consolidating Balance Sheet

June 30, 2008

(unaudited)


	Parent		Subsidiary Issuer		Non- Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2,000	$	—		$	—		$	2,000
Advances to affiliates		21,617		48,000		(55,383	)		—			14,234
Accounts receivable, affiliated companies		—		—		279,072			—			279,072
Accounts receivable, net		—		—		1,977,472			—			1,977,472
Inventories
Crude oil		—		—		37,647			—			37,647
Refined product		—		—		424			—			424
Materials, supplies and other		—		—		842			—			842

Total Current Assets		21,617		50,000		2,240,074			—			2,311,691

Properties, plants and equipment, net		—		—		1,116,920			—			1,116,920
Investment in affiliates		505,151		1,005,772		660,933			(2,086,233	)		85,623
Deferred charges and other assets		—		2,971		33,123			—			36,094

Total Assets	$	526,768	$	1,058,743	$	4,051,050		$	(2,086,233	)	$	3,550,328

Liabilities and Partners’ Capital Current Liabilities
Accounts payable	$	—	$	—	$	2,294,493		$	—		$	2,294,493
Accrued liabilities		981		2,555		44,577			—			48,113
Accrued taxes other than income taxes		—		—		46,807			—			46,807

Total Current Liabilities		981		2,555		2,385,877			—			2,389,413

Long-term debt		—		514,201		—			—			514,201
Other deferred credits and liabilities		—		—		28,683			—			28,683

Total Liabilities		981		516,756		2,414,560			—			2,932,297

Total Partners’ Capital		525,787		541,987		1,636,490			(2,086,233	)		618,031

Total Liabilities and Partners’ Capital	$	526,768	$	1,058,743	$	4,051,050		$	(2,086,233	)	$	3,550,328

Condensed Consolidating Balance Sheet

December 31, 2007


	Parent		Subsidiary Issuer		Non- Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2,000	$	—		$	—		$	2,000
Advances to affiliates		4,348		46,000		(42,288	)		—			8,060
Accounts receivable, affiliated companies		—		—		62,167			—			62,167
Accounts receivable, net		—		—		1,200,782			—			1,200,782
Inventories
Crude oil		—		—		29,145			—			29,145
Refined product additives		—		—		682			—			682
Materials, supplies and other		—		—		842			—			842

Total Current Assets		4,348		48,000		1,251,330			—			1,303,678

Properties, plants and equipment, net		—		—		1,089,262			—			1,089,262
Investment in affiliates		584,060		1,101,139		85,084			(1,685,298	)		84,985
Deferred charges and other assets		—		3,278		23,439			—			26,717

Total Assets	$	588,408	$	1,152,417	$	2,449,115		$	(1,685,298	)	$	2,504,642

Liabilities and Partners’ Capital Current Liabilities
Accounts payable	$	—	$	—	$	1,289,402		$	—		$	1,289,402
Accrued liabilities		980		3,863		40,316			—			45,159
Accrued taxes other than income taxes		—		—		34,277			—			34,277

Total Current Liabilities		980		3,863		1,363,995			—			1,368,838

Long-term debt		—		515,104		—			—			515,104
Other deferred credits and liabilities		—		—		29,655			—			29,655

Total Liabilities		980		518,967		1,393,650			—			1,913,597

Total Partners’ Capital		587,428		633,450		1,055,465			(1,685,298	)		591,045

Total Liabilities and Partners’ Capital	$	588,408	$	1,152,417	$	2,449,115		$	(1,685,298	)	$	2,504,642

Condensed Consolidating Statement of Cash Flows

Six Months Ended June 30, 2008

(unaudited)


	Parent			Subsidiary Issuer			Non- Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	88,826		$	87,749		$	149,373		$	(191,772	)	$	134,176

Cash Flows from Investing Activities:
Capital expenditures		—			—			(52,495	)		—			(52,495	)
MagTex Acquisition		—			—			(10,462	)		—			(10,462	)
Intercompany		(6,939	)		(84,749	)		(100,084	)		191,772			—

		(6,939	)		(84,749	)		(163,041	)		191,772			(62,957	)

Cash Flows from Financing Activities:
Distribution paid to Limited Partners and General Partner		(64,694	)		—			—			—			(64,694	)
Payments of statutory withholding on net issuance of Limited Partner units under restricted unit incentive plan		—			—			(1,278	)		—			(1,278	)
Contribution from General Partner for Limited Partner unit transactions		76			—			—			—			76
Advances to affiliates, net		(17,269	)		(2,000	)		13,095			—			(6,174	)
Borrowings under credit facility		—			85,000			—			—			85,000
Repayments under credit facility		—			(86,000	)		—			—			(86,000	)
Contributions from affiliate		—			—			1,851			—			1,851

		(81,887	)		(3,000	)		13,668			—			(71,219	)

Net change in cash and cash equivalents		—			—			—			—			—
Cash and cash equivalents at beginning of year		—			2,000			—			—			2,000

Cash and cash equivalents at end of year	$	—		$	2,000		$	—		$	—		$	2,000

Condensed Consolidating Statement of Cash Flows

Six Months Ended June 30, 2007

(unaudited)


	Parent			Subsidiary Issuer			Subsidiary Guarantors			Non- Guarantor Subsidiaries		Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	47,514		$	46,293		$	71,144		$	—	$	(111,599	)	$	53,352

Cash Flows from Investing Activities:
Capital expenditures		—			—			(50,642	)		—		—			(50,642	)
Acquisitions		—			—			(13,173	)		—		—			(13,173	)
Intercompany		2,726			(109,054	)		(5,271	)		—		111,599			—

		2,726			(109,054	)		(69,086	)				111,599			(63,815	)

Cash Flows from Financing Activities:
Distribution paid to Limited Partners and General Partner		(57,271	)		—			—			—		—			(57,271	)
Payments of statutory withholding on net issuance of Limited Partner units under restricted unit incentive plan		—			—			(1,479	)		—		—			(1,479	)
Contribution from General Partner for Limited Partner unit transactions		58			—			—			—		—			58
Repayments from (advances to) affiliates, net		6,973			(9,516	)		(1,331	)		—		—			(3,874	)
Borrowings under credit facility		—			91,900			—			—		—			91,900
Repayments under credit facility		—			(20,000	)		—			—		—			(20,000	)
Contributions from (distributions to) affiliate		—			—			752			—		—			752

		(50,240	)		62,384			(2,058	)		—		—			10,086

Net change in cash and cash equivalents		—			(377	)		—			—		—			(377	)
Cash and cash equivalents at beginning of year		—			9,412			—			—		—			9,412

Cash and cash equivalents at end of period	$	—		$	9,035		$	—		$	—	$	—		$	9,035

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Results of Operations – Three Months Ended June 30, 2008 and 2007

Sunoco Logistics Partners L.P.

Operating Highlights

Three Months Ended June 30, 2008 and 2007


	Three Months Ended June 30,
	2008	2007
Eastern Pipeline System:⁽¹⁾
Total shipments (barrel miles per day)⁽²⁾	61,028,163	63,253,888
Revenue per barrel mile (cents)	0.521	0.485
Terminal Facilities:
Terminal throughput (bpd):
Refined product terminals⁽³⁾	428,704	440,152
Nederland terminal	526,350	529,462
Refinery terminals⁽⁴⁾	622,011	715,462
Western Pipeline System:⁽¹⁾
Crude oil pipeline throughput (bpd)	547,489	535,715
Crude oil purchases at wellhead (bpd)	177,317	180,390
Gross margin per barrel of pipeline throughput (cents)⁽⁵⁾	54.1	20.2

⁽¹⁾	Excludes amounts attributable to equity ownership interests in corporate joint ventures.

⁽²⁾	Represents total average daily pipeline throughput multiplied by the number of miles of pipeline through which each barrel has been shipped.

⁽³⁾	Includes results from the Partnership’s purchase of a 50% undivided interest in a refined products terminal in Syracuse, New York in June 2007.

⁽⁴⁾	Consists of the Partnership’s Fort Mifflin Terminal Complex, the Marcus Hook Tank Farm and the Eagle Point Dock.

⁽⁵⁾	Represents total segment sales minus cost of products sold and operating expenses and depreciation and amortization divided by crude oil pipeline throughput.

Analysis of Consolidated Net Income

Net income was $51.3 million for the second quarter 2008 as compared with $25.3 million for the second quarter 2007, an increase of $26.0 million. The increase was the result of continued margin improvement across all segments, stronger asset utilization in the Western Pipeline system and additional tankage placed into service at the Nederland terminal during 2007 and 2008. These increases were partially offset by lower volumes in our Eastern Pipeline and Terminal systems.

Net interest expense decreased $1.4 million to $8.1 million for the second quarter 2008 from $9.5 million for the prior year’s quarter primarily due to lower interest rates related to the Partnership’s revolving Credit Facility.

Analysis of Segment Operating Income

Eastern Pipeline System

Operating income for the Eastern Pipeline System increased $3.8 million to $14.6 million for the second quarter 2008 from $10.8 million for the second quarter 2007. Sales and other operating revenue increased by $1.0 million to $29.0 million due primarily to higher fees across the Partnership’s refined product and crude oil pipelines, partially offset by decreased volumes. Other income decreased $0.8 million compared to the prior year’s quarter due primarily to a decrease in equity income associated with the Partnership’s joint venture interests. Cost of goods sold and operating expenses decreased by $3.6 million to $10.0 million compared to the prior year’s quarter due primarily to the impact of increased crude oil and refined product prices on operating gains and a decreased level of environmental charges. These decreases were partially offset by increased utility costs throughout the system.

Terminal Facilities

The Terminal Facilities business segment had operating income of $17.9 million for the second quarter 2008, as compared to $15.5 million for the prior year’s second quarter. Sales and other operating revenue increased by $4.0 million to $39.3 million due primarily to the addition of tankage at the Nederland terminal, increased terminal fees, sales of product overages which were favorably impacted by the increased price of crude oil and increased product additive revenues. Other income increased $0.8 million from the prior year’s second quarter as a result of the final insurance recovery for hurricane damage sustained during 2005 at the Partnership’s Nederland terminal. Cost of goods sold and operating expenses increased by $1.1 million to $13.9 million for the second quarter of 2008 due primarily to increased product additive costs, higher utility costs and timing of maintenance activity. Selling, general and administrative expenses increased by $1.1 million to $4.2 million for the second quarter of 2008. During 2007, expenses were reduced by $0.9 million in connection with an insurance recovery.

Western Pipeline System

Operating income for the Western Pipeline System increased $18.5 million to $26.9 million for the second quarter of 2008 compared to the prior year’s quarter due primarily to improved asset utilization resulting from the creation of a bi-directional pipeline connection to the Partnership’s Nederland terminal, increased pipeline volumes and fees and higher lease acquisition margins. Additionally, the Partnership benefited in the second quarter of 2008 from third party contracts, to purchase and sell crude oil inventory, that were entered into in conjunction with a contract to exchange crude oil inventory with the Department of Energy (“DOE”). In accordance with accounting standards, these third party contracts were deemed to be derivatives, which required a mark to market adjustment to be recorded in income during the second quarter of 2008. The accounting for the third party contracts, along with the exchange contract with the DOE, resulted in $3.2 million in income being recognized during the second quarter 2008. These contracts will be settled during the third quarter of 2008. Other income increased $1.1 million compared to the prior year’s quarter due primarily to a gain recognized on the insurance recovery discussed earlier.

Higher crude oil prices were a key driver of the overall increase in total revenue, cost of products sold and operating expenses from the prior year’s quarter. The average price of West Texas Intermediate crude oil at Cushing, Oklahoma increased to $124.00 per barrel for the second quarter of 2008 from $65.02 per barrel for the second quarter of 2007.

Results of Operations – Six Months Ended June 30, 2008 and 2007

Sunoco Logistics Partners L.P.

Operating Highlights

Six Months Ended June 30, 2008 and 2007


	Six Months Ended June 30,
	2008	2007
Eastern Pipeline System:⁽¹⁾
Total shipments (barrel miles per day)⁽²⁾	60,705,947	63,372,001
Revenue per barrel mile (cents)	0.524	0.479
Terminal Facilities:
Terminal throughput (bpd):
Refined product terminals⁽³⁾	423,662	427,923
Nederland terminal	539,702	536,840
Refinery terminals⁽⁴⁾	648,604	664,768
Western Pipeline System:⁽¹⁾
Crude oil pipeline throughput (bpd)	548,957	534,816
Crude oil purchases at wellhead (bpd)	174,381	182,757
Gross margin per barrel of pipeline throughput (cents)⁽⁵⁾	52.3	22.5

⁽¹⁾	Excludes amounts attributable to equity ownership interests in corporate joint ventures.

⁽²⁾	Represents total average daily pipeline throughput multiplied by the number of miles of pipeline through which each barrel has been shipped.

⁽³⁾	Includes results from the Partnership’s purchase of a 50% undivided interest in a refined products terminal in Syracuse, New York.

⁽⁴⁾	Consists of the Partnership’s Fort Mifflin Terminal Complex, the Marcus Hook Tank Farm and the Eagle Point Dock.

⁽⁵⁾	Represents total segment sales and other operating revenue minus cost of products sold and operating expenses and depreciation and amortization divided by crude oil pipeline throughput.

Analysis of Consolidated Net Income

Net income was $88.8 million for the six month period ended June 2008 as compared with $47.6 million for the comparable period in 2007. The increase was driven primarily by higher operating income resulting from higher margins and fees across all segments, improved asset utilization within the Western Pipeline system and additional tankage placed into service at the Nederland terminal during 2007 and 2008. These improvements to operating income were partially offset by lower volumes in the Eastern Pipeline system and Terminal Facilities along with a $5.7 million non-cash impairment charge related to a cancelled project. A decrease in interest expense further contributed to the $41.2 million increase in net income.

Net interest expense decreased $2.4 million to $15.8 million for the first six months of 2008 from $18.1 million for the first six months of 2007 due to decreased borrowings and lower interest rates related to the Partnership’s revolving Credit Facility.

Analysis of Segment Operating Income

Eastern Pipeline System

Operating income for the Eastern Pipeline System increased $4.8 million to $25.3 million for the first six months of 2008 from $20.5 million for the first six months of 2007. Sales and other operating revenue increased from $54.9 million for the prior year’s period to $57.8 million for the six months ended June 2008 due mainly to higher fees across the Partnership’s refined product and crude oil pipelines, partially offset by decreased volumes. Other income decreased by $2.1 million to $4.2 million for the first six months of 2008 from $6.3 million for the prior year period due primarily to a decrease in equity income associated with the Partnership’s joint venture interests. Operating expenses decreased by $3.6 million to $22.0 million due primarily to the impact of increased crude oil and refined product prices on operating gains and a decreased level of environmental charges. This decrease was partially offset by increased utility costs throughout the system.

Terminal Facilities

The Terminal Facilities segment had operating income of $29.1 million for the six months ended June 2008, as compared to $27.8 million for the first six months of 2007. Operating income was reduced during the first six months of 2008 due to a $5.7 million non-cash impairment charge related to the Partnership’s decision to discontinue efforts to expand LPG storage capacity at its Inkster, Michigan facility. Sales and other operating revenue increased $10.5 million to $78.7 million in the first half of 2008 due primarily to the addition of new tankage at the Nederland terminal, higher fees at the Partnership’s Nederland and refined products terminals, the sale of product overages which were favorably impacted by the increased price of crude oil and increased product additive revenues. The increases were partially offset by decreased volumes in the Partnership’s refinery and refined product terminals. Other income increased $0.8 million from the first six months of 2008 as a result of the insurance recovery discussed above. Cost of goods sold and operating expenses increased by $2.3 million to $27.6 million for the six months ended June 2008 due primarily to increased utility costs and timing of maintenance activity. Selling, general and administrative expenses increased by $1.5 million to $9.1 million for the six months ended June 30, 2008. During 2007, expenses were reduced by $0.9 million in connection with an insurance recovery.

Western Pipeline System

Operating income for the Western Pipeline System increased $32.8 million to $50.2 million for the first six months of 2008 from $17.4 million for the first six months of 2007. The increase was due primarily to improved asset utilization resulting from creation of a bi-directional pipeline connection to the Partnership’s Nederland terminal, increased pipeline volumes and fees and higher lease acquisition margins. Additionally, the Partnership benefited in the first six months of 2008 from third party contracts, to purchase and sell crude oil inventory, that were entered into in conjunction with a contract to exchange crude oil inventory with the Department of Energy (“DOE”). In accordance with accounting standards, these third party contracts were deemed to be derivatives, which required a mark to market adjustment to be recorded in income during the second quarter of 2008. The accounting for the third party contracts, along with the exchange contract with the DOE, resulted in $5.1 million in income being recognized for the first six months of 2008. These contracts will be settled during the third quarter of 2008. Other income also contributed to the increased profitability due to increased equity income associated with the Partnership’s joint venture interests and the gain on an insurance recovery discussed above.

Higher crude oil prices were a key driver of the overall increase in total revenue, cost of products sold and operating expenses from the prior year period. The average price of West Texas Intermediate crude oil at Cushing, Oklahoma increased to $110.98 per barrel for the first six months of 2008 from $61.64 per barrel for the first six months of 2007.

Liquidity and Capital Resources

Liquidity

Cash generated from operations and borrowings under the credit facilities are the Partnership’s primary sources of liquidity. At June 30, 2008, the Partnership had available borrowing capacity under the credit facilities of $410.0 million. The Partnership’s working capital position reflects crude oil inventories based on historical costs under the LIFO method of accounting. If the inventories had been valued at their current replacement cost, the Partnership would have had working capital of $181.2 million at June 30, 2008.

On April 28, 2008, Sunoco Pipeline L.P., a subsidiary of the Partnership, entered into a definitive agreement to acquire a refined products pipeline system and certain other real and personal property interests and assets from Mobil Pipe Line Company. In addition to the pipeline system, Sunoco Partners Marketing & Terminals L.P., a subsidiary of the Partnership, entered into definitive agreements with Exxon Mobil Corporation, Mobil Pipe Line Company and ExxonMobil Oil Corporation, to acquire six refined products terminal facilities. Subject to necessary regulatory filings and approvals and the satisfaction of certain closing conditions, the transactions, with a combined purchase price of approximately $200.0 million, are expected to be completed in the third quarter of 2008. These acquisitions are expected to be funded through a combination of cash on hand and the Partnership’s revolving credit facilities and other borrowings. For further information on these transactions see “Item 1. Notes to Condensed Consolidated Financial Statements (unaudited)—Note 2.”

Capital Resources

The Partnership periodically supplements its cash flows from operations with proceeds from debt and equity financing activities.

$400 Million Credit Facility

Sunoco Logistics Partners Operations L.P. (the “Operating Partnership”), a wholly-owned entity of the Partnership, has a five-year $400 million Credit Facility, which is available to fund the Operating Partnership’s working capital requirements, to finance future acquisitions, to finance future capital projects and for general partnership purposes. The Credit Facility matures in November 2012. At December 31, 2007, there was $91.0 million outstanding under the credit facility. During the first six months of 2008, the Partnership had net repayments of $1.0 million resulting in an outstanding balance of $90.0 million at June 30, 2008.

The Credit Facility bears interest at the Operating Partnership’s option, at either (i) LIBOR plus an applicable margin, (ii) the higher of the federal funds rate plus 0.50 percent or the Citibank prime rate (each plus the applicable margin) or (iii) the federal funds rate plus an applicable margin.

The Credit Facility contains various covenants limiting the Operating Partnership’s ability to a) incur indebtedness, b) grant certain liens, c) make certain loans, acquisitions and investments, d) make any material change to the nature of its business, e) acquire another company, or f) enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership’s subsidiaries. The Credit Facility also requires the Operating Partnership to maintain, on a rolling four-quarter basis, a maximum total debt to EBITDA ratio of 4.75 to 1, which can generally be increased to 5.25 to 1 during an acquisition period. The Operating Partnership is in compliance with this requirement as of June 30, 2008. The Partnership’s ratio of total debt to EBITDA was 2.5 to 1 at June 30, 2008.

$100 Million Credit Facility

In anticipation of the pending MagTex Acquisition, the Operating Partnership entered into a $100 million 364 day revolving credit facility (“$100 million Credit Facility”) on May 28, 2008. This $100 million Credit Facility is available to fund the same activities as the Credit Facility described above. If the MagTex Acquisition is terminated, this new revolver will be terminated. The $100 million Credit Facility matures in May 2009 and can be prepaid at any time. Interest on outstanding borrowings is calculated, at the Operating Partnership’s option, using either (i) LIBOR plus and applicable margin or (ii) the higher of (a) the federal funds rates plus 0.50 percent plus an applicable margin, and (b) the Citibank prime rate plus an applicable margin. The $100 million Credit Facility contains the same covenant requirements as the Credit Facility described above. As of June 30, 2008 there were no borrowings outstanding under the $100 million Credit Facility.

Letters of Credit

Cash Flows and Capital Expenditures

Net cash provided by operating activities for the six months ended June 30, 2008 was $134.2 million compared with $53.4 million of net cash provided by operating activities for the first six months of 2007. Net cash provided by operating activities for the first six months of 2008 was primarily the result of net income of $88.8 million, depreciation and amortization of $19.5 million, the $5.7 million impairment charge, and an $18.7 million decrease in working capital. The decrease in working capital was the result of an increase in both accounts payable and accounts receivable activity driven primarily by commodity prices. Net cash provided by operating activities for the first six months of 2007 was primarily the result of net income of $47.5 million and depreciation and amortization of $18.3 million, partially offset by a $22.9 million increase in working capital. The increase in working capital was primarily attributable to an increase in revenues along with an increase in inventory volumes associated with contango inventory positions.

Net cash used in investing activities for the first six months of 2008 was $63.0 million compared with $63.8 million for the first six months of 2007.

Net cash used in financing activities for the first six months of 2008 was $71.2 million compared with $10.1 million net cash provided by financing activities for the first six months of 2007. Net cash used in financing activities for the first six months of 2008 resulted from $64.7 million in distributions paid to limited partners and the general partner and an increase in advances to affiliates of $6.2 million. Net cash provided by financing activities for the first six months of 2007 was the result of $71.9 million increase in net borrowings under the Partnership’s Credit Facility to fund the Partnership’s organic growth capital program, contango inventory positions, and to purchase a 50% undivided interest in a refined products terminal located in Syracuse, New York. This increase was partially offset by $57.3 million in distributions paid to limited partners and the general partner and $3.9 million in net advances to affiliates.

Under a treasury services agreement with Sunoco, the Partnership participates in Sunoco’s centralized cash management program. Advances from affiliates in the Partnership’s condensed consolidated balance sheets at June 30, 2008 represent amounts due to Sunoco under this agreement. Advances to affiliates at December 31, 2007 represent amounts due from Sunoco under this agreement.

Capital Requirements

The pipeline, terminalling, and crude oil transport operations are capital intensive, requiring significant investment to maintain, upgrade or enhance existing operations and to meet environmental and operational regulations. The capital requirements have consisted, and are expected to continue to consist, primarily of:

•

Maintenance capital expenditures, such as those required to maintain equipment reliability, tankage and pipeline integrity and safety, and to address environmental regulations; and

•

Expansion capital expenditures to acquire assets to grow the business and to expand existing and construct new facilities, such as projects that increase storage or throughput volume.

The following table summarizes maintenance and expansion capital expenditures, including net cash paid for acquisitions, for the periods presented (in thousands of dollars):


	Six Months Ended June 30,
	2008		2007
Maintenance	$	7,771	$	7,541
Expansion		44,724		56,274

	$	52,495	$	63,815

Management anticipates maintenance capital expenditures to be approximately $26.0 million for the year ended December 31, 2008, excluding reimbursements from Sunoco in accordance with the terms of certain agreements. Maintenance capital expenditures for both periods presented include recurring expenditures such as pipeline integrity costs, pipeline relocations, repair and upgrade of field instrumentation, including measurement devices, repair and replacement of tank floors and roofs, upgrades of cathodic protection systems, crude trucks and related equipment, and the upgrade of pump stations.

Expansion capital expenditures for the six months ended June 30, 2008 were $44.7 million compared to $56.3 million for the first six months of 2007. The decrease is attributable to the $13.4 million acquisition of a 50 percent interest in the Syracuse, New York refined products terminal in 2007. Expansion capital for 2008 includes construction in progress, in connection with the Partnership’s agreement with Motiva Enterprises LLC, of three crude oil storage tanks at its Nederland Terminal and a crude oil pipeline from Nederland to Motiva’s Port Arthur, Texas refinery. Expansion capital also includes construction of five additional crude oil storage tanks at Nederland, of which two began construction during the second quarter of 2008. These five crude oil storage tanks will have a combined shell capacity of approximately 3.0 million barrels.

The Partnership expects to fund capital expenditures, including pending and future acquisitions, from both cash provided by operations and, to the extent necessary, from the proceeds of borrowings under the Credit Facility, other borrowings and the issuance of additional common units.

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

Interest Rate Risk

Our exposure to interest-rate risk relates primarily to variable-rate borrowings. Variable-rate debt outstanding at June 30, 2008 was $90.0 million and averaged $73.7 million during the second quarter of 2008. The Partnership issues long-term debt either at fixed rates or use interest rate swaps to limit exposure to changes in interest rates on variable-rate, long-term debt. On January 8, 2008, the Partnership entered into an interest rate swap with a notional amount of $50.0 million maturing January 2010. Under the swap agreement, the Partnership receives interest equivalent to the three-month LIBOR and pays a fixed rate of interest of 3.489 percent with settlements occurring quarterly. To maintain hedge accounting for the Swap, the Partnership is committed to maintaining at least $50.0 million in borrowings at an interest rate based on the three-month LIBOR, plus an applicable margin, through January 2010. Additional variable-rate borrowings under the revolving credit facilities will be subject to fluctuations in interest rates.

Commodity Market Risk

The Partnership is exposed to volatility in crude oil commodity prices. To manage such exposures, inventory levels and expectations of future commodity prices are monitored when making decisions with respect to risk management and inventory carried. The Partnership does not hold or issue any derivative instruments for trading purposes. In January 2008, the Partnership commenced an exchange contract with the Department of Energy (“DOE”). Under the terms of this contract, the DOE was required to deliver various grades of crude oil to the Partnership during the period of January 2008 through June 2008. In return, the Partnership agreed to deliver an equivalent amount of crude oil to the DOE during the period of February 2008 through July 2008. In connection with this contract, the Partnership entered into third party contracts to balance the timing of crude oil receipts and purchases. In accordance with accounting standards, these third party contracts were deemed to be derivatives, and therefore a mark to mark adjustment was recorded in income during the second quarter of 2008. The combination of these contracts, along with the exchange contract with the DOE, resulted in $5.1 million of income being recognized as of June 30, 2008. These contracts will be settled during the third quarter of 2008.

Forward-Looking Statements

Some of the information included in this quarterly report on Form 10-Q contains “forward-looking” statements, as such term is defined in Section 27A of the Securities Act of 1933 and Section 21E of the Exchange Act, and information relating to Sunoco Logistics Partners L.P. that is based on the beliefs of its management as well as assumptions made by and information currently available to management.

Forward-looking statements discuss expected future results based on current and pending business operations, and may be identified by words such as “anticipates,” “believes,” “expects,” “planned,” “scheduled” or similar expressions. Although management of the Partnership believes these forward-looking statements are reasonable, they are based upon a number of assumptions, any or all of which may ultimately prove to be inaccurate. Statements made regarding future results are subject to numerous assumptions, uncertainties and risks that may cause future results to be materially different from the results stated or implied in this document.

The following are among the important factors that could cause actual results to differ materially from any results projected, forecasted, estimated or budgeted:

•

Our ability to successfully consummate announced acquisitions or expansions and integrate them into our existing business operations;

•

Delays related to construction of, or work on, new or existing facilities and the issuance of applicable permits;

•

Changes in demand for, or supply of, crude oil, refined petroleum products and natural gas liquids that impact demand for the Partnership’s pipeline, terminalling and storage services;

•

Changes in the demand for crude oil we both buy and sell;

•

The loss of Sunoco R&M as a customer or a significant reduction in its current level of throughput and storage with the Partnership;

•

An increase in the competition encountered by the Partnership’s petroleum products terminals, pipelines and crude oil acquisition and marketing operations;

•

Changes in the financial condition or operating results of joint ventures or other holdings in which the Partnership has an equity ownership interest;

•

Changes in the general economic conditions in the United States;

•

Changes in laws and regulations to which the Partnership is subject, including federal, state, and local tax, safety, environmental and employment laws;

•

Changes in regulations concerning required composition of refined petroleum products that result in changes in throughput volumes, pipeline tariffs and/or terminalling and storage fees;

•

Improvements in energy efficiency and technology resulting in reduced demand for petroleum products;

•

The Partnership’s ability to manage growth and/or control costs;

•

The effect of changes in accounting principles and tax laws and interpretations of both;

•

Global and domestic economic repercussions, including disruptions in the crude oil and petroleum products markets, from terrorist activities, international hostilities and other events, and the government’s response thereto;

•

Changes in the level of operating expenses and hazards related to operating facilities (including equipment malfunction, explosions, fires, spills and the effects of severe weather conditions);

•

The occurrence of operational hazards or unforeseen interruptions for which the Partnership may not be adequately insured;

•

The age of, and changes in the reliability and efficiency of the Partnership’s operating facilities;

•

Changes in the expected level of capital, operating, or remediation spending related to environmental matters;

•

Changes in insurance markets resulting in increased costs and reductions in the level and types of coverage available;

•

Risks related to labor relations and workplace safety;

•

Non-performance by or disputes with major customers, suppliers or other business partners;

•

Changes in the Partnership’s tariff rates implemented by federal and/or state government regulators;

•

The amount of the Partnership’s indebtedness, which could make the Partnership vulnerable to adverse general economic and industry conditions, limit the Partnership’s ability to borrow additional funds, place it at competitive disadvantages compared to competitors that have less debt, or have other adverse consequences;

•

Restrictive covenants in the Partnership’s or Sunoco, Inc.’s credit agreements;

•

Changes in the Partnership’s or Sunoco, Inc.’s credit ratings, as assigned by ratings agencies;

•

The condition of the debt capital markets and equity capital markets in the United States, and the Partnership’s ability to raise capital in a cost-effective way;

•

Changes in interest rates on the Partnership’s outstanding debt, which could increase the costs of borrowing;

•

Claims of the Partnership’s non-compliance with regulatory and statutory requirements; and

•

The costs and effects of legal and administrative claims and proceedings against the Partnership or any entity in which it has an ownership interest, and changes in the status of, or the initiation of new litigation, claims or proceedings, to which the Partnership, or any entity in which it has an ownership interest, is a party.

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of the Partnership’s forward-looking statements. Other factors could also have material adverse effects on future results. The Partnership undertakes no obligation to update publicly any forward-looking statement whether as a result of new information or future events.

Item 4.

Controls and Procedures

(a) Disclosure controls and procedures are designed to ensure that information required to be disclosed in the Partnership reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the rules and forms of the Securities and Exchange Commission. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in the Partnership reports under the Exchange Act is accumulated and communicated to management, including the President and Chief Executive Officer of Sunoco Partners LLC (the Partnership’s general partner) and the Vice President and Chief Financial Officer of the general partner, as appropriate, to allow timely decisions regarding required disclosure.

(b) As of June 30, 2008, the Partnership carried out an evaluation, under the supervision and with the participation of the management of the general partner (including the President and Chief Executive Officer and the Vice President and Chief Financial Officer), of the effectiveness of the design and operation of the Partnership’s disclosure controls and procedures pursuant to Exchange Act Rule 13a-15. Based upon that evaluation, the general partner’s President and Chief Executive Officer, and its Vice President and Chief Financial Officer, concluded that the Partnership’s disclosure controls and procedures are effective.

(c) No change in the Partnership’s internal control over financial reporting has occurred during the fiscal quarter ended June 30, 2008 that has materially affected, or that is reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

PART II

OTHER INFORMATION

Item 1.

Legal Proceedings

There are certain legal and administrative proceedings arising prior to the February 2002 IPO pending against the Partnership’s Sunoco-affiliated predecessors and the Partnership (as successor to certain liabilities of those predecessors). Although the ultimate outcome of these proceedings cannot be ascertained at this time, it is reasonably possible that some of them may be resolved unfavorably. Sunoco has agreed to indemnify the Partnership for 100 percent of all losses from environmental liabilities related to the transferred assets arising prior to, and asserted within 21 years of February 8, 2002. There is no monetary cap on this indemnification from Sunoco. Sunoco’s share of liability for claims asserted thereafter will decrease by 10 percent each year through the thirtieth year following the February 8, 2002 date. Any remediation liabilities not covered by this indemnity will be the Partnership’s responsibility. In addition Sunoco is obligated to indemnify the Partnership under certain other agreements executed after the February 2002 IPO.

There are certain other pending legal proceedings related to matters arising after the February 2002 IPO that are not indemnified by Sunoco. Management believes that any liabilities that may arise from these legal proceedings will not be material to the Partnership’s financial position at June 30, 2008.

Item 1A.

Risk Factors

There have been no material changes from the risk factors described previously in Part I, Item 1A of the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on February 26, 2008.

Item 2.

Unregistered Sales of Equity Securities and Uses of Proceeds

None.

Item 3.

Defaults Upon Senior Securities

None.

Item 4.

Submission of Matters to a Vote of Security Holders

None.

Item 5.

Other Information

None.

Item 6.

Exhibits

Exhibits



2.1		Sale and Purchase Agreement for Magtex Refined Products Pipeline System between Mobil Pipe Line Company and Sunoco Pipeline L.P., executed April 28, 2008

2.1.1		List of Schedules and Exhibits to Sale and Purchase Agreement omitted from this filing. Registrant hereby undertakes, pursuant to Regulation S-K Item 601(2) to furnish any such schedules and exhibits to the SEC supplementally, upon request.

2.2		Terminals Sale and Purchase Agreement for Center, TX, Hearne(East), TX, Waco, TX and Waskom, TX Terminals between ExxonMobil Oil Corporation and Sunoco Partners Marketing & Terminals L.P., executed April 28, 2008

2.2.1		List of Schedules and Exhibits to Terminals and Purchase Agreement omitted from this filing. Registrant hereby undertakes, pursuant to Regulation S-K Item 601(2) to furnish any such schedules and exhibits to the SEC supplementally, upon request.

2.3		Terminals Sale and Purchase Agreement for Arcadia, LA Terminal between Exxon Mobil Corporation and Sunoco Partners Marketing & Terminals L.P., executed April 28, 2008

2.3.1		List of Schedules and Exhibits to Terminals and Purchase Agreement omitted from this filing. Registrant hereby undertakes, pursuant to Regulation S-K Item 601(2) to furnish any such schedules and exhibits to the SEC supplementally, upon request.

2.4		Terminals Sale and Purchase Agreement for Hearne, TX (West) Terminal between Mobil Pipe Line Company and Sunoco Partners Marketing & Terminals L.P., executed April 28, 2008

2.4.1		List of Schedules and Exhibits to Terminals and Purchase Agreement omitted from this filing. Registrant hereby undertakes, pursuant to Regulation S-K Item 601(2) to furnish any such schedules and exhibits to the SEC supplementally, upon request.

10.1		Sunoco Partners LLC Executive Summary Compensation Sheet

12.1		Statement of Computation of Ratio of Earnings to Fixed Charges

31.1		Chief Executive Officer Certification of Periodic Report Pursuant to Exchange Act Rule 13a-14(a)

31.2		Chief Financial Officer Certification of Periodic Report Pursuant to Exchange Act Rule 13a-14(a)

32.1		Chief Executive Officer Certification of Periodic Report Pursuant to Exchange Act Rule 13a-14(b) and U.S.C. §1350

32.2		Chief Financial Officer Certification of Periodic Report Pursuant to Exchange Act Rule 13a-14(b) and U.S.C. §1350

We are pleased to furnish this Form 10-Q to unitholders who request it by writing to:

Sunoco Logistics Partners L.P.

Investor Relations

Mellon Bank Center

1735 Market Street

Philadelphia, PA 19103-7583

or through our website at www.sunocologistics.com.

SIGNATURE

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


Sunoco Logistics Partners L.P.

By:		/s/ NEAL E. MURPHY
		Neal E. Murphy
		Vice President and Chief Financial Officer

Date: August 6, 2008