View Filing Data

3,325

2,808

2,385

1,955

1,786

1,583

1,815

1,507

10,473

6,691

4,696

Other income

Cost of products sold and operating expenses

10,918

7,838

5,430

Costs and Expenses

10,264

7,398

5,023

Selling, general and administrative expenses

^[1]

Total Costs and Expenses

10,482

7,537

5,135

Net interest cost to affiliates (Note 3)

112

128

121

436

301

295

Other interest cost and debt expense, net

Capitalized interest

(7)

(5)

(4)

Gain on investments in affiliates (Note 2)

128

Provision for income taxes (Note 1)

347

356

250

Net Income attributable to noncontrolling interests

^[2]

^[3]

194

^[3]

322

348

250

Net Income attributable to Sunoco Logistics Partners L.P.

193

313

346

250

Calculation of Limited Partners' interest:

Net Income attributable to Sunoco Logistics Partners L.P.

193

313

346

250

Less: General Partner's interest

(14)

(12)

(15)

(11)

(10)

(54)

(48)

(52)

Limited Partners' interest

$ 62

$ 81

$ 80

$ 36

$ 47

$ 178

$ 40

$ 33

$ 259

$ 298

$ 198

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit (Note 4):

Basic | $ / shares

0.60

0.78

0.80

0.36

0.47

1.87

0.43

0.35

2.56

^[4]

3.13

^[4]

2.17

^[4]

Diluted | $ / shares

0.60

0.78

0.80

0.36

0.47

1.86

0.43

0.35

2.54

^[4]

3.11

^[4]

2.16

^[4]

Weighted average Limited Partners' units outstanding:

Basic | shares

^[4]

101.3

95.2

91.0

Diluted | shares

^[4]

101.8

95.7

91.6

[1]	In 2011, the Partnership recognized a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[2]	Net income for the fourth quarter 2011 includes a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge is comprised of a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[3]	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.
[4]	Reflects the fourth quarter 2011 three-for-one unit split.

Consolidated Balance Sheets - USD ($)
$ in Millions

Dec. 31, 2011

Dec. 31, 2010

Assets

Advances to affiliated companies (Note 3)

$ 5

$ 2

107

Accounts receivable, affiliated companies (Note 3)

154

2,188

1,536

Inventories (Note 5)

206

Properties, plants and equipment

2,506

1,799

3,234

2,799

Less accumulated depreciation and amortization

(712)

(671)

Properties, plants and equipment, net (Note 6)

2,522

2,128

Investment in affiliates (Note 7)

Goodwill (Note 8)

Intangible assets, net (Note 8)

277

109

5,477

^[1]

4,188

^[2]

Liabilities and Equity

Current portion of long-term debt (Note 9)

2,111

1,591

250

Accrued taxes payable (Note 1)

112

Long-term debt, affiliated companies (Notes 3 & 9)

2,535

1,711

100

Long-term debt (Note 9)

1,448

1,129

Other deferred credits and liabilities

Deferred income taxes (Note 1)

222

164

Commitments and contingent liabilities (Note 10)

Limited Partners' interest (99,386,301 and 99,197,496 units outstanding, repectively)

4,283

3,146

Equity

^[3]

1,039

940

General Partner's interest

Accumulated other comprehensive gain/(loss)

(3)

Total Sunoco Logistics Partners L.P. equity

1,096

965

Noncontrolling interests

1,194

1,042

Class A interest (3,939,435 and 0 units outstanding, respectively)

5,477

$ 4,188

Common Class A [Member]

Equity

^[3]

$ 22

[1]	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $107 million advances to affiliates, $15 million deferred financing costs, and $40 million to properties, and plants and equipment, net.
[2]	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $44 million advances to affiliates, $9 million deferred financing costs, and $32 million to properties, and plants and equipment, net.
[3]	Reflects the fourth quarter 2011 three-for-one unit split.

Consolidated Balance Sheets (Parenthetical) - shares	12 Months Ended
Consolidated Balance Sheets (Parenthetical) - shares	Dec. 31, 2011	Dec. 31, 2010
Limited partners, units outstanding	99,386,301	99,197,496
Common Class A [Member]
General partners, units outstanding	3,939,435	0

Consolidated Statements Of Cash Flows - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Cash Flows from Operating Activities:

Adjustments to reconcile net income to net cash provided by (used in) operating activities:

$ 322

$ 348

$ 250

Deferred income tax expense

^[1]

(2)

Amortization of financing fees and bond discount

Restricted unit incentive plan expense

Changes in working capital pertaining to operating activities:

(128)

Accounts receivable, affiliated companies

154

(106)

(647)

(248)

(627)

Accounts payable and accrued liabilities

(108)

548

360

463

Accrued taxes payable

Other

(8)

Net cash provided by operating activities

430

341

176

Cash Flows from Investing Activities:

(213)

(174)

(176)

Net cash used in investing activities

(396)

(252)

(50)

(609)

(426)

(226)

Cash Flows from Financing Activities:

Distributions paid to limited and general partners

(210)

(189)

(173)

Distributions paid to noncontrolling interests

(8)

(4)

Net proceeds from issuance of limited partner units

143

110

Contributions from general partner

Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan

(3)

(2)

Repayments under credit facilities

(560)

(888)

(687)

Borrowings under credit facilities

529

650

633

Net proceeds from issuance of long-term debt

595

494

173

Promissory note from affiliate

(100)

100

Repayment of promissory note to general partner

(201)

Advances to affiliated companies, net

(63)

(21)

(6)

Net cash provided by financing activities

182

Net change in cash and cash equivalents

Cash and cash equivalents at beginning of year

Cash and cash equivalents at end of period

$ 5

$ 2

[1]

In 2011, the Partnership recognized a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.

Consolidated Statements Of Equity - USD ($)
shares in Millions, $ in Millions

Class A Units [Member]

Limited Partners [Member]

Common Stock [Member]

General Partner [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

Non-Controlling Interests [Member]

Total

Balance at Dec. 31, 2008

$ 653

$ 20

$ (3)

$ 670

Balance, shares at Dec. 31, 2008

^[1]

86.1

Comprehensive Income:

Gain (loss) on cash flow hedges

$ 197

250

Total comprehensive income

197

251

Issuance of Limited Partner units to the public, value

$ 110

112

Issuance of Limited Partner units to the public, shares

^[1]

6.7

Units issued under incentive plans

$ 5

Units issued under incentive plans, shares

^[1]

0.2

Distribution equivalent rights

$ (1)

(1)

Payment of statutory withholding on issuance of LTIP

(2)

Distributions paid to limited partners, general partner and noncontrolling interests

(125)

(48)

(173)

Balance at Dec. 31, 2009

$ 837

(2)

862

Balance, shares at Dec. 31, 2009

^[1]

93.0

Comprehensive Income:

Recognition of funded status of affiliates' postretirement plans

$ 298

$ 2

348

Gain (loss) on cash flow hedges

(2)

Total comprehensive income

298

(1)

347

Issuance of Limited Partner units to the public, value

$ 143

146

Issuance of Limited Partner units to the public, shares

^[1]

6.0

Units issued under incentive plans

$ 5

Units issued under incentive plans, shares

^[1]

0.2

Distribution equivalent rights

$ (1)

(1)

Payment of statutory withholding on issuance of LTIP

(2)

Noncontrolling equity in joint venture acquisitions

Distribution related to IDR transaction

(197)

(4)

(201)

Distributions paid to limited partners, general partner and noncontrolling interests

(143)

(46)

(4)

(193)

Other

(1)

Balance at Dec. 31, 2010

$ 940

(3)

1,042

Balance, shares at Dec. 31, 2010

^[1]

99.2

Comprehensive Income:

Gain (loss) on cash flow hedges

$ 2

$ 257

322

Total comprehensive income

257

326

Issuance of Class A units to Sunoco, Inc., value

$ 20

Issuance of Class A units to Sunoco, Inc., shares

^[1]

3.9

Units issued under incentive plans

$ 6

Units issued under incentive plans, shares

^[1]

0.2

Distribution equivalent rights

$ (2)

(2)

Payment of statutory withholding on issuance of LTIP

(3)

Noncontrolling equity in joint venture acquisitions

Distributions paid to limited partners, general partner and noncontrolling interests

(160)

(50)

(8)

(218)

Other

Balance at Dec. 31, 2011

$ 22

$ 1,039

$ 34

$ 1

$ 98

$ 1,194

Balance, shares at Dec. 31, 2011

^[1]

3.9

99.4

[1]	Reflects the fourth quarter 2011 three-for-one unit split

Summary Of Significant Accounting Policies

12 Months Ended

Dec. 31, 2011

Summary Of Significant Accounting Policies [Abstract]

Summary Of Significant Accounting Policies

1. Summary of Significant Accounting Policies

Principles of Consolidation

The consolidated financial statements reflect the results of Sunoco Logistics Partners L.P. (the "Partnership" or "SXL") and its wholly-owned subsidiaries, including Sunoco Logistics Partners Operations L.P. (the "Operating Partnership") and the proportionate shares of the Partnership's undivided interests in assets, and the accounts of entities in which the Partnership has a controlling financial interest. A controlling financial interest is evidenced by either a voting interest greater than 50 percent or a risk and rewards model that identifies the Partnership or one of its subsidiaries as the primary beneficiary of a variable interest entity (VIE). The Partnership holds a controlling financial interest in Inland Corporation ("Inland"), Mid-Valley Pipeline Company ("Mid-Valley") and West Texas Gulf Pipe Line Company ("West Texas Gulf"), and as such, these joint ventures are reflected as consolidated subsidiaries of the Partnership from the respective dates of acquisition. All significant intercompany accounts and transactions are eliminated in consolidation and noncontrolling interests in equity and net income are shown separately in the consolidated statements of income and balance sheets. Equity ownership interests in corporate joint ventures in which the Partnership does not have a controlling financial interest are accounted for under the equity method of accounting. The consolidated financial statements separately reflect amounts attributable to the noncontrolling interests.

Reclassifications and Recasts

Certain amounts in the prior years' consolidated financial statements have been reclassified to conform to the current-year presentation. Specifically, the Partnership realigned its reporting segments in 2011 and recast prior year amounts conform to the current year presentation for comparability purposes. In addition, the Partnership completed a three-for-one split of its common and Class A units in 2011. The unit split resulted in the issuance of two additional common or Class A units for every one unit owned. All unit and per unit information included in this report are presented on a post-split basis.

Use of Estimates

The preparation of financial statements in conformity with United States generally accepted accounting principles ("GAAP") requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.

Revenue Recognition

Terminalling and storage revenues are recognized at the time the services are provided. Pipeline revenues are recognized upon delivery of the barrels to the location designated by the shipper. Acquisition and marketing revenues for crude oil and refined products are recognized when title to and risk of loss of the product is transferred to the customer. Revenues are not recognized for crude oil exchange transactions, which are entered into primarily to acquire crude oil of a desired quality or to reduce transportation costs by taking delivery closer to the Partnership's end markets. Any net differential for exchange transactions is recorded as an adjustment of inventory costs in the purchases component of cost of products sold and operating expenses in the consolidated statements of income.

Affiliated revenues consist of sales of crude oil and refined products, as well as the provision of crude oil and refined products, pipeline transportation, terminalling and storage services to Sunoco, Inc. and its wholly owned subsidiaries (collectively referred to as "Sunoco"). Sales of crude oil and refined products to affiliates are priced using market based rates. Sunoco pays fees for transportation or terminalling services based on the terms and conditions of an established agreement or utilizing published tariffs.

Cash Equivalents

The Partnership considers all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash equivalents. At December 31, 2011 and 2010, these cash equivalents consist of money market accounts.

Accounts Receivable, Net

Accounts receivable represent valid claims against non-affiliated customers (see Note 3 for affiliated receivables) for products sold or services rendered. The Partnership extends credit terms to certain customers after review of various credit indicators, including the customer's credit rating. Outstanding customer receivable balances are regularly reviewed for possible non-payment indicators and reserves are recorded for doubtful accounts based upon management's estimate of collectability at the time of review. Actual balances are charged against the reserve when all collection efforts have been exhausted.

Inventories

Inventories are valued at the lower of cost or market. Crude oil and refined products inventory costs have been determined using the last-in, first-out method ("LIFO"). Under this methodology, the cost of products sold consists of the actual acquisition costs of the Partnership, which include transportation and storage costs. Such costs are adjusted to reflect increases or decreases in inventory quantities, which are valued based on the changes in the LIFO inventory layers. The cost of materials, supplies and other inventories is principally determined using the average cost method.

Properties, Plants and Equipment

Properties, plants and equipment are stated at cost. Additions to properties, plants and equipment, including replacements and improvements, are recorded at cost. Repair and maintenance expenditures are charged to expense as incurred. Depreciation is provided principally using the straight-line method based on the estimated useful lives of the related assets. For certain interstate pipelines, the depreciation rate is applied to the net asset value based on the Federal Energy Regulatory Commission's ("FERC") requirements, which approximates the useful lives proscribed under GAAP.

Capitalized Interest

The Partnership capitalizes interest on borrowed funds related to capital projects for periods that construction activities are in progress to bring these projects to their intended use.

Investment in Affiliates

Investments in affiliates, which consist of corporate joint ventures, are accounted for under the equity method of accounting. Under this method, an investment is carried at acquisition cost, increased for the equity in income or decreased for the equity in loss from the date of acquisition, reduced for dividends received and increased or decreased for adjustments in other comprehensive income. Income recognized from the Partnership's corporate joint venture interests is presented within other income on the consolidated statements of income.

The Partnership allocates the excess of its investment cost over its equity in the net assets of affiliates to the underlying tangible and intangible assets of the corporate joint ventures. 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. The amortization of these amounts is included within depreciation and amortization in the consolidated statements of income.

Acquisitions

The assets acquired and liabilities assumed as part of the Partnership's business combinations are recorded at their estimated fair values as of the date of acquisition. Any excess of consideration transferred plus the fair value of noncontrolling interest over the estimated fair value of the net assets acquired is recorded as goodwill. To the extent the estimated fair value of the net assets acquired exceeds the purchase price plus the fair value of the noncontrolling interest, a gain is recorded in current operations. The results of operations of acquired businesses are included in the Partnership's results from the dates of acquisition.

The Partnership's asset acquisitions are recorded at the purchase price, which is allocated to the acquired assets and assumed liabilities based on their relative estimated fair values.

Assets acquired and liabilities assumed include tangible and intangible assets, and contingent assets and liabilities. The estimated fair values of these assets and liabilities are determined based on observable inputs such as quoted market prices, information from comparable transactions, offers made by other prospective acquirers in the cases where the Partnership has certain rights to acquire additional interests in existing investments, and the replacement cost of assets in the same condition or stage of usefulness, or on unobservable inputs such as expected future cash flows or internally developed estimates of value. In accordance with GAAP, the Partnership classifies its valuations in the fair value hierarchy based on the lowest level of inputs used to estimate fair value.

Impairment of Long-Lived Assets

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. An asset is considered to be impaired when the undiscounted estimated net cash flows expected to be generated by the asset are less than its carrying amount. The impairment recognized is the amount by which the carrying amount exceeds the estimated fair value of the impaired asset. Long-lived assets held for sale are recorded at the lower of their carrying amount or estimated fair value less cost to sell the assets.

In September 2011, Sunoco announced its intention to exit its refining business in the northeast and initiated a process to sell its refineries located in Philadelphia and Marcus Hook, Pennsylvania. In December 2011, the main processing units at the Marcus Hook refinery were idled indefinitely. Sunoco continues to pursue a sale of both the Philadelphia and Marcus Hook facilities, however Sunoco does not believe that the Marcus Hook facility will be sold and restarted as an operating refinery. If arrangements for sale cannot be made, Sunoco intends to permanently idle the facilities by July 2012. Management assessed the impact that Sunoco's decision to exit its refining business in the northeast will have on the Partnership's assets that have historically served the refineries and determined that the Partnership's refined products pipeline and terminal assets continue to have expected future cash flows that support their carrying values. However, the Partnership recognized a $42 million charge in the fourth quarter 2011 for crude oil terminal assets which would be negatively impacted if the Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.

In 2010, the Partnership recognized an impairment of $3 million related to the cancellation of a construction project. The impairment charge reflects costs associated with assets that the Partnership cannot deploy elsewhere.

The impairment was calculated using fair value assumptions, including comparable land sale transactions and current replacement costs of similar new equipment, adjusted to reflect the age, condition, maintenance history and estimated useful life of the assets. Since the fair value assessment reflects both observable and unobservable inputs, it was determined to be a non-recurring level 3 fair value measurement within the fair value hierarchy under current accounting guidance.

Goodwill

Goodwill, which represents the excess of the purchase price in a business combination over the fair value of net assets acquired, is tested for impairment annually or more often if warranted by events or changes in circumstances indicating that the carrying value may exceed the estimated fair value. The Partnership determined during 2011, 2010 and 2009 that goodwill was not impaired.

Management's process of evaluating goodwill for impairment involves estimating the fair value of the Partnership's reporting units that contain goodwill. Inherent in estimating the fair value for each reporting unit are certain judgments and estimates relating to market multiples for comparable businesses, including management's interpretation of current economic indicators and market conditions, and assumptions about the Partnership's strategic plans with regard to its operations. To the extent additional information arises, market conditions change or the Partnership's strategies change, it is possible that the conclusion regarding whether the goodwill is impaired could change and result in future goodwill impairment charges.

Fair value is estimated using a market multiple methodology whereby multiples of business enterprise value to earnings, before interest, taxes, depreciation and amortization ("EBITDA") of comparable companies are used to estimate the fair value of the reporting units. Management establishes fair value by comparing the reporting unit to other companies that are similar, from an operational or industry standpoint and considers the risk characteristics in order to determine the risk profile relative to the comparable companies as a group. The most significant assumptions are the market multiplies.

In September 2011, the FASB codified guidance related to the testing of goodwill for impairment. The guidance provides entities with the option to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is more likely than not that the fair value of a reporting unit is not less than its carrying amount, then performing the two-step impairment test is not required. However, if an entity concludes otherwise, then it is required to perform the first step of the two-step impairment test. Entities have the option of bypassing the qualitative analysis in any period and proceeding directly to the two-step impairment test. The provisions of this guidance are effective for the Partnership January 1, 2012. The Partnership did not elect to early adopt this guidance for the year ended December 31, 2011. The Partnership does not expect the application of the qualitative assessment to yield different results than the previous methodology.

Intangible Assets

The Partnership has acquired intangible assets such as throughput and deficiency contracts, customer relationships, historical shipping rights and patents related to butane blending technology. The value assigned to these intangible assets is amortized on a straight-line basis over their respective economic lives through depreciation and amortization expense in the consolidated statements of income.

Environmental Remediation

The Partnership accrues environmental remediation costs for work at identified sites where an assessment has indicated that cleanup costs are probable and reasonably estimable. Such accruals are undiscounted and are based on currently available information, estimated timing of remedial actions and related inflation assumptions, existing technology and presently enacted laws and regulations. If a range of probable environmental cleanup costs exists for an identified site, the minimum of the range is accrued unless some other point or points in the range are more likely, in which case the most likely amount in this range is accrued.

Income Taxes

The Partnership is not a taxable entity for U.S. federal income tax purposes, or for the majority of states that impose income taxes. Rather, income taxes are generally assessed at the partner level. There are some states in which the Partnership operates where it is subject to state and local income taxes. Substantially all of the income tax reflected in the Partnership's consolidated financial statements is derived from the operations of Inland, Mid-Valley and West Texas Gulf, all of which are entities subject to income taxes for federal and state purposes at the corporate level. The effective tax rates for these entities approximate the federal statutory rate of 35 percent.

The Partnership recognizes a tax benefit from uncertain positions only if it is more likely than not that the position is sustainable, based solely on its technical merits and consideration of the relevant taxing authorities' widely understood administrative practices and precedents. The tax benefits recognized from such positions are measured based on the largest benefit that has a greater than 50 percent likelihood of being realized upon settlement.

For the years ended December 31, 2011 and 2010, income tax expense is comprised of:


	Year ended December 31,
	2011			2010
	(in millions)
Federal
Current	$	25		$	6
Deferred		(2	)		—
State
Current		2			2
Deferred		—			—

Total income tax expense	$	25		$	8

During 2011 and 2010, the income taxes paid by Inland, Mid-Valley and West Texas Gulf approximated current income tax expense for each year. There was no income tax provision for the year ended December 31, 2009 when the operations of Inland, Mid-Valley and West Texas Gulf were not consolidated, as the Partnership did not have a controlling financial interest in these entities.

In taxable jurisdictions, the Partnership records deferred income taxes on all significant temporary differences between the book basis and the tax basis of assets and liabilities. At December 31, 2011 and 2010, the Partnership had $222 and $164 million, respectively, of net deferred tax liability derived principally from the difference in the book and tax bases of properties, plants and equipment associated with the Inland, Mid-Valley and West Texas Gulf acquisitions.

Long-Term Incentive Plan

The Partnership accounts for the compensation cost of all unit-based payment awards at fair value and reports the related expense within selling, general and administrative expenses in the consolidated statements of income. Unit-based compensation cost for awards of restricted units is derived from the fair market value of common units on the grant date using a Monte Carlo Simulation if the payout is determined by market criteria related to unit proxies or grant date market price of the underlying unit. The Partnership recognizes unit-based compensation cost as expense ratably on a straight-line basis over the requisite service period unless the participant is retirement eligible, in which case, the recognition of the compensation cost is accelerated in the period the participant becomes retirement-eligible.

Asset Retirement Obligations

Asset retirements obligations ("AROs") represent the fair value of a liability related to the retirement of long-lived assets and are recorded at the time a legal obligation is incurred. A corresponding asset is also recorded at that time and is depreciated over the remaining useful life of the related asset. The fair value of any ARO is determined based on estimates and assumptions related to retirement costs, which the Partnership bases on historical retirement costs, future inflation rates and credit-adjusted risk-free interest rates. These fair value assessments are considered to be non-recurring level 3 measurements, as they are based on both observable and unobservable inputs. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.

The Partnership's consolidated balance sheets include liabilities for asset retirement obligations, as a component of other deferred credits and liabilities, of $51 million and $25 million at December 31, 2011 and 2010, respectively. The increase in the balance from 2010 to 2011 is attributable to $15 million of additional AROs, associated with increases in assumed retirement costs of $8 million, $7 million related to the continued expansion of the business, and $11 million of regulatory obligations which would be incurred if certain terminal assets which provide services to Sunoco's Philadelphia refinery are permanently idled. The Partnership believes it may have additional asset retirement obligations related to its pipeline assets and storage tanks, for which it is not possible to estimate whether or when the retirement obligations will be settled. Consequently, these retirement obligations cannot be measured at this time.

Fair Value Measurements

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. 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 the Financial Accounting Standards Board ("FASB"). The Partnership generally applies a "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.

In May 2011, the FASB issued a new accounting standard update, which amends the fair value measurement guidance and includes some enhanced disclosure requirements. The most significant change in disclosures is an expansion of the information required for level 3 measurements based on unobservable inputs. The standard is effective for fiscal years beginning after December 15, 2011. The Partnership will adopt this standard January 1, 2012 and does not expect the adoption of this standard to have a material impact on its consolidated financial statements and disclosures.

Comprehensive Income

In June 2011, FASB codified guidance related to the presentation of comprehensive income. The guidance requires entities to present net income and other comprehensive income in a single continuous statement of comprehensive income or in two separate, but consecutive, statements. The new guidance does not change the components that are recognized in net income and the components that are recognized in other comprehensive income. Currently, the Partnership presents comprehensive income in its statements of equity. The provisions of this guidance are effective for the Partnership beginning January 1, 2012 and are required to be applied retroactively.

Lease Accounting

The Partnership accounts for arrangements that convey the right to use property, plant or equipment for a stated period of time as leases. Whether an arrangement contains a lease is determined at inception of the arrangement based on all of the facts and circumstances. The Partnership reassesses whether the arrangement contains a lease after the inception of the arrangement only if (a) there is a change in the contractual terms, (b) a renewal option is exercised or an extension is agreed to by the parties to the arrangement, (c) there is a change in the determination as to whether or not fulfillment is dependent on specified property, plant, or equipment, or (d) there is a substantial physical change to the specified property, plant, or equipment. The Partnership continually analyzes its new and existing arrangements to evaluate whether they contain leases. Revenue or expense from arrangements where the Partnership is the lessor or lessee, respectively, is recognized ratably over the term of the underlying arrangement.

Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit

The Partnership uses the two-class method to determine basic and diluted earnings per unit. The two-class method is an earnings allocation formula that determines the earnings for each class of equity ownership and participating security according to distributions declared and participation rights in undistributed earnings. The Partnership calculates basic and diluted net income attributable to Sunoco Logistics Partners L.P. per limited partner unit ("net income attributable to SXL") by dividing net income attributable to SXL, after deducting the amount allocated to the general partner's interest and incentive distribution rights ("IDRs"), by the weighted-average number of limited partner units and Class A units outstanding during the period. IDRs in a master limited partnership are treated as participating securities for the purpose of computing net income attributable to limited partner units. The general partner holds all of the IDRs. In addition, when earnings differ from cash distributions, undistributed or over distributed earnings are to be allocated to the general partner, limited partners and Class A unitholder based on the contractual terms of the partnership agreement.

Acquisitions

12 Months Ended

Dec. 31, 2011

Acquisitions [Abstract]

2. Acquisitions

A key component of the Partnership's primary business strategy is to pursue strategic and accretive acquisitions that complement its existing asset base. The Partnership completed the following acquisitions during the three-year period ended December 31, 2011:

2011 Acquisitions

•

In August 2011, the Partnership acquired a refined products terminal, located in East Boston, Massachusetts, from affiliates of ConocoPhillips for $56 million plus the fair value of inventory. The terminal includes a 10-bay truck rack and approximately 1 million barrels of capacity and is the sole service provider to Logan International Airport under a long-term contract to supply jet fuel. The acquisition is included within the Terminal Facilities segment.

•

In August 2011, the Partnership acquired a crude oil purchasing and marketing business from Texon L.P. ("Texon") for $205 million plus the fair value of its crude oil inventory. The purchase consisted of a crude oil acquisition and marketing business and gathering assets for approximately 75,000 barrels per day at the wellhead in 16 states, primarily in the western United States. The acquisition is included within the Crude Oil Acquisition and Marketing segment.

•

In July 2011, the Partnership acquired the Eagle Point tank farm and related assets from Sunoco for $100 million. The tank farm is located in Westville, New Jersey and has approximately 5 million barrels of active storage for refined products and dark oils. The acquisition was funded by the issuance of 3.9 million of Class A units with an estimated market value of $98 million and payment of $2 million of cash to Sunoco. The Class A units represent a new class of units on which no distributions will be paid and which convert to common units on the one-year anniversary of their issuance. As the acquisition was from a related party, the assets acquired were recorded by the Partnership at Sunoco's net carrying cost of $22 million. The $20 million difference between the carrying value of the assets and the cash consideration paid was recorded by the Partnership as an increase to equity. The acquisition is included within the Terminal Facilities segment.

•

In May 2011, the Partnership acquired an 83.8 percent equity interest in Inland, which is the owner of 350 miles of active refined products pipelines in Ohio. The pipeline connects three refineries in Ohio to terminals and major markets in Ohio. The Partnership acquired its equity interest for $99 million, net of cash received, through a purchase of a 27.0 percent equity interest from Shell Oil Company ("Shell") and a 56.8 percent equity interest from Sunoco. The 56.8 percent equity interest acquired from Sunoco was considered a transaction between entities under common control and therefore the assets and liabilities transferred were recorded by the Partnership at Sunoco's carrying value. As the Partnership acquired a controlling financial interest in Inland, the joint venture is reflected as a consolidated subsidiary of the Partnership from the date of the final acquisition and is included within the Refined Products Pipelines segment.

The following table summarizes the effects of the 2011 acquisitions on the Partnership's consolidated balance sheet as of the respective acquisition dates:


	East Boston Terminal			Crude Oil Acquisition and Marketing			Eagle Point Tank Farm			Inland			Total
	(in millions)
Increase in:
Current assets	$	17		$	24		$	—		$	3		$	44
Properties, plants & equipment, net		63			7			22			178			270
Intangible assets, net		—			183			—			—			183
Goodwill		—			14			—			—			14
Current liabilities		—			(6	)		—			(1	)		(7	)
Other deferred credits and liabilities		(7	)		—			—			(1	)		(8	)
Deferred income taxes		—			—			—			(60	)		(60	)
Sunoco Logistics Partners L.P. equity		—			—			(20	)		—			(20	)
Noncontrolling interests		—			—			—			(20	)		(20	)

Cash paid for acquisitions	$	73		$	222		$	2		$	99		$	396

2010 Acquisitions

•

In October 2010, the Partnership acquired two terminals in Texas for $9 million. The Partnership also assumed a $1 million environmental liability in connection with these transactions. The acquisitions included a terminal in Bay City, Texas, acquired from Gulfstream Terminals & Marketing LLC, which is capable of handling both crude oil and refined product volumes. Total active terminal storage capacity of the facility is less than half of a million barrels. In addition, the Partnership acquired a refined products terminal and pipeline segment in Big Sandy, Texas, from affiliates of Chevron Corporation. The terminal and pipeline have not been operational and were sold to affiliates of Delek US Holdings, Inc. in February 2012. The terminals were included in the Terminal Facilities from the respective dates of acquisition.

•

In July 2010, the Partnership acquired a butane blending business from Texon L.P. for $140 million plus refined product inventory for a total of $152 million. The acquisition included patented technology for blending of butane into gasoline, contracts with customers currently utilizing the patented technology, butane inventories and other related assets. Goodwill was recognized related to expected synergies with the Partnership's terminal facilities. The acquisition is included within the Terminal Facilities.

•

In July 2010, the Partnership exercised its rights to acquire an additional ownership interest in West Shore Pipeline Company ("West Shore") from an affiliate of BP for $6 million, increasing its ownership interest from 12.3 percent to 17.1 percent. West Shore owns approximately 650-miles of common carrier refined products pipelines that originate in Chicago, Illinois and services delivery points from Chicago to Wisconsin. The investment is accounted for as an equity method investment within the Partnership's Refined Products Pipelines, with the equity income recorded based on the Partnership's ownership percentage from the date of acquisition.

•

In July 2010, the Partnership exercised its rights to acquire an additional ownership interest in Mid-Valley from an affiliate of BP for $58 million, increasing its ownership interest from 55.3 percent to 91.0 percent. Mid-Valley owns, and the Partnership is the operator of, an approximately 1,000-mile common carrier pipeline, which originates in Longview, Texas and terminates in Samaria, Michigan. The pipeline provides crude oil to a number of refineries, primarily in the midwest United States.

In August 2010, the Partnership exercised similar rights to acquire an additional ownership interest in West Texas Gulf from an affiliate of BP for $27 million, increasing its ownership interest from 43.8 percent to 60.3 percent. West Texas Gulf owns, and the Partnership is the operator of, an approximately 600-mile common carrier crude oil pipeline system which originates from the West Texas oil fields at Colorado City and the Partnership's Nederland Terminal, and extends to Longview, Texas where deliveries are made to several pipelines, including Mid-Valley.

As the Partnership acquired a controlling financial interest in both Mid-Valley and West Texas Gulf, the joint ventures are reflected as consolidated subsidiaries of the Partnership from their respective acquisition dates. The acquisitions are included within the Crude Oil Pipelines from the respective acquisition dates. Gains attributable to the re-measurement of the previously held equity interests in Mid-Valley and West Texas Gulf totaling $128 million, were recognized in "Gain on investments in affiliates" in the consolidated statement of income for the year ended December 31, 2010. The fair value of the Partnership's pre-acquisition equity interests in Mid-Valley and West Texas Gulf, $90 million and $72 million, respectively, were determined based on the amounts paid by the Partnership, which were equal to the offers of other prospective acquirers (level 1 observable input). The Partnership used the same methodology to determine the fair value of the noncontrolling interests.

The following table summarizes the effects of the 2010 acquisitions on the Partnership's consolidated balance sheet (including the consolidation of Mid-Valley and West Texas Gulf) as of the respective acquisition dates:


	Butane Blending		Joint Ventures			Terminals			Total
	(in millions)
Increase in:
Current assets	$	14	$	23		$	—		$	37
Investment in affiliates		—		6			—			6
Properties, plants & equipment, net		1		471			10			482
Intangible assets, net		90		—			—			90
Goodwill		47		—			—			47
Deferred charges and other assets		—		1			—			1
Current liabilities		—		(4	)		—			(4	)
Other deferred credits and liabilities		—		(1	)		(1	)		(2	)
Deferred income taxes		—		(164	)		—			(164	)
Sunoco Logistics Partners L.P. equity		—		(128	)		—			(128	)
Noncontrolling interests		—		(80	)		—			(80	)
Decrease in:
Investment in affiliates		—		(33	)		—			(33	)

Cash paid for acquisitions	$	152	$	91		$	9		$	252

2009 Acquisitions

•

In September 2009, the Partnership purchased a refined products terminal located in Romulus, Michigan from R.K.A. Petroleum LLC ("RKA") for $18 million. The total terminal storage capacity is less than half of a million barrels. The terminal services the Detroit metropolitan area and is connected to the Partnership's pipeline system. The agreement included a contingency clause which requires additional payments to RKA up to $2 million, if revenue generated as a result of certain customers/products exceeds a pre-determined amount. The estimated fair value of the contingency was included in the purchase price. The results of the acquisition are included in the consolidated financial statements within the Terminal Facilities from the acquisition date.

•

In September 2009, the Partnership purchased a 100% membership interest in Excel Pipeline LLC ("Excel") from affiliates of Gary-Williams Energy Corporation ("Gary-Williams") for $32 million. The tangible assets of Excel consist of approximately 50 miles of a crude oil pipeline originating in Duncan, Oklahoma and terminating at Gary-Williams' refinery in Oklahoma. The Partnership was the operator of the pipeline prior to the acquisition. In connection with the transaction, the Partnership assumed a 20-year throughput and deficiency contract with Gary-Williams. Pursuant to the contract, Gary-Williams guarantees minimum amounts of crude oil throughput on the pipelines and the Partnership agrees to provide transportation of such crude oil. The results of the acquisition are included in the Crude Oil Pipelines from the acquisition date.

The following table summarizes the effects of the 2009 acquisitions on the Partnership's consolidated balance sheet as of the acquisition dates:


	Excel Pipeline LLC		Romulus Terminal		Total
	(in millions)
Increase in:
Properties, plants & equipment, net	$	11	$	18	$	29
Intangible assets, net		21		—		21

Cash paid for acquisitions	$	32	$	18	$	50

No pro forma information has been presented since the impact of acquisitions during the 2009 through 2011 period were not material in relation to the Partnership's consolidated results of operations.

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

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Related Party Transactions

Related Party Transactions

12 Months Ended

Dec. 31, 2011

3. Related Party Transactions

Incentive Distribution Rights Exchange

In January 2010, the Partnership entered into a repurchase agreement with its general partner, whereby the Partnership agreed to repurchase from the general partner the existing IDRs for $201 million and the issuance of new IDRs. The Partnership initially financed this arrangement with a promissory note to the general partner that was due December 31, 2010. Pursuant to this transaction, the Partnership executed the third amended and restated agreement of limited partnership of the Partnership (the "new partnership agreement"). The new partnership agreement reflects the cancellation of the original IDRs and the authorization and issuance of the new IDRs (Note 12). Proceeds from the February 2010 issuance of $500 million in Senior Notes were used to repay this promissory note in full (Note 9).

Promissory Note from Affiliate

In July 2010, the Partnership acquired a butane blending business from Texon L.P. The acquisition was partially funded by a three-year, subordinated $100 million note from Sunoco, which bears interest at three-month LIBOR plus 275 basis points per annum. The Partnership repaid the $100 million note during the fourth quarter of 2011.

Pipeline and Terminalling Agreements

The Partnership is party to various agreements with Sunoco to supply refined products and to provide pipeline and terminalling services. Affiliated revenues in the consolidated statements of income consist of sales of refined products and crude oil as well as the related provision, and services including pipeline transportation, terminalling, and storage and blending to Sunoco.

The Partnership had the following material agreements with Sunoco and their affiliates for the year ended December 31, 2011:

•

The Partnership has a five-year product terminal services agreement with Sunoco under which Sunoco may throughput refined products through the Partnership's terminals. The agreement contains no minimum throughput obligations for Sunoco. The agreement is expected to be renegotiated during the first quarter 2012.

•

The Partnership has a tank farm agreement under which Sunoco may throughput refined products through the Partnership's Marcus Hook tank farm. The agreements contain no minimum throughput obligations for Sunoco. The agreement was extended on a month to month basis beginning in February 2012.

•

The Partnership has an agreement with Sunoco relating to the Fort Mifflin Terminal Complex. Under this agreement, Sunoco will deliver an average of 300,000 bpd of crude oil and refined products per contract year at the Fort Mifflin Terminal Complex. This minimum average throughput is an annual amount for each contract period running from March 1 to February 28. Sunoco does not have exclusive use of the Fort Mifflin Terminal Complex; however, the Partnership is obligated to provide the necessary tanks, marine docks and pipelines for Sunoco to meet its minimum requirements under the agreement. This agreement was extended on a month to month basis beginning in February 2012.

•

The Partnership has a three-year agreement with Sunoco to provide 2.5 million barrels of storage capacity and terminalling services to Sunoco at the Eagle Point tank farm. The agreement expires in June 2014. Sunoco does not have exclusive use of the Eagle Point tank farm.

•

Under a 20-year lease agreement which expires in February 2022, Sunoco leases the Partnership's interrefinery pipelines between Sunoco's Philadelphia and Marcus Hook refineries for an annual fee which escalates at 1.67 percent each January 1 for the term of the agreement. The lease agreement also requires Sunoco to reimburse the Partnership for any non-routine maintenance expenditures, as defined, incurred during the term of the agreement. There were no material reimbursements under this agreement during 2009 through 2011.

•

Sunoco is a shipper on the Partnership's refined products pipelines. All movements are on the same terms that would be available to an unrelated third party and are based on published tariff rates on the respective pipelines.

•

The Partnership has an agreement with Sunoco whereby Sunoco purchases, at market-based rates, refined products at certain of the Partnership's terminal facilities. This agreement is negotiated annually and the current agreement expires in May 2012.

During 2011, Sunoco continued to execute its strategy to exit its refining operations which included selling its Toledo, Ohio refinery in March 2011 and initiating a process to sell its northeast refineries located in Philadelphia and Marcus Hook, Pennsylvania. In December 2011, the main processing units at the Marcus Hook refinery were idled indefinitely. Sunoco continues to pursue a sale of both the Philadelphia and Marcus Hook facilities, however Sunoco does not believe that the Marcus Hook facility will be sold and restarted as an operating refinery. If arrangements for sale cannot be made, Sunoco intends to permanently idle the facilities by July 2012. Management assessed the impact that Sunoco's decision to exit its refining business in the northeast will have on the Partnership's assets that have historically served the refineries and determined that the Partnership's refined products pipeline and terminal assets continue to have expected future cash flows that support their carrying values. However, the Partnership recognized a $42 million charge in the fourth quarter 2011 for certain crude oil terminal assets which would be negatively impacted if the Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled. The Partnership continues to assess the impact that Sunoco's exit from refining in the northeast will have on the Partnership's operations.

Sunoco has also announced its intention to continue to grow its distribution and retail marketing assets. The Partnership's pipeline and terminal assets provide a cost effective and efficient outlet to supply Sunoco's retail marketing network, and as such, Management expects that Sunoco will continue to utilize these assets going forward. However, if Sunoco reduces its use of the Partnership's facilities, it could materially and adversely affect the Partnership's results of operations, financial condition or cash flows. The Partnership continues to monitor how operating changes of these refineries will impact future results.

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 $350 million Credit Facility (see Note 9).

Administrative Services

Under the Omnibus Agreement, the Partnership pays Sunoco or the general partner an annual administrative fee that includes expenses incurred by Sunoco and its affiliates to perform certain centralized corporate functions, such as legal, accounting, treasury, engineering, information technology, insurance, and other corporate services, including the administration of employee benefit plans. This fee was $13, $5 and $6 million for the years ended December 31, 2011, 2010 and 2009, respectively. The 2012 annual fee increased to $18 million to cover additional consolidation of services provided by Sunoco that were previously provided by third parties and includes an allocation of management costs for the Chief Executive Officer; Vice President, Chief Financial Officer; Vice President, Chief Human Resources Officer; and others from Sunoco that were previously included in the Partnership's direct costs. This 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), the salaries of pipeline and terminal personnel or other employees of the general partner, or the cost of their employee benefits. The Partnership has no employees, and reimburses Sunoco and its affiliates for these costs and other direct expenses incurred on the Partnership's behalf. 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) was extended by one year in January 2012. 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.

In addition to the fees for the centralized corporate functions, selling, general and administrative expenses in the consolidated statements of income include the allocation of shared insurance costs of $4 million for the years ended December 31, 2011, 2010 and 2009. The Partnership's share of allocated Sunoco employee benefit plan expenses, including 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 was $26, $29 and $28 million for the years ended December 31, 2011, 2010 and 2009 respectively. These expenses are reflected in cost of products sold and operating expenses and selling, general and administrative expenses in the consolidated statements of income.

Affiliated Revenues and Accounts Receivable, Affiliated Companies

The Partnership is party to various agreements with Sunoco to supply crude oil and refined products, as well as to provide pipeline and terminalling services. Affiliated revenues in the consolidated statements of income consist of sales of crude oil and refined products, as well as the related provision, and services including pipeline transportation, terminalling and storage and blending to Sunoco. Sales of crude oil are priced using market-based rates under agreements which automatically renew on a monthly basis unless terminated by either party on 30 days written notice. Sales of refined product are priced using market-based rates under agreements which are negotiated annually. Service revenues are recognized based on published tariffs or negotiated rates under agreements.

Capital Contributions

In July 2011, the Partnership issued 3.9 million Class A Units to Sunoco in connection with the acquisition of the Eagle Point tank farm and related assets (see Note 2). As this the transaction was between related parties, GAAP required the issuance to be recorded at the net of Sunoco's historical carrying value of the assets acquired ($22 million) and the $2 million cash consideration paid. The $20 million of deferred distribution units are a new class of units that will convert to common units, on a one-to-one basis, on the one-year anniversary of their issuance. The Class A Units participate in the allocation of net income on a pro-rata basis with the common units. In connection with this transaction, the general partner contributed $2 million to the Partnership. The Partnership recorded this amount as a capital contribution to Equity within its consolidated balance sheet.

In August 2010, the Partnership completed a public offering of 6.0 million limited partnership units. As a result of this offering, the general partner contributed $3 million to the Partnership to maintain its 2 percent general partner interest. The Partnership recorded this amount as a capital contribution to Equity within its consolidated balance sheet.

In April and May 2009, the Partnership sold 6.7 million limited partnership units in a public offering. As a result of the issuance, the general partner contributed $2 million to the Partnership to maintain its 2 percent general partner interest. The Partnership recorded this amount as a capital contribution to Equity within its consolidated balance sheet.

In February 2011, 2010 and 2009 the Partnership issued 0.2 million limited partnership units, in each year, 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 limited partnership units, the general partner contributed less than $0.1 million in each period to the Partnership to maintain its 2 percent general partner interest. The Partnership recorded these amounts as capital contributions to Equity within its consolidated balance sheets.

The entire disclosure for related party transactions, including the nature of the relationship(s), a description of the transactions, the amount of the transactions, the effects of any change in the method of establishing the terms of the transaction from the previous period, stated interest rate, expiration date, terms and manner of settlement per the agreement with the related party, and amounts due to or from related parties. If the entity and one or more other entities are under common ownership or management control and this control affects the operating results or financial position, disclosure includes the nature of the control relationship even if there are no transactions between the entities. Disclosure may also include the aggregate amount of current and deferred tax expense for each statement of earnings presented where the entity is a member of a group that files a consolidated tax return, the amount of any tax related balances due to or from affiliates as of the date of each statement of financial position presented, the principal provisions of the method by which the consolidated amount of current and deferred tax expense is allocated to the members of the group and the nature and effect of any changes in that method. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

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Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data [Abstract]

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data

12 Months Ended

Dec. 31, 2011

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data

4. Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit Data

The general partner's interest in net income attributable to SXL consists of its 2 percent general partner interest and "incentive distributions," which are increasing percentages, up to 50 percent of quarterly distributions in excess of $0.1667 per limited partner unit (see Note 12). The general partner was allocated net income attributable to SXL of $54 million (representing 17 percent of total net income attributable to SXL for the period) for the year ended December 31, 2011, $48 million (representing 14 percent of total net income attributable to SXL for the period) for the year ended December 31, 2010 and $52 million (representing 21 percent of total net income attributable to SXL for the period) for the year ended December 31, 2009. Diluted net income attributable to SXL per limited partner unit is calculated by dividing net income attributable to SXL by the sum of the weighted-average number of common units and Class A units outstanding (see Note 11) and the dilutive effect of incentive unit awards (see Note 13).

The following table sets forth the reconciliation of the weighted average number of limited partner units used to compute basic net income attributable to SXL per limited partner unit to those used to compute diluted net income attributable to SXL per limited partner unit for the years ended December 31, 2011, 2010 and 2009:


	2011		2010		2009
	(in millions)
Weighted average number of limited partner units outstanding—basic		101.3		95.2		91.0
Add effect of dilutive incentive awards		0.5		0.5		0.6

Weighted average number of limited partner units—diluted		101.8		95.7		91.6

On December 2, 2011, the Partnership completed a three-for-one split of its common and Class A units. The unit split resulted in the issuance of two additional common and Class A units for every one unit owned. All unit and per unit information included in this report are presented on a post-split basis.

Inventories

12 Months Ended

Dec. 31, 2011

Inventories [Abstract]

Properties, Plants And Equipment [Abstract]

5. Inventories

The components of inventories are as follows:


	December 31,
	2011		2010
	(in millions)
Crude oil	$	142	$	39
Refined products		55		16
Refined products additives		2		2
Materials, supplies and other		7		6

	$	206	$	63

The current replacement cost of crude oil and refined products inventory exceeded its carrying value by $196 million and $166 million at December 31, 2011 and 2010, respectively. The increases in crude oil and refined products inventory levels for 2011 compared to 2010 were due principally to the growth in the operating levels of the business and strategic purchases of crude oil.

Properties, Plants And Equipment

12 Months Ended

Dec. 31, 2011

Properties, Plants And Equipment

6. Properties, Plants and Equipment

The components of net properties, plants and equipment are as follows:


	Estimated Useful Lives		December 31,
	Estimated Useful Lives		2011			2010
			(in millions)
Land and land improvements (including rights of way)		—	$	525		$	401
Pipeline and related assets		38 - 60		1,344			1,271
Terminals and storage facilities		5- 44		768			686
Other		5- 48		385			325
Construction-in-progress				212			116

Total properties, plants and equipment			$	3,234		$	2,799
Less: Accumulated depreciation and amortization				(712	)		(671	)

Total properties, plants and equipment, net			$	2,522		$	2,128

The entire disclosure for long-lived, physical assets that are used in the normal conduct of business to produce goods and services and not intended for resale. Examples include land, buildings, machinery and equipment, and other types of furniture and equipment including, but not limited to, office equipment, furniture and fixtures, and computer equipment and software. This disclosure may include property plant and equipment accounting policies and methodology, a schedule of property, plant and equipment gross, additions, deletions, transfers and other changes, depreciation, depletion and amortization expense, net, accumulated depreciation, depletion and amortization expense and useful lives, income statement disclosures, assets held for sale and public utility disclosures.

Investment In Affiliates

12 Months Ended

Dec. 31, 2011

Investment In Affiliates [Abstract]

Investment In Affiliates

7. Investment in Affiliates

The corporate joint ventures own refined products pipeline systems or crude oil pipeline systems. The Partnership's ownership percentages in corporate joint ventures as of December 31, 2011 and 2010 are as follows:


	Ownership percentage
Explorer Pipeline Company		9.4	%
Yellowstone Pipe Line Company		14.0	%
West Shore Pipe Line Company		17.1	%
Wolverine Pipe Line Company		31.5	%

During 2010, the Partnership acquired controlling financial interests in Mid-Valley and West Texas Gulf , which were previously accounted for as equity method investments. Accordingly, the Partnership has consolidated these joint ventures from the dates of their respective acquisitions.

The following table provides summarized unaudited financial information on a 100 percent basis for the Partnership's equity ownership interests:


	2011		2010		2009
	(in millions)
Income Statement Data:⁽¹⁾
Total revenues	$	374	$	439	$	458
Income before income taxes	$	130	$	193	$	190
Net income	$	80	$	120	$	119


Balance Sheet Data (as of year-end):⁽¹⁾
Current assets	$	130	$	122	$	126
Non-current assets	$	648	$	646	$	680
Current liabilities	$	127	$	122	$	124
Non-current liabilities	$	549	$	546	$	568
Net equity	$	102	$	100	$	114

⁽ ¹⁾

The balance sheet and income statement data as of and for the year ended December 31, 2011 and 2010 exclude amounts related to Mid-Valley and West Texas Gulf from the dates of the Partnership's acquisition of its controlling financial interests in these joint ventures. Such amounts are included in the Partnership's consolidated financial statements.

The Partnership's investments in Yellowstone Pipe Line Company ("Yellowstone"), West Shore and Wolverine Pipe Line Company ("Wolverine") at December 31, 2011 include an excess investment amount of $54 million, net of accumulated amortization of $5 million. The excess investment is the difference between the investment balance and the Partnership's proportionate share of the net assets of the entities. During the years ended December 31, 2011, 2010 and 2009, the Partnership has not provided additional financial support to any of the joint ventures.

The Partnership had $22 million of undistributed earnings from its investments in corporate joint ventures within Equity at December 31, 2011. During the years ended December 31, 2011, 2010 and 2009 the Partnership received dividends of $11, $15 and $19 million, respectively, from its investments in corporate joint ventures.

The entire disclosure for equity investment, or group of investments, for which combined disclosure is appropriate, including: (a) the name of each investee and percentage of ownership of common stock, (b) accounting policies for investments in common stock, (c) difference between the amount at which the investment is carried and the amount of underlying equity in net assets and the accounting treatment of the difference, (d) the total fair value of each identified investment for which a market value is available, (e) summarized information as to assets, liabilities, and results of operations of the investees (for investments in unconsolidated subsidiaries, common stock of joint ventures, or other investments using the equity method), and (f) material effects of possible conversions, exercises, or contingent issuances of the investee. Other disclosures include (a) the names of any investee in which the investor owns 20 percent or more of the voting stock and investment is not accounted for using the equity method, and the reasons why not, and (b) the names of any investee in which the investor owns less than 20 percent of the voting stock and the investment is accounted for using the equity method, and the reasons why it is.

Goodwill And Other Intangible Assets [Abstract]

Goodwill And Other Intangible Assets

12 Months Ended

Dec. 31, 2011

Goodwill And Other Intangible Assets

8. Goodwill and Other Intangible Assets

Goodwill

Goodwill represents the excess of consideration transferred plus the fair value of noncontrolling interest of an acquired business over the fair value of net assets acquired. Goodwill is not amortized; however it is subject to at least an annual impairment testing. The Partnership's goodwill balance at December 31, 2011 was $77 million compared to $63 million at December 31, 2010. The $14 million increase in goodwill relates to the acquisition of a crude oil acquisition and marketing business in August 2011. The Partnership's goodwill balance increased to $63 million at December 31, 2010 from $16 million at December 31, 2009, due to goodwill recognized as part of the acquisition of a butane blending business in July 2010.

Identifiable Intangible Assets

The Partnership's identifiable intangible assets are comprised of customer relationships, which consist of throughput contracts and historical shipping rights, and technology related assets, which consist of patented technology associated with the Partnership's butane blending services. The values assigned to these intangible assets are amortized to earnings using a straight-line approach, over a weighted-average amortization period of approximately 11 years. Amortization expense related to these intangibles was $15, $4 and less than $1 million for the years ended December 31, 2011, 2010 and 2009, respectively.

Customer relationship intangible assets represent the estimated economic value assigned to certain relationships acquired in connection with business combinations or asset purchases whereby (i) the Partnership acquired information about or access to customers, (ii) the customers now have the ability to transact business with the Partnership and (iii) the Partnership is positioned due to limited competition to provide products or services to the customers. Technology-related intangible assets are the Partnership's patents for blending of butane into refined products. These patents are amortized over their remaining legal lives.


	Weighted Average		December 31,
	Amortization Period		2011			2010
			(in millions)
Gross
Customer relationships		11	$	239		$	56
Technology		14		58			58

Total gross			$	297		$	114

Accumulated amortization
Customer relationships			$	(14	)	$	(3	)
Technology				(6	)		(2	)

Total accumulated amortization			$	(20	)	$	(5	)

Total Net			$	277		$	109

As of December 31, 2011, the Partnership forecasts $26 million of annual amortization expense for each year through the year 2016 for these intangible assets.

Intangible assets attributable to rights of way are included in the properties, plants and equipment in the Partnership's consolidated balance sheets at December 31, 2011 and December 31, 2010.

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

Debt

12 Months Ended

Dec. 31, 2011

Debt [Abstract]

Debt

9. Debt

The components of the Partnership's long-term debt balances are as follows:


	December 31,
	2011			2010
	(in millions)
Affiliated Companies
Promissory note, due May 2013	$	—		$	100

Credit Facilities
$63 million Credit Facility, terminated August 2011	$	—		$	31

Senior Notes
Senior Notes—7.25%, due February 2012	$	250		$	250
Senior Notes—8.75%, due February 2014		175			175
Senior Notes—6.125%, due May 2016		175			175
Senior Notes—5.50%, due February 2020		250			250
Senior Notes—4.65%, due February 2022		300			—
Senior Notes—6.85%, due February 2040		250			250
Senior Notes—6.10%, due February 2042		300			—

		1,700			1,100
Less:
Unamortized bond discount		(2	)		(2	)
Current portion of long-term debt		(250	)		—

Long-term debt	$	1,448		$	1,129

The aggregate amount of long-term debt maturities is as follows:


Year Ended December 31,	(in millions)
2012	$	250
2013		—
2014		175
2015		—
2016		175
Thereafter		1,100

Total	$	1,700

Cash payments for interest related to long-term debt, net of capitalized interest (see Note 1), were $73, $59 and $37 million in 2011, 2010 and 2009, respectively.

Promissory Note, Affiliated Companies

During the third quarter of 2010, the Operating Partnership entered into a subordinated $100 million variable rate promissory note due to Sunoco in May 2013. The note bore interest at three-month LIBOR plus 275 basis points per annum. The proceeds from this note were used to fund a portion of the purchase price of the Partnership's acquisition of a butane blending business in July 2010. The Partnership repaid this note in full during the fourth quarter 2011.

Credit Facilities

In August 2011, the Partnership replaced its existing $458 million of credit facilities with two new credit facilities totaling $550 million. The prior credit facilities consisted of a five-year $395 million credit facility and a $63 million revolving credit facility, which were collectively 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 new credit facilities consist of a five-year $350 million unsecured credit facility (the "$350 million Credit Facility") and a $200 million 364 day unsecured credit facility (the "$200 million Credit Facility"). As of December 31, 2011, there were no outstanding borrowings under the credit facilities.

The $350 million Credit Facility, which matures in August 2016, is available to fund the Operating Partnership's working capital requirements, to finance acquisitions, to finance capital projects and for general partnership purposes. The $350 million Credit Facility bears interest at LIBOR or the Base Rate (defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the Citibank prime rate or (c) LIBOR plus an applicable margin) or the Federal Funds Rate (each plus an applicable margin). The $200 million Credit Facility, entered into by Sunoco Partners Marketing & Terminals LP (a wholly-owned subsidiary of the Partnership), is available to fund certain inventory activities. The $200 million Credit Facility matures in August 2012 and bears interest at LIBOR or the Base Rate (defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the Citibank prime rate or (c) LIBOR plus an applicable margin) (each plus an applicable margin). The credit facilities may be prepaid at any time.

The credit facilities contains various covenants limiting the 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; or enter into a merger or sale of assets, including the sale or transfer of interests in the Operating Partnership's subsidiaries. The credit facilities also limit the Partnership, on a rolling four-quarter basis, to a maximum total consolidated debt to consolidated Adjusted EBITDA, as defined in the underlying credit agreement, ratio of 5.00 to 1, which can generally be increased to 5.50 to 1 during an acquisition period. The Partnership's ratio of total debt to Adjusted EBITDA was 3.13 to 1 at December 31, 2011, as calculated in accordance with the bank covenants.

Senior Notes

The Operating Partnership had $250 million of 7.25 percent Senior Notes which matured and were repaid in February 2012.

In July 2011 the Operating Partnership issued $300 million of 4.65 percent Senior Notes and $300 million of 6.10 percent Senior Notes (the "2022 and 2042 Senior Notes"), due February 2022 and February 2042, respectively. The net proceeds of $595 million from the 2022 and 2042 Senior Notes were used to pay down outstanding borrowings under the prior $63 and $395 million revolving credit facilities, which were used to fund the acquisitions of a controlling financial interest in Inland and the Texon crude oil acquisition and marketing business, and for general partnership purposes.

In February 2010, the Operating Partnership issued $250 million of 5.50 percent Senior Notes and $250 million of 6.85 percent Senior Notes, due February 15, 2020 and February 15, 2040, respectively. The net proceeds of $494 million from the 2020 and 2040 Senior Notes, were used to repay the $201 million promissory note issued in connection with the Partnership's repurchase and exchange of its IDR interest, repay outstanding borrowings under the prior credit facility and for general partnership purposes.

In February 2009, the Operating Partnership issued $175 million of 8.75 percent Senior Notes, due February 15, 2014. The net proceeds of $173 million from the 2014 Senior Notes, were used to repay outstanding borrowings under the prior credit facility.

Debt Guarantee

The Partnership currently serves as guarantor of the Senior Notes and of any obligations under the $350 million and $200 million Credit Facilities. The Operating Partnership is also a guarantor of the $200 million Credit Facility. These guarantees are full and unconditional. See Note 19 for supplemental condensed consolidating financial information.

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

Commitments And Contingent Liabilities [Abstract]

Commitments And Contingent Liabilities

12 Months Ended

Dec. 31, 2011

Commitments And Contingent Liabilities

10. Commitments and Contingent Liabilities

Total rental expense for 2011, 2010 and 2009 amounted to $10, $8 and $7 million, respectively. The Partnership, as lessee, has non-cancelable operating leases for office space and equipment for which the aggregate amount of future minimum annual rentals as of December 31, 2011 is as follows:


	Year Ended December 31,
	(in millions)
2012	$	6
2013		4
2014		4
2015		3
2016		1
Thereafter		2

Total	$	20

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 December 31, 2011 and 2010, there were accrued liabilities for environmental remediation in the consolidated balance sheets of $4 million. The accrued liabilities for environmental remediation do not include any amounts attributable to unasserted claims, since no unasserted claims are probable of settlement or reasonably estimable, nor have any recoveries from insurance been assumed. Charges against income for environmental remediation totaled $5, $3 and $3 million for the years ended December 31, 2011, 2010 and 2009, 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. Management believes it is reasonably possible that additional environmental remediation losses will be incurred. At December 31, 2011, the aggregate of the estimated maximum additional reasonably possible losses, which relate to numerous individual sites, totaled $2 million. However, the Partnership believes it is unlikely that it will realize the maximum reasonably possible loss at every site. Furthermore, the recognition of additional losses, if and when they were to occur, would likely extend over many years and therefore, likely would not have a material impact on the Partnership's results of operations, financial position or expected cash flows.

The Partnership is a party to certain pending and threatened claims. Although the ultimate outcome of these claims cannot be ascertained at this time nor can a range of reasonably possible losses be determined, 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 Partnership's results of operations, financial position or cash flows at December 31, 2011. 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 arose from the operation of such assets prior to the closing of the February 2002 initial public offering ("IPO"). Sunoco has indemnified the Partnership for 100 percent of all losses asserted within the first 21 years of closing of the 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 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 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 arose out of Sunoco's ownership and operation of the assets prior to the closing of the IPO and that are asserted within 10 years after closing of the 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 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 operations, cash flows or financial position of the Partnership at December 31, 2011. There are certain other pending legal proceedings related to matters arising after the 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 operations, cash flows or financial position of the Partnership at December 31, 2011.

The entire disclosure for commitments and contingencies.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 14
-Paragraph 3
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9, 10, 11, 12
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.25)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 450
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6952336&loc=d3e14435-108349

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 440
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6394976&loc=d3e25287-109308

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6449706&loc=d3e16207-108621

Equity Offerings	12 Months Ended
Equity Offerings	Dec. 31, 2011
Equity Offerings [Abstract]
Equity Offerings	11. Equity Offerings On December 2, 2011, the Partnership completed a three-for-one split of its common and Class A units. The unit split resulted in the issuance of two additional common and Class A units for every one common unit owned. All unit and per unit information included in this report are presented on a post-split basis. In July 2011, the Partnership issued an aggregate 3.9 million Class A units to the General Partner as part of the consideration paid for the acquisition of the Eagle Point tank farm from Sunoco. The Class A units are a new class of limited partner interests in the Partnership, which are not entitled to receive quarterly distributions that are made on the Partnership's common units, but are otherwise entitled to share in earnings pro rata with the common units. The Class A units will automatically convert to common units on a one-to-one basis, one year from the date of issuance. Under GAAP, the Partnership recorded the Class A units at $20 million, the difference between Sunoco's historical carrying value of the assets acquired and the cash paid by the Partnership. In connection with this transaction, the general partner contributed $2 million to the Partnership to maintain its 2 percent general partner interest. In August 2010, the Partnership completed a public offering of 6.0 million common units. Net proceeds of $143 million were used to fund the acquisition of additional interests in three of the Partnership's joint venture pipelines and to reduce outstanding borrowings under the Operating Partnership's prior $395 million Credit Facility. In connection with this offering, the general partner contributed $3 million to the Partnership to maintain its 2 percent general partner interest. In April and May 2009, the Partnership completed a public offering of 6.7 million common units. Net proceeds of $110 million were used to reduce outstanding borrowings under the Partnership's prior credit facility and for general partnership purposes. In connection with these offerings, the general partner contributed $2 million to the Partnership to maintain its 2 percent general partner interest.

The entire disclosure for the formation, structure, control and ownership of the partnership. Disclosures related to accounts comprising partners' capital. Includes balances of general partners' capital account, limited partners' capital account, preferred partners' capital account and total partners' capital account and units outstanding; accumulated other comprehensive income; amount and nature of changes to amount of partner's capital and units outstanding by class, rights and privileges for each class of units; distribution policies and distributions paid by unit class; impact of and correction of an error in previously issued financial statements; limitations of partners' liability; redemption, conversion and distribution policies; and deferred compensation related to the issuance of units.

Management Incentive Plan [Abstract]

Cash Distributions

12 Months Ended

Dec. 31, 2011

Cash Distributions [Abstract]

Cash Distributions

12. 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.

If cash distributions exceed $0.1667 per unit in a quarter, the general partner receives increasing percentages, up to 50 percent, of the cash distributed in excess of that amount. These distributions are referred to as "incentive distributions." The percentage interests shown for the unitholders and the general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution.

In January 2010, the Partnership repurchased, and its general partner transferred and assigned to the Partnership for cancellation, the IDRs held by the general partner under the Second Amended and Restated Agreement of Limited Partnership, as amended, in consideration for (i) the issuance to the general partner of new IDRs issued under the Third Amended and Restated Agreement of Limited Partnership and (ii) the issuance to the general partner of a promissory note in the principal amount of $201 million. In February 2010, the Operating Partnership issued a total of $500 million in senior notes which mature in February 2020 and February 2040. A portion of the net proceeds from this offering was used to repay in full this promissory note.

The following table compares the target distribution levels and distribution "splits" between the general partner and the holders of the Partnership's common units under the cancelled IDRs and under the new IDRs:


	Cancelled IDRs								New IDRs
	Total Quarterly Distribution Target Amount		Marginal Percentage Interest in Distributions						Total Quarterly Distribution Target Amount		Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount		General Partner			Unitholders			Total Quarterly Distribution Target Amount		General Partner			Unitholders
Minimum Quarterly Distribution	$	0.1500		2	%		98	%
First Target Distribution		up to $0.1667		2	%		98	%				No change
Second Target Distribution		above $0.1667 up to $0.1917		15	%*		85	%
Third Target Distribution		above $0.1917 up to $0.2333		25	%*		75	%		above $0.1917 up to $0.5275		37	%*		63	%
Thereafter		above $0.2333		50	%*		50	%		above $0.5275		50	%*		50	%

*	Includes 2 percent general partner interest.

Distributions paid by the Partnership during the years ended December 31, 2011, 2010 and 2009 were as follows:


Cash Distribution Payment Date	Cash Distribution per Limited Partner Unit		Annualized Cash Distribution per Limited Partner Unit		Total Cash Distribution to the Limited Partners		Total Cash Distribution to the General Partner
					(in millions)		(in millions)
November 14, 2011	$	0.4133	$	1.6532	$	41	$	13
August 12, 2011	$	0.4050	$	1.6200	$	40	$	13
May 13, 2011	$	0.3983	$	1.5932	$	40	$	12
February 14, 2011	$	0.3933	$	1.5732	$	39	$	12

November 12, 2010	$	0.3900	$	1.5600	$	39	$	12
August 13, 2010	$	0.3800	$	1.5200	$	35	$	11
May 14, 2010	$	0.3717	$	1.4867	$	35	$	10
February 12, 2010	$	0.3633	$	1.4533	$	34	$	14

November 14, 2009	$	0.3550	$	1.4200	$	33	$	13
August 14, 2009	$	0.3467	$	1.3867	$	32	$	13
May 15, 2009	$	0.3383	$	1.3533	$	31	$	12
February 14, 2009	$	0.3300	$	1.3200	$	29	$	10

On January 26, 2012, the Partnership declared a cash distribution of $0.42 per unit ($1.68 per unit annualized) on its outstanding common units, representing the distribution for the quarter ended December 31, 2011. The $55 million distribution, including $14 million to the general partner, was paid on February 14, 2012 to unitholders of record at the close of business on February 8, 2012.

Management Incentive Plan

12 Months Ended

Dec. 31, 2011

Management Incentive Plan

13. Management Incentive Plan

Sunoco Partners LLC, the general partner of the Partnership, has adopted 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 partner's 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 additional 0.8 million common units.

Restricted Units

A restricted unit entitles the grantee to receive a common unit or, at the discretion of the Compensation Committee, an amount of cash equivalent to the value of a common unit upon the vesting of the unit, which may include the attainment of predetermined performance targets. The Compensation Committee may make additional grants under the LTIP to employees and directors containing such terms as the Compensation Committee shall determine. Common units to be delivered to the grantee upon vesting may be common units acquired by the general partner in the open market, common units already owned by the general partner, common units acquired by the general partner directly from the Partnership or any other person, or any combination of the foregoing. The general partner will be entitled to reimbursement by the Partnership for the cost incurred in acquiring common units. If the Partnership issues new common units upon vesting of the restricted units, the total number of common units outstanding will increase.

The Compensation Committee, in its discretion, may grant tandem distribution equivalent rights ("DERs") with respect to the restricted units. Subject to applicable vesting criteria, DERs entitle the grantee to receive an amount of cash equal to the per unit cash distributions made by the Partnership during the period the restricted unit is outstanding. During the years ended December 31, 2011, 2010 and 2009, the Partnership granted 189,714, 272,427 and 299,403 restricted units, respectively, which included tandem DERs. Although some of these awards are time-vested only, most are subject to the Partnership achieving certain market-based and cash distribution performance targets as compared to a peer group average or certain cash distribution performance targets as defined by the Compensation Committee, which can cause the actual amount of units that ultimately vest to range from between 0 to 200 percent of the original units granted. These restricted unit awards generally vest over a three-year period.

The following table summarizes information regarding restricted unit award activity during the three years ended December 31, 2011:

Restricted Unit Activity


	Number of Units			Weighted Average Grant- Date Fair Value
Granted, non-vested and outstanding, December 31, 2008		402,408		$	18.33
Granted⁽¹⁾		299,403		$	19.92
Performance Factor adjustment		149,286		$	18.68
Vested		(322,725	)	$	18.75
Cancelled/forfeited		(60,387	)	$	18.61

Granted, non-vested and outstanding, December 31, 2009		467,985		$	19.13

Granted⁽¹⁾		272,427		$	24.87
Performance Factor adjustment		131,760		$	17.65
Vested		(326,130	)	$	14.41
Cancelled/forfeited		(101,949	)	$	20.92

Granted, non-vested and outstanding, December 31, 2010		444,093		$	22.59

Granted⁽¹⁾		189,714		$	31.13
Performance Factor adjustment		184,113		$	19.88
Vested		(449,055	)	$	19.87
Cancelled/forfeited		(23,010	)	$	27.66

Granted, non-vested and outstanding, December 31, 2011		345,855		$	28.17

⁽¹⁾

Of the total number of restricted units granted, the portion that represents units that are subject to performance factors may ultimately be issued at 0 to 200 percent of the original grant, based on the Partnership's achievement of performance goals for total shareholder return and cash distributions relative to a selected peer group of competitors.

The total fair value of restricted unit awards vested during the years ended December 31, 2011, 2010 and 2009 was $18, $9, and $7 million, respectively. As of December 31, 2011 estimated compensation cost related to non-vested awards not yet recognized was $4 million, and the weighted-average period over which this cost is expected to be recognized in expense is 1.8 years. The number of restricted stock units outstanding and the total compensation cost related to non-vested awards not yet recognized reflects the Partnership's estimates of performance factors for certain restricted unit awards.

The estimated fair value of restricted units under the LTIP is determined based upon the nature of the award. For performance-based awards, the fair value is determined using the grant date market price of the Partnership's common units. For market-based awards, the fair value is determined using a Monte Carlo simulation.

The Partnership recognizes compensation expense on a straight-line basis over the requisite service period, and estimates forfeitures over the requisite service period when recognizing compensation expense.

The following table summarizes the fair value assumptions associated with the performance based awards:


	Year Ended December 31,
	2011		2010		2009
Expected unit-price volatility		24.6%		25.9%		29.1%
Distribution yield		5.4%		6.4%		7.4%
Risk-free interest rate		1.0%		1.6%		1.3%
Weighted average fair value of performance units granted during the year	$	31.51	$	25.16	$	19.92

Expected unit-price volatility is based on the daily historical volatility of the Partnership's common units, generally for the three years prior to the grant date. The distribution yield represents the Partnership's annualized distribution yield on the average closing price of the Partnership's common units 30 days prior to the date of grant. The risk-free interest rate is based on the zero-coupon U.S. Treasury bond, with a term equal to the remaining contractual term of the restricted unit awards.

The Partnership recognized unit-based compensation expense within selling, general and administrative expenses on the consolidated statements of income related to the LTIP of $6, $5 and $5 million in the years ended December 31, 2011, 2010 and 2009 respectively, related to the unit grants and performance factor adjustments noted in the table above. Each of the restricted unit grants also have tandem DERs which are recognized as a reduction of Equity when earned.

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 123R
-Paragraph 64, 65, A240
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 93-6
-Paragraph 53
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 14

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 50
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6406099&loc=d3e25284-112666

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5047-113901

Reference 6: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5070-113901

Reference 7: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
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-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5444-113901

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-Name Accounting Standards Codification
-Topic 718
-SubTopic 40
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6418621&loc=d3e17540-113929

Derivatives And Risk Management [Abstract]

Derivatives And Risk Management

12 Months Ended

Dec. 31, 2011

Derivatives And Risk Management

14. Derivatives and Risk Management

The Partnership is exposed to various market risks, including volatility in crude oil and refined product prices and interest rates. In order to manage such exposure, the Partnership's policy is (i) to only purchase crude oil and refined products for which sales contracts have been executed or for which ready markets exist, (ii) to structure sales contracts so that price fluctuations do not materially impact the margins earned, and (iii) not to acquire and hold physical inventory, futures contracts or other derivative instruments for the purpose of speculating on commodity price changes. Although the Partnership seeks to maintain a balanced inventory position within its commodity inventories, net unbalances may occur for short periods of time due to production, transportation and delivery variances. When physical inventory builds or draws do occur, the Partnership continuously manages the variance to a balanced position over a period of time. Pursuant to the Partnership's approved risk management policy, derivative contracts may be used to hedge or reduce exposure to price risk associated with acquired inventory or forecasted physical transactions.

Price Risk Management

The Partnership is exposed to risks associated with changes in the market price of crude oil and refined products as a result of the forecasted purchase or sale of these products. These risks are primarily associated with price volatility related to pre-existing or anticipated purchases, sales and storage. Price changes are often caused by shifts in the supply and demand for these commodities, as well as their locations. The physical contracts related to the Partnership's crude oil and refined products businesses that qualify as derivatives have been designated as normal purchases and sales and are accounted for using traditional accrual accounting. The Partnership accounts for derivatives that do not qualify as normal purchases and sales at fair value. The Partnership does not utilize derivative instruments to manage its exposure to prices related to crude oil purchase and sale activities. The Partnership does utilize derivatives such as swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products. These derivative contracts act as a hedging mechanism against the volatility of prices by allowing the Partnership to transfer this price risk to counterparties who are able and willing to bear it.

While all derivative instruments utilized by the Partnership represent economic hedges, certain of these derivatives are not designated as hedges for accounting purposes. Such derivatives include certain contracts that were entered into and closed during the same accounting period.

For refined products derivative contracts that are not designated as hedges for accounting purposes, all realized and unrealized gains and losses are recognized in the consolidated statement of income during the current period. For refined products derivative contracts that are designated and qualify as cash flow hedges pursuant to GAAP, the portion of the gain or loss on the derivative contract that is effective in offsetting the variable cash flows associated with the hedged forecasted transaction is reported as a component of other comprehensive income and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. The remaining gain or loss on the derivative contract in excess of the cumulative change in the present value of future cash flows of the hedged item, if any (i.e., the ineffective portion), is recognized in earnings during the current period. All realized gains and losses associated with refined product derivative contracts are recorded in earnings in the same line item associated with the forecasted transaction, either sales and other operating revenue or cost of products sold and operating expenses.

The Partnership had open derivative positions of 1.5 million barrels and 0.7 million barrels of refined products at December 31, 2011 and 2010, respectively. The derivatives outstanding at December 31, 2011 vary in duration but do not extend beyond one year. The Partnership records its derivatives at fair value based on observable market prices (levels 1 and 2). As of December 31, 2011 and 2010, the fair values of the Partnership's derivative assets and liabilities were:


	2011			2010
	(in millions)
Derivative assets	$	6		$	2
Derivative liabilities		(2	)		(6	)

	$	4		$	(4	)

Derivative asset and liability balances are recorded in accounts receivable and accrued liabilities, respectively, in the accompanying consolidated balance sheets. The Partnership had no commodity-related derivative activities during the year ended December 31, 2009.

The Partnership's derivative positions are comprised primarily of commodity contracts. The following tables set forth the impact of derivatives on the Partnership's financial performance for the years ended December 31, 2011 and 2010:


	Pretax Gains (Losses) Recognized in Other Comprehensive Income		Pretax Gains (Losses) Recognized in Earnings			Location of Gains (Losses) Recognized in Earnings
	(in million)
Year Ended December 31, 2011
Derivatives designated as cash flow hedging instruments:
Commodity contracts	$	4	$	(1	)	Sales and other operating revenue
Commodity contracts		—		2		Cost of product sold and operating expenses

	$	4	$	1

Derivatives not designated as hedging instruments:
Commodity contracts			$	6		Sales and other operating revenue
Commodity contracts				(1	)	Cost of product sold and operating expenses

			$	5

Year Ended December 31, 2010
Derivatives designated as cash flow hedging instruments:
Commodity contracts	$	—	$	—		Sales and other operating revenue
Commodity contracts		—		—		Cost of product sold and operating expenses

	$	—	$	—

Derivatives not designated as hedging instruments:
Commodity contracts			$	(1	)	Sales and other operating revenue
Commodity contracts				—		Cost of product sold and operating expenses

			$	(1	)

Credit Risks

The Partnership faces counterparty credit risk as a result of its use of financial derivative contracts. The Partnership's counterparties consist primarily of financial institutions and major integrated oil companies. This concentration of counterparties may impact the Partnership's overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.

The Partnership maintains credit policies with regard to its counterparties that management believes minimize the overall credit risk. The Partnership's customers' credit positions are analyzed prior to the extension of credit, and periodically after the credit has been extended. The Partnership manages its exposure to derivative counterparty credit risk through credit analysis, credit approvals, credit limits, and monitoring procedures.

The Partnership's over-the-counter derivatives are entered into with counterparties outside of organized exchanges. While management actively monitors the risk associated with entering into such transactions, it is possible that losses can result from counterparty credit risk in the future. At December 31, 2011, the Partnership did not hold any over-the-counter derivative and at December 31, 2010, the potential exposure to credit losses on over-the-counter derivatives was immaterial.

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6887037&loc=d3e80784-113994

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-Name Accounting Standards Codification
-Topic 815
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-Name Accounting Standards Codification
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-Paragraph 4B
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-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
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Reference 17: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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Reference 18: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5708775-113959

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41635-113959

Reference 20: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 21: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5708773-113959

Reference 22: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2011
Fair Value Measurements [Abstract]
Fair Value Measurements	15. Fair Value Measurements The estimated fair value of financial instruments has been determined based on the Partnership's assessment of available market information and appropriate valuation methodologies. The Partnership's current assets (other than derivatives and inventories) and current liabilities are financial instruments and most of these items are recorded at cost in the consolidated balance sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. The Partnership's derivatives are measured and recorded at fair value based on observable market prices (Note 14). The estimated fair value of the Senior Notes is determined using observable market prices, as these notes are actively traded. The estimated aggregate fair value of the Senior Notes at December 31, 2011 is $1.91 billion, compared to the carrying amount of $1.70 billion. The estimated aggregate fair value of the Senior Notes at December 31, 2010 was $1.25 billion, compared to the carrying amount of $1.10 billion.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44A, 44B
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15C, 15D
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-Subparagraph a-d
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15B
-Subparagraph a, b
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 3, 10, 14, 15
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32, 33, 34
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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 17-22, 27, 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

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-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

Reference 11: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Paragraph 5
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Concentration Of Credit Risk	12 Months Ended
Concentration Of Credit Risk	Dec. 31, 2011
Concentration Of Credit Risk [Abstract]
Concentration Of Credit Risk	16. Concentration of Credit Risk Of the total revenue recognized by the Partnership during 2011, 4 percent was derived from Sunoco. The Partnership sells refined products to Sunoco, transports refined products to/from Sunoco's refineries and provides terminalling and storage services for Sunoco. The Partnership does not believe that the transactions with Sunoco expose it to significant credit risk. The Partnership's other trade relationships are primarily with major integrated oil companies, independent oil companies and other pipelines and wholesalers. These concentrations of customers may affect the Partnership's overall credit risk in that the customers (including Sunoco) may be similarly affected by changes in economic, regulatory or other factors. The Partnership's customers' credit positions are analyzed prior to extending credit and periodically after the credit has been extended. The Partnership manages its exposure to credit risk through credit analysis, credit approvals, credit limits, monitoring procedures and the utilization of netting agreements. For certain transactions the Partnership may utilize letters of credit, prepayments and guarantees.

The entire disclosure for any concentrations existing at the date of the financial statements that make an entity vulnerable to a reasonably possible, near-term, severe impact. This disclosure informs financial statement users about the general nature of the risk associated with the concentration, and may indicate the percentage of concentration risk as of the balance sheet date.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 94-6
-Paragraph 21, 22, 24
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
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Business Segment Information [Abstract]

Business Segment Information

12 Months Ended

Dec. 31, 2011

Business Segment Information

17. Business Segment Information

The Partnership operates in 29 states throughout the United States. During 2011, the Partnership realigned its reporting segments. The updated reporting segments are: Refined Products Pipelines, Terminal Facilities, Crude Oil Pipelines and Crude Oil Acquisition and Marketing. Prior to the realignment, the Partnership's Crude Oil Pipeline segment included its crude oil pipeline and crude oil acquisition and marketing operations. The Partnership has determined it is more meaningful to segregate these operations into different reporting segments given the growth in the crude oil acquisition and marketing business. For the purpose of comparability, all prior year segment disclosures have been recast to conform to the current year presentation. Such recasts have no impact on previously reported consolidated net income.

•

The Refined Products Pipelines serve Sunoco and other third parties and consists of approximately 2,500 miles of refined product pipelines, including a two-thirds undivided interest in the approximately 100-mile refined product Harbor pipeline and joint venture interests in four refined products pipelines in selected areas of the United States. The pipelines receive fees for transporting refined products from refineries to markets in the northeast, midwest and southwest United States and Canada.

•

The Terminal Facilities consist of 42 active refined product terminals with an aggregate storage capacity of 8 million barrels, which provide storage, terminalling, blending and other ancillary services and are primarily sourced by the Refined Products Pipelines; the Nederland Terminal, a 22 million barrel marine crude oil terminal on the Texas Gulf Coast; a 2 million barrel refined product terminal that previously served Sunoco's Marcus Hook refinery near Philadelphia, Pennsylvania; one inland and two marine crude oil terminals with a combined capacity of 3 million barrels, and related pipelines, which serve Sunoco's Philadelphia refinery; the Eagle Point Terminal, a 5 million barrel refined product and crude oil terminal and dock facility; and a 1 million barrel liquefied petroleum gas ("LPG") terminal near Detroit, Michigan. The terminals receive fees for the terminalling, blending and other services provided.

•

The Crude Oil Pipelines transport crude oil principally in Oklahoma and Texas. The segment consists of approximately 4,900 miles of crude oil trunk pipelines, including a 37 percent undivided interest in the approximately 100-mile Mesa Pipe Line system and approximately 500 miles of crude oil gathering lines that supply the trunk pipelines. The pipelines receive fees for transporting crude oil to and from trading hubs, other pipelines and refineries in the southwest and midwest United States.

•

The Crude Oil Acquisition and Marketing segment gathers, purchases, markets and sells crude oil principally in the mid-continent United States. The segment consists of approximately 170 crude oil transport trucks and approximately 110 crude oil truck unloading facilities.

The following tables sets forth condensed, consolidated statement of income information concerning the Partnership's recast business segments and reconciles total segment operating income to net income attributable to SXL for the years ended December 31, 2011, 2010 and 2009, respectively.


	Year ended December 31,
	2011			2010			2009
	(in millions)
Sales and other operating revenue⁽¹⁾
Refined Products Pipelines	$	130		$	120		$	128
Terminal Facilities		435			287			207
Crude Oil Pipelines		319			221			185
Crude Oil Acquisition and Marketing		10,163			7,282			4,990
Intersegment eliminations		(142	)		(102	)		(108	)

Total sales and other operating revenue	$	10,905		$	7,808		$	5,402

Depreciation and amortization
Refined Products Pipelines	$	17		$	15		$	13
Terminal Facilities		34			26			19
Crude Oil Pipelines		25			21			14
Crude Oil Acquisition and Marketing		10			2			2

Total depreciation and amortization	$	86		$	64		$	48

Impairment charge and related matters⁽²⁾
Terminal Facilities	$	42		$	3		$	—

Operating income
Refined Products Pipelines⁽³⁾	$	33		$	44		$	45
Terminal Facilities		85			95			84
Crude Oil Pipelines⁽⁴⁾		181			126			123
Crude Oil Acquisition and Marketing		137			36			43

Total operating income	$	436		$	301		$	295


	Year ended December 31,
	2011		2010		2009
	(in millions)
Net interest expense	$	89	$	73	$	45
Gain on investments in affiliates		—		128		—

Income before provision for income taxes		347		356		250
Provision for income taxes		25		8		—

Net Income		322		348		250
Net Income attributable to noncontrolling interests		9		2		—

Net Income Attributable to Sunoco Logistics Partners L.P.	$	313	$	346	$	250

⁽¹⁾	Sales and other operating revenue includes amounts from Sunoco for the years ended December 31, 2011, 2010 and 2009 of:


	2011		2010		2009
	(in millions)
Refined Products Pipelines	$	64	$	76	$	79
Terminal Facilities		115		122		100
Crude Oil Pipelines		6		25		25
Crude Oil Acquisition and Marketing		247		894		502

Total sales and other operating revenue from Sunoco	$	432	$	1,117	$	706

⁽²⁾

⁽³⁾	Operating income for the Refined Products Pipelines includes $12, $14 and $12 million for the years ended December 31, 2011, 2010 and 2009, respectively of equity income attributable to the Partnership's equity ownership interest in joint ventures.

⁽⁴⁾	Operating income for the Crude Oil Pipelines includes $12 and $13 million for the years ended December 31, 2010 and 2009, respectively of equity income attributable to the Partnership's equity ownership interest in joint ventures.

The following table provides condensed consolidated balance sheet information concerning the Partnership's recast business segments as of December 31, 2011, 2010 and 2009, respectively:


	Refined Products Pipelines		Terminal Facilities		Crude Oil Pipeline		Crude Oil Acquisition and Marketing		Total
	(in millions)
As of and for the year ended December 31, 2011
Capital expenditures⁽¹⁾	$	23	$	121	$	49	$	15	$	213
Investment in affiliates	$	73	$	-	$	-	$	-	$	73
Goodwill	$	8	$	53	$	2	$	14	$	77
Identifiable assets⁽²⁾	$	736	$	1,053	$	1,055	$	2,469	$	5,477

As of and for the year ended December 31, 2010
Capital expenditures⁽³⁾	$	17	$	110	$	36	$	2	$	174
Investment in affiliates	$	73	$	-	$	-	$	-	$	73
Goodwill	$	8	$	53	$	2	$	-	$	63
Identifiable assets⁽⁴⁾	$	531	$	857	$	1,018	$	1,695	$	4,188

As of and for the year ended December 31, 2009
Capital expenditures⁽⁵⁾	$	12	$	110	$	38	$	3	$	176
Investment in affiliates	$	27	$	-	$	61	$	-	$	88
Goodwill	$	8	$	6	$	2	$	-	$	16
Identifiable assets⁽⁶⁾	$	476	$	598	$	583	$	1,405	$	3,099

⁽¹⁾

Total capital expenditures exclude $396 million for the acquisition of a crude oil and marketing business, a refined products terminal in East Boston, an interest in the Inland refined products pipeline system and the Eagle Point tank farm and include $5 million of capital expenditures attributable to corporate activities.

⁽²⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $107 million advances to affiliates, $15 million deferred financing costs, and $40 million to properties, and plants and equipment, net.

⁽³⁾	Total capital expenditures exclude $252 million for the acquisition of the butane blending business, additional ownership interests in West Shore, Mid-Valley and West Texas Gulf, and two terminals and include $9 million of capital expenditures attributable to corporate activities.

⁽⁴⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $44 million advances to affiliates, $9 million deferred financing costs, and $32 million to properties, and plants and equipment, net.

⁽⁵⁾	Total capital expenditures exclude $50 million for the acquisitions of the Romulus refined products terminal and the Excel crude oil pipeline and include $13 million of capital expenditures attributable to corporate activities.

⁽⁶⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $9 million advances to affiliates, $4 million deferred financing costs, and $22 million to properties, plants and equipment, net.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 131
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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Quarterly Financial Data

12 Months Ended

Dec. 31, 2011

Quarterly Financial Data [Abstract]

Quarterly Financial Data

18. Quarterly Financial Data (Unaudited)

Summarized quarterly financial data is as follows:


	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per unit amounts)
2011
Sales and other operating revenue:
Affiliates	$	303		$	39		$	39		$	51
Unaffiliated customers	$	1,955		$	2,385		$	2,808		$	3,325
Gross margin⁽¹⁾	$	95		$	139		$	148		$	173
Operating income	$	75		$	121		$	128		$	112
Net Income⁽²⁾	$	50		$	96		$	97		$	79
Net Income attributable to noncontrolling interests		2			2			2			3

Net Income attributable to Sunoco Logistics Partners L.P.	$	48		$	94		$	95		$	76
Less: General Partner's interest		(12	)		(14	)		(14	)		(14	)

Limited Partners' interest	$	36		$	80		$	81		$	62

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.36		$	0.80		$	0.78		$	0.60
Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.36		$	0.80		$	0.78		$	0.60


	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per unit amounts)
2010
Sales and other operating revenue:
Affiliates	$	173		$	214		$	293		$	437
Unaffiliated customers	$	1,507		$	1,815		$	1,583		$	1,786
Gross margin ⁽¹⁾	$	71		$	76		$	98		$	101
Operating income	$	58		$	70		$	90		$	83
Net Income⁽³⁾	$	43		$	51		$	194		$	60
Net Income attributable to noncontrolling interests		—			—			1			1

Net Income attributable to Sunoco Logistics Partners L.P.	$	43		$	51		$	193		$	59
Less: General Partner's interest		(10	)		(11	)		(15	)		(12	)

Limited Partners' interest	$	33		$	40		$	178		$	47

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.35		$	0.43		$	1.87		$	0.47
Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.35		$	0.43		$	1.86		$	0.47

⁽¹⁾	Gross margin equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.

⁽²⁾

Net income for the fourth quarter 2011 includes a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge is comprised of a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.

⁽³⁾	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.

The entire disclosure for the quarterly financial data in the annual financial statements. The disclosure may include a tabular presentation of financial information for each fiscal quarter for the current and previous year, including revenues, gross profit, income or loss before extraordinary items and earnings per share data. It also includes an indication if the information in the note is unaudited, comments on the aggregate effect of year-end adjustments, and an explanation of matters or transactions that affect comparability or are pertinent to an understanding of the information furnished.

Supplemental Condensed Consolidating Financial Information [Abstract]

Supplemental Condensed Consolidating Financial Information

12 Months Ended

Dec. 31, 2011

Supplemental Condensed Consolidating Financial Information

19. Supplemental Condensed Consolidating Financial Information

The Partnership serves as guarantor of the Senior Notes. These guarantees are full and unconditional. For purposes of the following footnote, Sunoco Logistics Partners L.P. is referred to as "Parent Guarantor" and Sunoco Logistics Partners Operations L.P. is referred to as "Subsidiary Issuer." All other consolidated subsidiaries of the Partnership are collectively referred to as "Non-Guarantor Subsidiaries."

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

Consolidated Statement of Income

Year Ended December 31, 2011

(in millions)


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	432	$	—		$	432
Unaffiliated customers		—		—			10,473		—			10,473
Equity in earnings of subsidiaries		313		399			—		(712	)		—
Other income		—		—			13		—			13

Total Revenues		313		399			10,918		(712	)		10,918

Costs and Expenses
Cost of products sold and operating expenses		—		—			10,264		—			10,264
Depreciation and amortization expense		—		—			86		—			86
Impairment charge and related matters		—		—			42		—			42
Selling, general and administrative expenses		—		—			90		—			90

Total Costs and Expenses		—		—			10,482		—			10,482

Operating Income		313		399			436		(712	)		436
Net interest cost to affiliates		—		—			3		—			3
Other interest cost and debt expense, net		—		93			—		—			93
Capitalized interest		—		(7	)		—		—			(7	)

Income Before Provision for Income Taxes		313		313			433		(712	)		347
Provision for income taxes							25					25

Net Income		313		313			408		(712	)		322
Net Income attributable to noncontrolling interests		—		—			9		—			9

Net Income attributable to Sunoco Logistics Partners L.P.	$	313	$	313		$	399	$	(712	)	$	313

Consolidated Statement of Income

Year Ended December 31, 2010

(in millions)


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	1,117	$	—		$	1,117
Unaffiliated customers		—		—			6,691		—			6,691
Equity in earnings of subsidiaries		346		416			—		(762	)		—
Other income		—		—			30		—			30

Total Revenues		346		416			7,838		(762	)		7,838

Costs and Expenses
Cost of products sold and operating expenses		—		—			7,398		—			7,398
Depreciation and amortization expense		—		—			64		—			64
Impairment charge		—		—			3		—			3
Selling, general and administrative expenses		—		—			72		—			72

Total Costs and Expenses		—		—			7,537		—			7,537

Operating Income		346		416			301		(762	)		301
Net interest cost to affiliates		—		(1	)		3		—			2
Other interest cost and debt expense, net		—		76			—		—			76
Capitalized interest		—		(5	)		—		—			(5	)
Gain on investments in affiliates		—		—			128		—			128

Income Before Provision for Income Taxes		346		346			426		(762	)		356
Provision for income taxes		—		—			8		—			8

Net Income		346		346			418		(762	)		348
Net Income attributable to noncontrolling interests		—		—			2		—			2

Net Income attributable to Sunoco Logistics Partners L.P.	$	346	$	346		$	416	$	(762	)	$	346

Consolidated Statement of Income

Year Ended December 31, 2009

(in millions)


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	706	$	—		$	706
Unaffiliated customers		—		—			4,696		—			4,696
Equity in earnings of subsidiaries		250		292			—		(542	)		—
Other income		—		—			28		—			28

Total Revenues		250		292			5,430		(542	)		5,430

Costs and Expenses
Cost of products sold and operating expenses		—		—			5,023		—			5,023
Depreciation and amortization expense		—		—			48		—			48
Selling, general and administrative expenses		—		—			64		—			64

Total Costs and Expenses		—		—			5,135		—			5,135

Operating Income		250		292			295		(542	)		295
Net interest cost to affiliates		—		(3	)		3		—			—
Other interest cost and debt expense, net		—		49			—		—			49
Capitalized interest		—		(4	)		—		—			(4	)

Income Before Provision for Income Taxes		250		250			292		(542	)		250
Provision for income taxes		—		—			—		—			—

Net Income		250		250			292		(542	)		250
Net income attributable to noncontrolling interests		—		—			—		—			—

Net Income attributable to Sunoco Logistics Partners L.P.	$	250	$	250		$	292	$	(542	)	$	250

Consolidated Balance Sheet

December 31, 2011

(in millions)


	Parent Guarantor		Subsidiary Issuer		Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2	$	3		$	—		$	5
Advances to affiliated companies		90		48		(31	)		—			107
Accounts receivable, net		—		—		2,188			—			2,188
Inventories		—		—		206			—			206

Total Current Assets		90		50		2,366			—			2,506

Properties, plants and equipment, net		—		—		2,522			—			2,522
Investment in affiliates		1,007		2,680		73			(3,687	)		73
Goodwill		—		—		77			—			77
Intangible assets, net		—		—		277			—			277
Other assets		—		13		9			—			22

Total Assets	$	1,097	$	2,743	$	5,324		$	(3,687	)	$	5,477

Liabilities and Equity
Accounts payable		—		1		2,110			—			2,111
Current portion of long-term debt		—		250		—			—			250
Accrued liabilities		1		37		74			—			112
Accrued taxes payable		—		—		62			—			62

Total Current Liabilities		1		288		2,246			—			2,535

Long-term debt		—		1,448		—			—			1,448
Other deferred credits and liabilities		—		—		78			—			78
Deferred income taxes		—		—		222			—			222

Total Liabilities		1		1,736		2,546			—			4,283

Equity
Sunoco Logistics Partners L.P. equity		1,096		1,007		2,680			(3,687	)		1,096
Noncontrolling interests		—		—		98			—			98

Total Equity		1,096		1,007		2,778			(3,687	)		1,194

Total Liabilities and Equity	$	1,097	$	2,743	$	5,324		$	(3,687	)	$	5,477

Consolidated Balance Sheet

December 31, 2010

(in millions)


	Parent Guarantor		Subsidiary Issuer		Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2	$	—		$	—		$	2
Advances to affiliated companies		28		47		(31	)		—			44
Accounts receivable, affiliated companies		—		—		154			—			154
Accounts receivable, net		—		—		1,536			—			1,536
Inventories		—		—		63			—			63

Total Current Assets		28		49		1,722			—			1,799

Properties, plants and equipment, net		—		—		2,128			—			2,128
Investment in affiliates		937		2,135		73			(3,072	)		73
Goodwill		—		—		63			—			63
Intangible assets, net		—		—		109			—			109
Other assets		—		7		9			—			16

Total Assets	$	965	$	2,191	$	4,104		$	(3,072	)	$	4,188

Liabilities and Equity
Accounts payable	$	—	$	—	$	1,591					$	1,591
Accrued liabilities		—		25		51						76
Accrued taxes payable		—		—		44						44

Total Current Liabilities		—		25		1,686			—			1,711

Long-term debt, affiliated companies		—		100		—			—			100
Long-term debt		—		1,129		—			—			1,129
Other deferred credits and liabilities		—		—		42			—			42
Deferred income taxes		—		—		164			—			164

Total Liabilities		—		1,254		1,892			—			3,146

Equity
Sunoco Logistics Partners L.P. equity		965		937		2,135			(3,072	)		965
Noncontrolling interests		—		—		77			—			77

Total Equity		965		937		2,212			(3,072	)		1,042

Total Liabilities and Equity	$	965	$	2,191	$	4,104		$	(3,072	)	$	4,188

Consolidated Statement of Cash Flows

Year Ended December 31, 2011

(in millions)


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	313		$	322		$	508		$	(713	)	$	430

Cash Flows from Investing Activities:
Capital expenditures		—			—			(213	)		—			(213	)
Acquisitions		—			—			(396	)		—			(396	)
Intercompany		(35	)		(786	)		108			713			—

Net cash used in investing activities		(35	)		(786	)		(501	)		713			(609	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(210	)		—			—			—			(210	)
Distributions paid to noncontrolling interests		(8	)		—			—			—			(8	)
Contributions from general partner		2			—			—			—			2
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(3	)		—			(3	)
Repayments under credit facility		—			(560	)		—			—			(560	)
Borrowings under credit facility		—			529			—			—			529
Net proceeds from issuance of long term debt		—			595			—			—			595
Promissory note from affiliate		—			(100	)		—			—			(100	)
Advances to affiliates, net		(62	)		—			(1	)		—			(63	)

Net cash provided by financing activities		(278	)		464			(4	)		—			182

Net change in cash and cash equivalents		—			—			3			—			3
Cash and cash equivalents at beginning of year		—			2			—			—			2

Cash and cash equivalents at end of year	$	—		$	2		$	3		$	—		$	5

Consolidated Statement of Cash Flows

Year Ended December 31, 2010

(in millions)


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	346		$	366		$	391		$	(762	)	$	341

Cash Flows from Investing Activities:
Capital expenditures		—			—			(174	)		—			(174	)
Acquisitions		—			—			(252	)		—			(252	)
Intercompany		(79	)		(723	)		40			762			—

Net cash used in investing activities		(79	)		(723	)		(386	)		762			(426	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(189	)		—			—			—			(189	)
Distributions paid to noncontrolling interests		(4	)		—			—			—			(4	)
Net proceeds from issuance of limited partner units		143			—			—			—			143
Contributions from general partner		3			—			—			—			3
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(2	)		—			(2	)
Repayments under credit facility		—			(888	)		—			—			(888	)
Borrowings under credit facility		—			650			—			—			650
Net proceeds from issuance of long term debt		—			494			—			—			494
Promissory note from affiliate		—			100			—			—			100
Repayment of promissory note to general partner		(201	)		—			—			—			(201	)
Advances to affiliates, net		(19	)		1			(3	)		—			(21	)

Net cash provided by financing activities		(267	)		357			(5	)		—			85

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

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

Consolidated Statement of Cash Flows

Year Ended December 31, 2009

(in millions)


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	250		$	252		$	216		$	(542	)	$	176

Cash Flows from Investing Activities:
Capital expenditures		—			—			(176	)		—			(176	)
Acquisitions		—			—			(50	)		—			(50	)
Intercompany		(181	)		(371	)		10			542			—

Net cash used in investing activities		(181	)		(371	)		(216	)		542			(226	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(173	)		—			—			—			(173	)
Net proceeds from issuance of limited partner units		110			—			—			—			110
Contributions from general partner		2			—			—			—			2
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(2	)		—			(2	)
Repayments under credit facility		—			(687	)		—			—			(687	)
Borrowings under credit facility		—			633			—			—			633
Net proceeds from issuance of long term debt		—			173			—			—			173
Advances to affiliates, net		(8	)		—			2			—			(6	)

Net cash provided by financing activities		(69	)		119			—			—			50

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

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

Summary Of Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2011

Summary Of Significant Accounting Policies [Abstract]

Principles Of Consolidation

Principles of Consolidation

Reclassifications And Recasts

Reclassifications and Recasts

Use Of Estimates

Use of Estimates

Revenue Recognition

Revenue Recognition

Cash Equivalents

Cash Equivalents

Accounts Receivable, Net

Accounts Receivable, Net

Properties, Plants And Equipment

Inventories

Properties, Plants and Equipment

Capitalized Interest

Capitalized Interest

The Partnership capitalizes interest on borrowed funds related to capital projects for periods that construction activities are in progress to bring these projects to their intended use.

Investment In Affiliates

Investment in Affiliates

Impairment Of Long-Lived Assets

Acquisitions

The Partnership's asset acquisitions are recorded at the purchase price, which is allocated to the acquired assets and assumed liabilities based on their relative estimated fair values.

Impairment of Long-Lived Assets

Environmental Remediation

Goodwill

Intangible Assets

Intangible Assets

Environmental Remediation

Income Taxes

Income Taxes

For the years ended December 31, 2011 and 2010, income tax expense is comprised of:


	Year ended December 31,
	2011			2010
	(in millions)
Federal
Current	$	25		$	6
Deferred		(2	)		—
State
Current		2			2
Deferred		—			—

Total income tax expense	$	25		$	8

Long-Term Incentive Plan

Long-Term Incentive Plan

Asset Retirement Obligations

Asset Retirement Obligations

Fair Value Measurements

Fair Value Measurements

Comprehensive Income

Comprehensive Income

Lease Accounting

Lease Accounting

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit

Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit

Summary Of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2011

Summary Of Significant Accounting Policies [Abstract]

Components Of Income Tax Expense


	Year ended December 31,
	2011			2010
	(in millions)
Federal
Current	$	25		$	6
Deferred		(2	)		—
State
Current		2			2
Deferred		—			—

Total income tax expense	$	25		$	8

Acquisitions (Tables)

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Acquisitions [Abstract]

Schedule Of Effects Of The Acquisitions On The Partnership's Consolidated Balance Sheet


	East Boston Terminal			Crude Oil Acquisition and Marketing			Eagle Point Tank Farm			Inland			Total
	(in millions)
Increase in:
Current assets	$	17		$	24		$	—		$	3		$	44
Properties, plants & equipment, net		63			7			22			178			270
Intangible assets, net		—			183			—			—			183
Goodwill		—			14			—			—			14
Current liabilities		—			(6	)		—			(1	)		(7	)
Other deferred credits and liabilities		(7	)		—			—			(1	)		(8	)
Deferred income taxes		—			—			—			(60	)		(60	)
Sunoco Logistics Partners L.P. equity		—			—			(20	)		—			(20	)
Noncontrolling interests		—			—			—			(20	)		(20	)

Cash paid for acquisitions	$	73		$	222		$	2		$	99		$	396


	Butane Blending		Joint Ventures			Terminals			Total
	(in millions)
Increase in:
Current assets	$	14	$	23		$	—		$	37
Investment in affiliates		—		6			—			6
Properties, plants & equipment, net		1		471			10			482
Intangible assets, net		90		—			—			90
Goodwill		47		—			—			47
Deferred charges and other assets		—		1			—			1
Current liabilities		—		(4	)		—			(4	)
Other deferred credits and liabilities		—		(1	)		(1	)		(2	)
Deferred income taxes		—		(164	)		—			(164	)
Sunoco Logistics Partners L.P. equity		—		(128	)		—			(128	)
Noncontrolling interests		—		(80	)		—			(80	)
Decrease in:
Investment in affiliates		—		(33	)		—			(33	)

Cash paid for acquisitions	$	152	$	91		$	9		$	252


	Excel Pipeline LLC		Romulus Terminal		Total
	(in millions)
Increase in:
Properties, plants & equipment, net	$	11	$	18	$	29
Intangible assets, net		21		—		21

Cash paid for acquisitions	$	32	$	18	$	50

Tabular disclosure of a material business combination completed during the period, including background, timing, and recognized assets and liabilities. This table does not include leveraged buyouts.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 51
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 52
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 68
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Appendix F
-Paragraph F4
-Subparagraph e

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1392-128463

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1486-128463

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data [Abstract]

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data (Tables)

12 Months Ended

Dec. 31, 2011

Schedule Of Weighted Average Number Of Basic And Diluted Units


	2011		2010		2009
	(in millions)
Weighted average number of limited partner units outstanding—basic		101.3		95.2		91.0
Add effect of dilutive incentive awards		0.5		0.5		0.6

Weighted average number of limited partner units—diluted		101.8		95.7		91.6

Inventories (Tables)

12 Months Ended

Dec. 31, 2011

Inventories [Abstract]

Schedule Of Inventories


	December 31,
	2011		2010
	(in millions)
Crude oil	$	142	$	39
Refined products		55		16
Refined products additives		2		2
Materials, supplies and other		7		6

	$	206	$	63

Properties, Plants And Equipment (Tables)

12 Months Ended

Dec. 31, 2011

Properties, Plants And Equipment [Abstract]

Property, Plant And Equipment


	Estimated Useful Lives		December 31,
	Estimated Useful Lives		2011			2010
			(in millions)
Land and land improvements (including rights of way)		—	$	525		$	401
Pipeline and related assets		38 - 60		1,344			1,271
Terminals and storage facilities		5- 44		768			686
Other		5- 48		385			325
Construction-in-progress				212			116

Total properties, plants and equipment			$	3,234		$	2,799
Less: Accumulated depreciation and amortization				(712	)		(671	)

Total properties, plants and equipment, net			$	2,522		$	2,128

Investment In Affiliates (Tables)

12 Months Ended

Dec. 31, 2011

Ownership Percentages [Member]

Investment In Affiliates [Line Items]

Schedule Of Partnerships Ownership Percentages Not Holding Controlling Financial Interest


	Ownership percentage
Explorer Pipeline Company		9.4	%
Yellowstone Pipe Line Company		14.0	%
West Shore Pipe Line Company		17.1	%
Wolverine Pipe Line Company		31.5	%

Financial Highlights [Member]

Investment In Affiliates [Line Items]

Schedule Of Partnerships Ownership Percentages Not Holding Controlling Financial Interest


	2011		2010		2009
	(in millions)
Income Statement Data:⁽¹⁾
Total revenues	$	374	$	439	$	458
Income before income taxes	$	130	$	193	$	190
Net income	$	80	$	120	$	119


Balance Sheet Data (as of year-end):⁽¹⁾
Current assets	$	130	$	122	$	126
Non-current assets	$	648	$	646	$	680
Current liabilities	$	127	$	122	$	124
Non-current liabilities	$	549	$	546	$	568
Net equity	$	102	$	100	$	114

⁽ ¹⁾

Goodwill And Other Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2011

Goodwill And Other Intangible Assets [Abstract]

Identifiable Intangible Assets


	Weighted Average		December 31,
	Amortization Period		2011			2010
			(in millions)
Gross
Customer relationships		11	$	239		$	56
Technology		14		58			58

Total gross			$	297		$	114

Accumulated amortization
Customer relationships			$	(14	)	$	(3	)
Technology				(6	)		(2	)

Total accumulated amortization			$	(20	)	$	(5	)

Total Net			$	277		$	109

Debt (Tables)

12 Months Ended

Dec. 31, 2011

Debt [Abstract]

Partnership's Debt Balances


	December 31,
	2011			2010
	(in millions)
Affiliated Companies
Promissory note, due May 2013	$	—		$	100

Credit Facilities
$63 million Credit Facility, terminated August 2011	$	—		$	31

Senior Notes
Senior Notes—7.25%, due February 2012	$	250		$	250
Senior Notes—8.75%, due February 2014		175			175
Senior Notes—6.125%, due May 2016		175			175
Senior Notes—5.50%, due February 2020		250			250
Senior Notes—4.65%, due February 2022		300			—
Senior Notes—6.85%, due February 2040		250			250
Senior Notes—6.10%, due February 2042		300			—

		1,700			1,100
Less:
Unamortized bond discount		(2	)		(2	)
Current portion of long-term debt		(250	)		—

Long-term debt	$	1,448		$	1,129

Long-Term Debt Maturities Aggregate Amount


Year Ended December 31,	(in millions)
2012	$	250
2013		—
2014		175
2015		—
2016		175
Thereafter		1,100

Total	$	1,700

Commitments And Contingent Liabilities (Tables)

12 Months Ended

Dec. 31, 2011

Commitments And Contingent Liabilities [Abstract]

Future Minimum Annual Rental Aggregate Amount


	Year Ended December 31,
	(in millions)
2012	$	6
2013		4
2014		4
2015		3
2016		1
Thereafter		2

Total	$	20

Cash Distributions (Tables)

12 Months Ended

Dec. 31, 2011

Cash Distributions [Abstract]

Schedule Of Distributions Made To General And Limited Partner


	Cancelled IDRs								New IDRs
	Total Quarterly Distribution Target Amount		Marginal Percentage Interest in Distributions						Total Quarterly Distribution Target Amount		Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount		General Partner			Unitholders			Total Quarterly Distribution Target Amount		General Partner			Unitholders
Minimum Quarterly Distribution	$	0.1500		2	%		98	%
First Target Distribution		up to $0.1667		2	%		98	%				No change
Second Target Distribution		above $0.1667 up to $0.1917		15	%*		85	%
Third Target Distribution		above $0.1917 up to $0.2333		25	%*		75	%		above $0.1917 up to $0.5275		37	%*		63	%
Thereafter		above $0.2333		50	%*		50	%		above $0.5275		50	%*		50	%

*	Includes 2 percent general partner interest.

Schedule Of Cash Distribution To Limited And General Partners


Cash Distribution Payment Date	Cash Distribution per Limited Partner Unit		Annualized Cash Distribution per Limited Partner Unit		Total Cash Distribution to the Limited Partners		Total Cash Distribution to the General Partner
					(in millions)		(in millions)
November 14, 2011	$	0.4133	$	1.6532	$	41	$	13
August 12, 2011	$	0.4050	$	1.6200	$	40	$	13
May 13, 2011	$	0.3983	$	1.5932	$	40	$	12
February 14, 2011	$	0.3933	$	1.5732	$	39	$	12

November 12, 2010	$	0.3900	$	1.5600	$	39	$	12
August 13, 2010	$	0.3800	$	1.5200	$	35	$	11
May 14, 2010	$	0.3717	$	1.4867	$	35	$	10
February 12, 2010	$	0.3633	$	1.4533	$	34	$	14

November 14, 2009	$	0.3550	$	1.4200	$	33	$	13
August 14, 2009	$	0.3467	$	1.3867	$	32	$	13
May 15, 2009	$	0.3383	$	1.3533	$	31	$	12
February 14, 2009	$	0.3300	$	1.3200	$	29	$	10

Management Incentive Plan (Tables)

12 Months Ended

Dec. 31, 2011

Management Incentive Plan [Abstract]

Summarizes Information Restricted Unit Award Activity


	Number of Units			Weighted Average Grant- Date Fair Value
Granted, non-vested and outstanding, December 31, 2008		402,408		$	18.33
Granted⁽¹⁾		299,403		$	19.92
Performance Factor adjustment		149,286		$	18.68
Vested		(322,725	)	$	18.75
Cancelled/forfeited		(60,387	)	$	18.61

Granted, non-vested and outstanding, December 31, 2009		467,985		$	19.13

Granted⁽¹⁾		272,427		$	24.87
Performance Factor adjustment		131,760		$	17.65
Vested		(326,130	)	$	14.41
Cancelled/forfeited		(101,949	)	$	20.92

Granted, non-vested and outstanding, December 31, 2010		444,093		$	22.59

Granted⁽¹⁾		189,714		$	31.13
Performance Factor adjustment		184,113		$	19.88
Vested		(449,055	)	$	19.87
Cancelled/forfeited		(23,010	)	$	27.66

Granted, non-vested and outstanding, December 31, 2011		345,855		$	28.17

⁽¹⁾

Schedule Of Fair Value Assumptions


	Year Ended December 31,
	2011		2010		2009
Expected unit-price volatility		24.6%		25.9%		29.1%
Distribution yield		5.4%		6.4%		7.4%
Risk-free interest rate		1.0%		1.6%		1.3%
Weighted average fair value of performance units granted during the year	$	31.51	$	25.16	$	19.92

Derivatives And Risk Management (Tables)

12 Months Ended

Dec. 31, 2011

Derivatives And Risk Management [Abstract]

Schedule Of Derivative Assets And Liabilities


	2011			2010
	(in millions)
Derivative assets	$	6		$	2
Derivative liabilities		(2	)		(6	)

	$	4		$	(4	)

Schedule Of Derivative Instruments, Gain (Loss) In Statement Of Financial Performance


	Pretax Gains (Losses) Recognized in Other Comprehensive Income		Pretax Gains (Losses) Recognized in Earnings			Location of Gains (Losses) Recognized in Earnings
	(in million)
Year Ended December 31, 2011
Derivatives designated as cash flow hedging instruments:
Commodity contracts	$	4	$	(1	)	Sales and other operating revenue
Commodity contracts		—		2		Cost of product sold and operating expenses

	$	4	$	1

Derivatives not designated as hedging instruments:
Commodity contracts			$	6		Sales and other operating revenue
Commodity contracts				(1	)	Cost of product sold and operating expenses

			$	5

Year Ended December 31, 2010
Derivatives designated as cash flow hedging instruments:
Commodity contracts	$	—	$	—		Sales and other operating revenue
Commodity contracts		—		—		Cost of product sold and operating expenses

	$	—	$	—

Derivatives not designated as hedging instruments:
Commodity contracts			$	(1	)	Sales and other operating revenue
Commodity contracts				—		Cost of product sold and operating expenses

			$	(1	)

Tabular disclosure of the location and amount of gains and losses reported in the statement of financial performance, or when applicable, the statement of financial position. For example, (a) gains and losses recognized in the income statement on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges and (b) gains and losses initially recognized in other comprehensive income on derivative instruments designated and qualifying as cash flow hedges.

Other Financial Highlights [Member]

Business Segment Information (Tables)

12 Months Ended

Dec. 31, 2011

Segment Reporting Information


	Refined Products Pipelines		Terminal Facilities		Crude Oil Pipeline		Crude Oil Acquisition and Marketing		Total
	(in millions)
As of and for the year ended December 31, 2011
Capital expenditures⁽¹⁾	$	23	$	121	$	49	$	15	$	213
Investment in affiliates	$	73	$	-	$	-	$	-	$	73
Goodwill	$	8	$	53	$	2	$	14	$	77
Identifiable assets⁽²⁾	$	736	$	1,053	$	1,055	$	2,469	$	5,477

As of and for the year ended December 31, 2010
Capital expenditures⁽³⁾	$	17	$	110	$	36	$	2	$	174
Investment in affiliates	$	73	$	-	$	-	$	-	$	73
Goodwill	$	8	$	53	$	2	$	-	$	63
Identifiable assets⁽⁴⁾	$	531	$	857	$	1,018	$	1,695	$	4,188

As of and for the year ended December 31, 2009
Capital expenditures⁽⁵⁾	$	12	$	110	$	38	$	3	$	176
Investment in affiliates	$	27	$	-	$	61	$	-	$	88
Goodwill	$	8	$	6	$	2	$	-	$	16
Identifiable assets⁽⁶⁾	$	476	$	598	$	583	$	1,405	$	3,099

⁽¹⁾

⁽²⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $107 million advances to affiliates, $15 million deferred financing costs, and $40 million to properties, and plants and equipment, net.

⁽³⁾	Total capital expenditures exclude $252 million for the acquisition of the butane blending business, additional ownership interests in West Shore, Mid-Valley and West Texas Gulf, and two terminals and include $9 million of capital expenditures attributable to corporate activities.

⁽⁴⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $44 million advances to affiliates, $9 million deferred financing costs, and $32 million to properties, and plants and equipment, net.

⁽⁵⁾	Total capital expenditures exclude $50 million for the acquisitions of the Romulus refined products terminal and the Excel crude oil pipeline and include $13 million of capital expenditures attributable to corporate activities.

⁽⁶⁾	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $9 million advances to affiliates, $4 million deferred financing costs, and $22 million to properties, plants and equipment, net.

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

Summarized Quarterly Financial Data

Quarterly Financial Data (Tables)

12 Months Ended

Dec. 31, 2011

Quarterly Financial Data [Abstract]


	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per unit amounts)
2011
Sales and other operating revenue:
Affiliates	$	303		$	39		$	39		$	51
Unaffiliated customers	$	1,955		$	2,385		$	2,808		$	3,325
Gross margin⁽¹⁾	$	95		$	139		$	148		$	173
Operating income	$	75		$	121		$	128		$	112
Net Income⁽²⁾	$	50		$	96		$	97		$	79
Net Income attributable to noncontrolling interests		2			2			2			3

Net Income attributable to Sunoco Logistics Partners L.P.	$	48		$	94		$	95		$	76
Less: General Partner's interest		(12	)		(14	)		(14	)		(14	)

Limited Partners' interest	$	36		$	80		$	81		$	62

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.36		$	0.80		$	0.78		$	0.60
Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.36		$	0.80		$	0.78		$	0.60


	First Quarter			Second Quarter			Third Quarter			Fourth Quarter
	(in millions, except per unit amounts)
2010
Sales and other operating revenue:
Affiliates	$	173		$	214		$	293		$	437
Unaffiliated customers	$	1,507		$	1,815		$	1,583		$	1,786
Gross margin ⁽¹⁾	$	71		$	76		$	98		$	101
Operating income	$	58		$	70		$	90		$	83
Net Income⁽³⁾	$	43		$	51		$	194		$	60
Net Income attributable to noncontrolling interests		—			—			1			1

Net Income attributable to Sunoco Logistics Partners L.P.	$	43		$	51		$	193		$	59
Less: General Partner's interest		(10	)		(11	)		(15	)		(12	)

Limited Partners' interest	$	33		$	40		$	178		$	47

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.35		$	0.43		$	1.87		$	0.47
Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.35		$	0.43		$	1.86		$	0.47

⁽¹⁾	Gross margin equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.

⁽²⁾

⁽³⁾	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.

Supplemental Condensed Consolidating Financial Information (Tables)

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Supplemental Condensed Consolidating Financial Information [Abstract]

Consolidated Statement Of Income


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	432	$	—		$	432
Unaffiliated customers		—		—			10,473		—			10,473
Equity in earnings of subsidiaries		313		399			—		(712	)		—
Other income		—		—			13		—			13

Total Revenues		313		399			10,918		(712	)		10,918

Costs and Expenses
Cost of products sold and operating expenses		—		—			10,264		—			10,264
Depreciation and amortization expense		—		—			86		—			86
Impairment charge and related matters		—		—			42		—			42
Selling, general and administrative expenses		—		—			90		—			90

Total Costs and Expenses		—		—			10,482		—			10,482

Operating Income		313		399			436		(712	)		436
Net interest cost to affiliates		—		—			3		—			3
Other interest cost and debt expense, net		—		93			—		—			93
Capitalized interest		—		(7	)		—		—			(7	)

Income Before Provision for Income Taxes		313		313			433		(712	)		347
Provision for income taxes							25					25

Net Income		313		313			408		(712	)		322
Net Income attributable to noncontrolling interests		—		—			9		—			9

Net Income attributable to Sunoco Logistics Partners L.P.	$	313	$	313		$	399	$	(712	)	$	313


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	1,117	$	—		$	1,117
Unaffiliated customers		—		—			6,691		—			6,691
Equity in earnings of subsidiaries		346		416			—		(762	)		—
Other income		—		—			30		—			30

Total Revenues		346		416			7,838		(762	)		7,838

Costs and Expenses
Cost of products sold and operating expenses		—		—			7,398		—			7,398
Depreciation and amortization expense		—		—			64		—			64
Impairment charge		—		—			3		—			3
Selling, general and administrative expenses		—		—			72		—			72

Total Costs and Expenses		—		—			7,537		—			7,537

Operating Income		346		416			301		(762	)		301
Net interest cost to affiliates		—		(1	)		3		—			2
Other interest cost and debt expense, net		—		76			—		—			76
Capitalized interest		—		(5	)		—		—			(5	)
Gain on investments in affiliates		—		—			128		—			128

Income Before Provision for Income Taxes		346		346			426		(762	)		356
Provision for income taxes		—		—			8		—			8

Net Income		346		346			418		(762	)		348
Net Income attributable to noncontrolling interests		—		—			2		—			2

Net Income attributable to Sunoco Logistics Partners L.P.	$	346	$	346		$	416	$	(762	)	$	346


	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Affiliates	$	—	$	—		$	706	$	—		$	706
Unaffiliated customers		—		—			4,696		—			4,696
Equity in earnings of subsidiaries		250		292			—		(542	)		—
Other income		—		—			28		—			28

Total Revenues		250		292			5,430		(542	)		5,430

Costs and Expenses
Cost of products sold and operating expenses		—		—			5,023		—			5,023
Depreciation and amortization expense		—		—			48		—			48
Selling, general and administrative expenses		—		—			64		—			64

Total Costs and Expenses		—		—			5,135		—			5,135

Operating Income		250		292			295		(542	)		295
Net interest cost to affiliates		—		(3	)		3		—			—
Other interest cost and debt expense, net		—		49			—		—			49
Capitalized interest		—		(4	)		—		—			(4	)

Income Before Provision for Income Taxes		250		250			292		(542	)		250
Provision for income taxes		—		—			—		—			—

Net Income		250		250			292		(542	)		250
Net income attributable to noncontrolling interests		—		—			—		—			—

Net Income attributable to Sunoco Logistics Partners L.P.	$	250	$	250		$	292	$	(542	)	$	250

Consolidated Balance Sheet


	Parent Guarantor		Subsidiary Issuer		Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2	$	3		$	—		$	5
Advances to affiliated companies		90		48		(31	)		—			107
Accounts receivable, net		—		—		2,188			—			2,188
Inventories		—		—		206			—			206

Total Current Assets		90		50		2,366			—			2,506

Properties, plants and equipment, net		—		—		2,522			—			2,522
Investment in affiliates		1,007		2,680		73			(3,687	)		73
Goodwill		—		—		77			—			77
Intangible assets, net		—		—		277			—			277
Other assets		—		13		9			—			22

Total Assets	$	1,097	$	2,743	$	5,324		$	(3,687	)	$	5,477

Liabilities and Equity
Accounts payable		—		1		2,110			—			2,111
Current portion of long-term debt		—		250		—			—			250
Accrued liabilities		1		37		74			—			112
Accrued taxes payable		—		—		62			—			62

Total Current Liabilities		1		288		2,246			—			2,535

Long-term debt		—		1,448		—			—			1,448
Other deferred credits and liabilities		—		—		78			—			78
Deferred income taxes		—		—		222			—			222

Total Liabilities		1		1,736		2,546			—			4,283

Equity
Sunoco Logistics Partners L.P. equity		1,096		1,007		2,680			(3,687	)		1,096
Noncontrolling interests		—		—		98			—			98

Total Equity		1,096		1,007		2,778			(3,687	)		1,194

Total Liabilities and Equity	$	1,097	$	2,743	$	5,324		$	(3,687	)	$	5,477


	Parent Guarantor		Subsidiary Issuer		Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Assets
Current Assets
Cash and cash equivalents	$	—	$	2	$	—		$	—		$	2
Advances to affiliated companies		28		47		(31	)		—			44
Accounts receivable, affiliated companies		—		—		154			—			154
Accounts receivable, net		—		—		1,536			—			1,536
Inventories		—		—		63			—			63

Total Current Assets		28		49		1,722			—			1,799

Properties, plants and equipment, net		—		—		2,128			—			2,128
Investment in affiliates		937		2,135		73			(3,072	)		73
Goodwill		—		—		63			—			63
Intangible assets, net		—		—		109			—			109
Other assets		—		7		9			—			16

Total Assets	$	965	$	2,191	$	4,104		$	(3,072	)	$	4,188

Liabilities and Equity
Accounts payable	$	—	$	—	$	1,591					$	1,591
Accrued liabilities		—		25		51						76
Accrued taxes payable		—		—		44						44

Total Current Liabilities		—		25		1,686			—			1,711

Long-term debt, affiliated companies		—		100		—			—			100
Long-term debt		—		1,129		—			—			1,129
Other deferred credits and liabilities		—		—		42			—			42
Deferred income taxes		—		—		164			—			164

Total Liabilities		—		1,254		1,892			—			3,146

Equity
Sunoco Logistics Partners L.P. equity		965		937		2,135			(3,072	)		965
Noncontrolling interests		—		—		77			—			77

Total Equity		965		937		2,212			(3,072	)		1,042

Total Liabilities and Equity	$	965	$	2,191	$	4,104		$	(3,072	)	$	4,188

Consolidated Statement Of Cash Flows


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	313		$	322		$	508		$	(713	)	$	430

Cash Flows from Investing Activities:
Capital expenditures		—			—			(213	)		—			(213	)
Acquisitions		—			—			(396	)		—			(396	)
Intercompany		(35	)		(786	)		108			713			—

Net cash used in investing activities		(35	)		(786	)		(501	)		713			(609	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(210	)		—			—			—			(210	)
Distributions paid to noncontrolling interests		(8	)		—			—			—			(8	)
Contributions from general partner		2			—			—			—			2
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(3	)		—			(3	)
Repayments under credit facility		—			(560	)		—			—			(560	)
Borrowings under credit facility		—			529			—			—			529
Net proceeds from issuance of long term debt		—			595			—			—			595
Promissory note from affiliate		—			(100	)		—			—			(100	)
Advances to affiliates, net		(62	)		—			(1	)		—			(63	)

Net cash provided by financing activities		(278	)		464			(4	)		—			182

Net change in cash and cash equivalents		—			—			3			—			3
Cash and cash equivalents at beginning of year		—			2			—			—			2

Cash and cash equivalents at end of year	$	—		$	2		$	3		$	—		$	5


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	346		$	366		$	391		$	(762	)	$	341

Cash Flows from Investing Activities:
Capital expenditures		—			—			(174	)		—			(174	)
Acquisitions		—			—			(252	)		—			(252	)
Intercompany		(79	)		(723	)		40			762			—

Net cash used in investing activities		(79	)		(723	)		(386	)		762			(426	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(189	)		—			—			—			(189	)
Distributions paid to noncontrolling interests		(4	)		—			—			—			(4	)
Net proceeds from issuance of limited partner units		143			—			—			—			143
Contributions from general partner		3			—			—			—			3
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(2	)		—			(2	)
Repayments under credit facility		—			(888	)		—			—			(888	)
Borrowings under credit facility		—			650			—			—			650
Net proceeds from issuance of long term debt		—			494			—			—			494
Promissory note from affiliate		—			100			—			—			100
Repayment of promissory note to general partner		(201	)		—			—			—			(201	)
Advances to affiliates, net		(19	)		1			(3	)		—			(21	)

Net cash provided by financing activities		(267	)		357			(5	)		—			85

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

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


	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	250		$	252		$	216		$	(542	)	$	176

Cash Flows from Investing Activities:
Capital expenditures		—			—			(176	)		—			(176	)
Acquisitions		—			—			(50	)		—			(50	)
Intercompany		(181	)		(371	)		10			542			—

Net cash used in investing activities		(181	)		(371	)		(216	)		542			(226	)

Cash Flows from Financing Activities:
Distributions paid to limited and general partners		(173	)		—			—			—			(173	)
Net proceeds from issuance of limited partner units		110			—			—			—			110
Contributions from general partner		2			—			—			—			2
Payments of statutory withholding on net issuance of limited partner units under restricted unit incentive plan		—			—			(2	)		—			(2	)
Repayments under credit facility		—			(687	)		—			—			(687	)
Borrowings under credit facility		—			633			—			—			633
Net proceeds from issuance of long term debt		—			173			—			—			173
Advances to affiliates, net		(8	)		—			2			—			(6	)

Net cash provided by financing activities		(69	)		119			—			—			50

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

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

Summary Of Significant Accounting Policies (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Accounting Policies [Line Items]

Controlling Financial Interest Evidenced By A Voting Interest Greater Than Certain Percentage

50.00%

Investment in affiliates, pipeline and related assets, estimated useful life, years

$ 42

^[1]

$ 3

^[1]

Liabilities for asset retirement obligations

$ 7

Federal statutory rate

35.00%

$ 51

Net deferred tax

222

$ 164

Increases in the asset retirement obligation

Increases in assumed retirement costs

Accounting Policies [Line Items]

$ 11

[1]

Summary Of Significant Accounting Policies (Components Of Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Summary Of Significant Accounting Policies [Abstract]
Current, Federal	$ 25	$ 6
Deferred, Federal	(2)
Current, State	2	2
Deferred, State
Total income tax expense	$ 25	$ 8

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted federal tax law to the domestic taxable Income or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Paragraph Question 1-7

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted state and local tax law to relevant amounts of taxable Income or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

The component of total income tax expense for the period comprised of the increase (decrease) during the period in the entity's domestic deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the federally enacted tax law.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 8, 16, 17, 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

The component of total income tax expense for the period comprised of the increase (decrease) in the entity's state and local deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the applicable enacted tax laws.

Proceeds from issuance of senior notes

Acquisitions (Narrative) (Details) shares in Millions, Boe in Millions, $ in Millions	1 Months Ended						3 Months Ended	12 Months Ended
	Aug. 31, 2011 USD ($) Boe states	Jul. 31, 2011 USD ($) Boe shares	May 31, 2011 USD ($) Mi	Aug. 31, 2010 USD ($) Mi	Jul. 31, 2010 USD ($) Mi	Sep. 30, 2009 USD ($) years Mi	Sep. 30, 2010 USD ($)	Dec. 31, 2011 USD ($) states	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Oct. 31, 2010 USD ($)
Business Acquisition [Line Items]
Total active terminal storage capacity of facility									500,000	500,000
Cash paid for acquisitions								$ 396	$ 252	$ 50
Cash paid for acquisitions, including inventory	$ 56
Assets acquired at carrying cost		$ 22
Excess of purchase price over related party carrying amount		20
Number of states the Partnership operates \| states								29
Acquisitions								$ 396	252	50
Ownership interest percentage			83.80%
Gain on investments in affiliates							$ 128		128
Partnership contract term period, years \| years						20
Conoco Phillips [Member]
Business Acquisition [Line Items]
Terminal bay truck rack capacity	10
Terminal storage capacity, barrels \| Boe	1.0
Texon L.P. [Member]
Business Acquisition [Line Items]
Cash paid for acquisitions, including inventory	$ 205
Current crude oil volume per day	75,000
Number of states the Partnership operates \| states	16
Inland Corporation [Member]
Business Acquisition [Line Items]
Cash paid for acquisitions			$ 99					99
Pipeline length in miles \| Mi			350
Shell Oil Company [Member]
Business Acquisition [Line Items]
Ownership interest percentage			27.00%
Eagle Point Tank Farm [Member]
Business Acquisition [Line Items]
Acquisition amount		$ 100
Issuance of Class A units to Sunoco, Inc., shares \| shares		3.9
Issuance of Class A units to Sunoco, Inc., value		$ 98
Cash paid for acquisitions		$ 2						2
Terminal storage capacity, barrels \| Boe		5.0
Sunoco [Member]
Business Acquisition [Line Items]
Ownership interest percentage			56.80%
Texon Crude [Member]
Business Acquisition [Line Items]
Acquisition amount					$ 152
Cash paid for acquisitions, including inventory					140
Gulfstream Terminals And Marketing LLC [Member]
Business Acquisition [Line Items]
Acquisition amount											$ 9
Environmental liability											$ 1
Excel Pipeline LLC [Member]
Business Acquisition [Line Items]
Cash paid for acquisitions										32
Ownership interest percentage after acquisition						100.00%
Pipeline length in miles \| Mi						50
RKA Terminal [Member]
Business Acquisition [Line Items]
Cash paid for acquisitions										$ 18
Business acquisition, additional payments						$ 2
Terminals [Member]
Business Acquisition [Line Items]
Cash paid for acquisitions									9
West Shore Pipe Line Company [Member]
Business Acquisition [Line Items]
Acquisition amount					$ 6
Ownership interest percentage before acquisition					12.30%
Ownership interest percentage after acquisition					17.10%
Pipeline length in miles \| Mi					650
West Texas Gulf Pipe Line Company [Member]
Business Acquisition [Line Items]
Acquisition amount				$ 27
Ownership interest percentage before acquisition				43.80%
Ownership interest percentage after acquisition				60.30%
Pipeline length in miles \| Mi				600
Pre-acquisition equity interests fair value								72
Mid-Valley Pipeline Company [Member]
Business Acquisition [Line Items]
Acquisition amount					$ 58
Ownership interest percentage before acquisition					55.30%
Ownership interest percentage after acquisition					91.00%
Pipeline length in miles \| Mi					1,000
Pre-acquisition equity interests fair value								$ 90
Mid-Valley And West Texas Gulf [Member]
Business Acquisition [Line Items]
Gain on investments in affiliates									$ 128

Acquisitions (Schedule Of Effects Of The Acquisitions On The Partnership's Consolidated Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2011	Jul. 31, 2011	May 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Business Acquisition [Line Items]
Current assets	$ 44			$ 37
Deferred charges and other assets				1
Properties, plants & equipment, net	270			482	$ 29
Intangible assets, net	183			90	21
Goodwill	14			47
Current liabilities	(7)			(4)
Other deferred credits and liabilities	(8)			(2)
Deferred income taxes	(60)			(164)
Sunoco Logistics Partners L.P. equity	(20)			(128)
Noncontrolling interests	(20)			(80)
Cash paid for acquisition	396			252	50
East Boston Terminal [Member]
Business Acquisition [Line Items]
Current assets	17
Properties, plants & equipment, net	63
Other deferred credits and liabilities	(7)
Cash paid for acquisition	73
Crude Oil Acquisition And Marketing [Member]
Business Acquisition [Line Items]
Current assets	24
Properties, plants & equipment, net	7
Intangible assets, net	183
Goodwill	14
Current liabilities	(6)
Cash paid for acquisition	222
Eagle Point Tank Farm [Member]
Business Acquisition [Line Items]
Properties, plants & equipment, net	22
Sunoco Logistics Partners L.P. equity	(20)
Cash paid for acquisition	2	$ 2
Inland Corporation [Member]
Business Acquisition [Line Items]
Current assets	3
Properties, plants & equipment, net	178
Current liabilities	(1)
Other deferred credits and liabilities	(1)
Deferred income taxes	(60)
Noncontrolling interests	(20)
Cash paid for acquisition	$ 99		$ 99
Butane Blending [Member]
Business Acquisition [Line Items]
Current assets				14
Properties, plants & equipment, net				1
Intangible assets, net				90
Goodwill				47
Cash paid for acquisition				152
Joint Ventures [Member]
Business Acquisition [Line Items]
Current assets				23
Deferred charges and other assets				1
Properties, plants & equipment, net				471
Current liabilities				(4)
Other deferred credits and liabilities				(1)
Deferred income taxes				(164)
Sunoco Logistics Partners L.P. equity				(128)
Noncontrolling interests				(80)
Cash paid for acquisition				91
Terminals [Member]
Business Acquisition [Line Items]
Properties, plants & equipment, net				10
Other deferred credits and liabilities				(1)
Cash paid for acquisition				9
Excel Pipeline LLC [Member]
Business Acquisition [Line Items]
Properties, plants & equipment, net					11
Intangible assets, net					21
Cash paid for acquisition					32
RKA Terminal [Member]
Business Acquisition [Line Items]
Properties, plants & equipment, net					18
Cash paid for acquisition					$ 18
Investment In Affiliate, Increase [Member]
Business Acquisition [Line Items]
Investment in affiliates				6
Investment In Affiliate, Increase [Member] \| Joint Ventures [Member]
Business Acquisition [Line Items]
Investment in affiliates				6
Investment In Affiliate, Decrease [Member]
Business Acquisition [Line Items]
Investment in affiliates				(33)
Investment In Affiliate, Decrease [Member] \| Joint Ventures [Member]
Business Acquisition [Line Items]
Investment in affiliates				$ (33)

Related Party Transactions (Details)
shares in Millions, $ in Millions

1 Months Ended

2 Months Ended

3 Months Ended

12 Months Ended

Jul. 31, 2011

USD ($)

Mar. 31, 2011

bbl

Feb. 28, 2011

USD ($)

Aug. 31, 2010

USD ($)

Jul. 31, 2010

USD ($)

Feb. 28, 2010

USD ($)

Jan. 31, 2010

USD ($)

Feb. 28, 2009

USD ($)

May 31, 2009

USD ($)

Dec. 31, 2011

USD ($)

Dec. 31, 2011

USD ($)

MMBoe

days

years

Dec. 31, 2010

USD ($)

Dec. 31, 2009

USD ($)

May 31, 2011

USD ($)

$ 595.0

$ 494.0

$ 173.0

$ 595.0

$ 494.0

$ 173.0

Net proceeds from issuance of long-term debt

595.0

$ 494.0

$ 173.0

$ 595.0

494.0

173.0

Repurchase amount for incentive distribution rights

$ 201.0

Basis points included in interest rate on related party borrowings

275

Product terminal services agreement period, in years | years

Agreement expiration date

June 2014

Barrels per day | bbl

300,000

Notes payable, noncurrent

100.0

$ 13.0

5.0

6.0

Allocation of shared insurance costs

4.0

Allocated employee benefit expenses

$ 26.0

29.0

28.0

Period of time when an agreement can be terminated by either party through written notice, in days | days

Business Acquisition, Cost of Acquired Entity, Cash Paid

$ 396.0

252.0

$ 50.0

Assets acquired at carrying cost

22.0

Issuance of deferred distribution units to Sunoco

$ 22.0

Basis at which class A units convert to common units one year after issuance

one-to-one

Public offerings of partnership units | shares

6.0

6.7

General partnership interest

2.00%

Units issued under incentive plans, shares | shares

0.2

Maximum contributions from general partner

$ 0.1

$ 3.0

$ 0.1

$ 2.0

Storage capacity and terminalling services | MMBoe

2.5

Annual fee escalation percentage

1.67%

$ 42.0

^[1]

$ 3.0

^[1]

Inland Corporation [Member]

7.0

Business Acquisition, Cost of Acquired Entity, Cash Paid

99.0

$ 99.0

Eagle Point Tank Farm [Member]

Business Acquisition, Cost of Acquired Entity, Cash Paid

$ 2.0

2.0

Issuance of Class A units to general partners | shares

3.9

Issuance of deferred distribution units to Sunoco

$ 20.0

Maximum contributions from general partner

$ 2.0

Third Parties [Member]

$ 18.0

Eagle Point Tank Farm [Member]

Term Of Agreement, in years | years

Interrefinery Pipelines [Member]

Term Of Agreement, in years | years

$395 Million Credit Facility - Due November 2012 [Member]

Revolving credit facility

350.0

$ 350.0

Promissory Note - Due May 2013 [Member]

Repayment of note

100.0

Notes payable, noncurrent

$ 100.0

31.0

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data [Abstract]

$ 11.0

[1]

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data (Narrative) (Details)		1 Months Ended				2 Months Ended	3 Months Ended								12 Months Ended
	Dec. 02, 2011	Feb. 28, 2011	Aug. 31, 2010	Feb. 28, 2010	Feb. 28, 2009	May 31, 2009	Dec. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Jun. 30, 2011 USD ($)	Mar. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Sep. 30, 2010 USD ($)	Jun. 30, 2010 USD ($)	Mar. 31, 2010 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data [Abstract]
General partnership interest		2.00%	2.00%	2.00%	2.00%	2.00%									2.00%
Less: General Partner's interest							$ 14,000,000	$ 14,000,000	$ 14,000,000	$ 12,000,000	$ 12,000,000	$ 15,000,000	$ 11,000,000	$ 10,000,000	$ 54,000,000	$ 48,000,000	$ 52,000,000
Percentage of net income attributable to Sunoco Logistics Partners L.P															17.00%	14.00%	21.00%
Maximum incentive distribution received by General Partner															50.00%
Incentive distribution, minimum threshold															$ 0.1667
Stock split conversion ratio	3
Stock split	two additional common and Class A units for every one unit

Net Income Attributable To Sunoco Logistics Partners L.P. Per Limited Partner Unit Data (Schedule Of Weighted Average Number Of Shares) (Details) - shares
shares in Millions

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Weighted average number of limited partner units outstanding-basic

^[1]

101.3

95.2

91.0

Add effect of dilutive unit incentive awards

0.5

0.6

Weighted average number of limited partner units-diluted

^[1]

101.8

95.7

91.6

[1]	Reflects the fourth quarter 2011 three-for-one unit split.

Inventories (Schedule Of Inventories) (Details) - USD ($) $ in Millions	Dec. 31, 2011	Dec. 31, 2010
Inventories [Abstract]
Crude oil	$ 142	$ 39
Refined products	55	16
Refined products additives	2	2
Materials, supplies and other	7	6
Inventories	206	63
Increase in replacement cost of crude oil and refined products inventory	$ 196	$ 166

Properties, Plants And Equipment (Property, Plant And Equipment) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) years	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives, Maximum (in Years)	40
Total properties, plants and equipment	$ 3,234	$ 2,799
Less: Accumulated depreciation and amortization	(712)	(671)
Properties, plants and equipment, net (Note 6)	2,522	2,128	$ 22
Land And Land Improvements (Including Rights Of Way) [Member]
Property, Plant and Equipment [Line Items]
Total properties, plants and equipment	$ 525	401
Pipeline And Related Assets [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives, Minimum (in Years) \| years	38
Property, Plant and Equipment, Estimated Useful Lives, Maximum (in Years) \| years	60
Total properties, plants and equipment	$ 1,344	1,271
Terminals And Storage Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives, Minimum (in Years) \| years	5
Property, Plant and Equipment, Estimated Useful Lives, Maximum (in Years) \| years	44
Total properties, plants and equipment	$ 768	686
Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives, Minimum (in Years) \| years	5
Property, Plant and Equipment, Estimated Useful Lives, Maximum (in Years) \| years	48
Total properties, plants and equipment	$ 385	325
Construction-In-Progress [Member]
Property, Plant and Equipment [Line Items]
Total properties, plants and equipment	$ 212	$ 116

Investment In Affiliates (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Investment In Affiliates [Abstract]
Basis for presentation of equity method investments	100.00%
Excess investment amount	$ 54
Accumulated amortization	5
Undistributed earnings	22
Dividends received	$ 11	$ 15	$ 19

Investment In Affiliates (Schedule Of Partnerships Ownership Percentages Not Holding Controlling Financial Interest) (Details)	Dec. 31, 2011	Dec. 31, 2010
Explorer Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by parent	9.40%	9.40%
Yellowstone Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by parent	14.00%	14.00%
West Shore Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by parent	17.10%	17.10%
Wolverine Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by parent	31.50%	31.50%

Investment In Affiliates (Schedule Of Summarized Financial Information Of Equity Investments) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Schedule of Equity Method Investments [Line Items]

Current assets

^[1]

$ 130

$ 122

$ 126

Non-current assets

^[1]

648

646

680

Current liabilities

^[1]

127

122

124

Non-current liabilities

^[1]

549

546

568

Net equity

^[1]

102

100

114

Partnership Entity [Member]

Schedule of Equity Method Investments [Line Items]

Total revenues

^[1]

374

439

458

Income before income taxes

^[1]

130

193

190

Net income

^[1]

$ 80

$ 120

$ 119

[1]

Goodwill And Other Intangible Assets (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Goodwill And Other Intangible Assets [Abstract]
Balance of goodwill	$ 77	$ 63	$ 16
Increase in goodwill relating to acquisition of crude oil and marketing business	14
Amortization expenses of intangible assets	$ 15	$ 4	$ 1
Weighted-average amortization period, Identifiable intangible assets, Years	11
Forecasts of annual amortization expense	$ 26

Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 43
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 68
-Subparagraph l
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6388280&loc=d3e13770-109266

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 350
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6905597&loc=d3e13816-109267

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 72
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 142
-Paragraph 45
-Subparagraph e
-Clause 1
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Goodwill And Other Intangible Assets (Identifiable Intangible Assets) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)
Finite-Lived Intangible Assets [Line Items]
Weighted Average Amortization Period, Years	11
Total gross	$ 297	$ 114
Total accumulated amortization	(20)	(5)
Total Net	$ 277	109
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Weighted Average Amortization Period, Years	11
Total gross	$ 239	56
Total accumulated amortization	$ (14)	(3)
Technology [Member]
Finite-Lived Intangible Assets [Line Items]
Weighted Average Amortization Period, Years	14
Total gross	$ 58	58
Total accumulated amortization	$ (6)	$ (2)

Debt (Narrative) (Details)	1 Months Ended				12 Months Ended
Debt (Narrative) (Details)	Jul. 31, 2011 USD ($)	Jul. 31, 2010	Feb. 28, 2010 USD ($)	Feb. 28, 2009 USD ($)	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Aug. 31, 2011 USD ($)	Aug. 31, 2010 USD ($)
Line of Credit Facility [Line Items]
Interest Expense, Long-term Debt and Capital Securities					$ 73,000,000	$ 59,000,000	$ 37,000,000
Basis points included in interest rate on related party borrowings		275
Current portion of long-term debt					250,000,000
Net proceeds from issuance of senior notes	$ 595,000,000		$ 494,000,000	$ 173,000,000	$ 595,000,000	494,000,000	$ 173,000,000
Repayment of promissory note			201,000,000
Senior Notes - 4.65%, Due February 2022 [Member]
Line of Credit Facility [Line Items]
Senior notes principal amount	$ 300,000,000
Debt instrument maturity	2022				February 2022
Interest rate	4.65%				4.65%
Senior Notes - 6.10%, Due February 2042 [Member]
Line of Credit Facility [Line Items]
Senior notes principal amount	$ 300,000,000
Debt instrument maturity	2042				February 2042
Interest rate	6.10%				6.10%
$395 Million Credit Facility - Due November 2012 [Member]
Line of Credit Facility [Line Items]
Revolving credit facility					$ 350,000,000
$63 Million Credit Facility, Terminated August 2011 [Member]
Line of Credit Facility [Line Items]
Revolving credit facility					$ 63,000,000
Debt instrument maturity					August 2011
$350 Million Credit Facility, Due August 2016 [Member]
Line of Credit Facility [Line Items]
Revolving credit facility								$ 350,000,000
Interest rate operating partnership option					LIBOR or the Base Rate (defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the Citibank prime rate or (c) LIBOR plus an applicable margin) or the Federal Funds Rate (each plus an applicable margin).
Line of credit facility expiration date					August 2016
$200 Million Credit Facility, Due August 2012 [Member]
Line of Credit Facility [Line Items]
Revolving credit facility								200,000,000
Interest rate operating partnership option					(defined as the highest of (a) the Federal Funds Rate plus 0.50%, (b) the Citibank prime rate or (c) LIBOR plus an applicable margin)
Senior Notes - 8.75%, Due February 2014 [Member]
Line of Credit Facility [Line Items]
Senior notes principal amount				$ 175,000,000
Debt instrument maturity				February 15, 2014	February 2014
Interest rate				8.75%	8.75%
Senior Notes - 5.50%, Due February 2020 [Member]
Line of Credit Facility [Line Items]
Senior notes principal amount			$ 250,000,000
Debt instrument maturity			2020		February 2020
Interest rate			5.50%		5.50%
Senior Notes - 6.85%, Due February 2040 [Member]
Line of Credit Facility [Line Items]
Senior notes principal amount			$ 250,000,000
Debt instrument maturity			2040		February 2040
Interest rate			6.85%		6.85%
$395 Million Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving credit facility									$ 395,000,000
Promissory Note - Due May 2013 [Member]
Line of Credit Facility [Line Items]
Debt instrument maturity					May 2013
Promissory note						$ 100,000,000
Senior Notes - 7.25%, Due February 2012 [Member]
Line of Credit Facility [Line Items]
Debt instrument maturity					February 2012
Interest rate					7.25%
Senior Notes - 7.25%, Due February 2012 [Member] \| Partnership Entity [Member]
Line of Credit Facility [Line Items]
Current portion of long-term debt					$ 250,000,000
$63 Million Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving credit facility	$ 63,000,000
$395 Million Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving credit facility	$ 395,000,000
Maximum [Member] \| $350 Million Credit Facility, Due August 2016 [Member]
Line of Credit Facility [Line Items]
Increased consolidated debt to consolidated EBIDTA ratio					5.50:1
Maximum [Member] \| $200 Million Credit Facility, Due August 2012 [Member]
Line of Credit Facility [Line Items]
Increased consolidated debt to consolidated EBIDTA ratio					5.50:1
Minimum [Member] \| $350 Million Credit Facility, Due August 2016 [Member]
Line of Credit Facility [Line Items]
Increased consolidated debt to consolidated EBIDTA ratio					5.00:1
Minimum [Member] \| $200 Million Credit Facility, Due August 2012 [Member]
Line of Credit Facility [Line Items]
Increased consolidated debt to consolidated EBIDTA ratio					5.00:1
Former Capacity [Member]
Line of Credit Facility [Line Items]
Line of credit facility total								458,000,000
Current Capacity [Member]
Line of Credit Facility [Line Items]
Line of credit facility total								$ 550,000,000

Debt (Partnership's Debt Balances) (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Jul. 31, 2011	Feb. 28, 2010	Feb. 28, 2009	Dec. 31, 2011	Dec. 31, 2010
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 1,700	$ 1,100
Unamortized bond discount				(2)	(2)
Current portion of long-term debt				(250)
Long-term debt				$ 1,448	1,129
Promissory Note - Due May 2013 [Member]
Line of Credit Facility [Line Items]
Promissory note					100
Debt instrument maturity				May 2013
$63 Million Credit Facility, Terminated August 2011 [Member]
Line of Credit Facility [Line Items]
Credit Facility					31
Debt instrument maturity				August 2011
Revolving credit facility				$ 63
Senior Notes - 7.25%, Due February 2012 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 250	250
Interest rate				7.25%
Debt instrument maturity				February 2012
Senior Notes - 8.75%, Due February 2014 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 175	175
Interest rate			8.75%	8.75%
Debt instrument maturity			February 15, 2014	February 2014
Senior Notes - 6.125%, Due May 2016 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 175	175
Interest rate				6.125%
Debt instrument maturity				May 2016
Senior Notes - 5.50%, Due February 2020 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 250	250
Interest rate		5.50%		5.50%
Debt instrument maturity		2020		February 2020
Senior Notes - 6.85%, Due February 2040 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 250	$ 250
Interest rate		6.85%		6.85%
Debt instrument maturity		2040		February 2040
Senior Notes - 4.65%, Due February 2022 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 300
Interest rate	4.65%			4.65%
Debt instrument maturity	2022			February 2022
Senior Notes - 6.10%, Due February 2042 [Member]
Line of Credit Facility [Line Items]
Senior Notes, Total				$ 300
Interest rate	6.10%			6.10%
Debt instrument maturity	2042			February 2042

Debt (Long-Term Debt Maturities Aggregate Amount) (Details) $ in Millions	Dec. 31, 2011 USD ($)
Debt [Abstract]
2012	$ 250
2013
2014	175
2015
2016	175
Thereafter	1,100
Total	$ 1,700

Commitments And Contingent Liabilities (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2011 USD ($) years	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Commitments And Contingent Liabilities [Abstract]
Total rental expense \| $	$ 10	$ 8	$ 7
Accrued liabilities for environmental remediation \| $	4	4
Charges against income for environmental remediation \| $	$ 5	$ 3	$ 3
Percent indemnification for first 21 years after IPO	100.00%
Annual decrease of partnership liability for claims asserted	10.00%
Estimated maximum additional reasonable possible losses \| $	$ 2
Percent indemnification in twenty-third year after IPO	80.00%
Indemnified period for the partnership from environmental and toxic tort liabilities, years \| years	30
Time period of one hundred percent indemnification after IPO, years \| years	21
Indemnified period for the partnership other than environmental and toxic tort liabilities, years \| years	10
Indemnified period for partnership consents and permits, years \| years	10

Commitments And Contingent Liabilities (Future Minimum Annual Rental Aggregate Amount) (Details) $ in Millions	Dec. 31, 2011 USD ($)
Commitments And Contingent Liabilities [Abstract]
2012	$ 6
2013	4
2014	4
2015	3
2016	1
Thereafter	2
Total	$ 20

Equity Offerings (Details) shares in Millions, $ in Millions		1 Months Ended					2 Months Ended	12 Months Ended
	Dec. 02, 2011	Jul. 31, 2011 USD ($) shares	Feb. 28, 2011 USD ($)	Aug. 31, 2010 USD ($) shares	Feb. 28, 2010 USD ($)	Feb. 28, 2009 USD ($)	May 31, 2009 USD ($) shares	Dec. 31, 2011 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Equity [Line Items]
Stock split conversion ratio	3
Stock split	two additional common and Class A units for every one unit
Issuance of deferred distribution units to Sunoco								$ 22.0
Issuance of Limited Partner units to the public, shares \| shares				6.0			6.7
Net proceeds from issuance of limited partner units				$ 143.0			$ 110.0		$ 143.0	$ 110.0
Partner contribution			$ 0.1	$ 3.0	$ 0.1	$ 0.1	$ 2.0
Percent general partner interest								2.00%
General partnership interest			2.00%	2.00%	2.00%	2.00%	2.00%	2.00%
Common Units [Member]
Equity [Line Items]
Issuance of Limited Partner units to the public, shares \| shares				6.0			6.7
General Partner [Member]
Equity [Line Items]
Issuance of deferred distribution units to Sunoco								$ 2.0
Partner contribution				$ 3.0			$ 2.0
General partnership interest							2.00%
Class A Units [Member]
Equity [Line Items]
Issuance of deferred distribution units to Sunoco		$ 20.0
Class A Units [Member] \| General Partner [Member]
Equity [Line Items]
Issuance of Class A units to general partners \| shares		3.9
$395 Million Credit Facility [Member]
Equity [Line Items]
Credit facility, maximum borrowing capacity				$ 395.0

Cash Distributions (Narrative) (Details) - USD ($)		1 Months Ended			3 Months Ended	12 Months Ended			36 Months Ended
Cash Distributions (Narrative) (Details) - USD ($)	Jan. 26, 2012	Feb. 14, 2012	Feb. 28, 2010	Jan. 31, 2010	Dec. 31, 2011	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2011
Promissory note issued to general partner				$ 201,000,000
Maximum incentive percentage distribution received by General Partner						50.00%
Senior noted principal amount			$ 500,000,000
Distribution made to member or limited partner, distributions declared, per unit	$ 0.42
Annualized distribution made to limited partner distributions declared per unit					$ 1.68
Total distribution		$ 55,000,000				$ 218,000,000	$ 193,000,000	$ 173,000,000
Distribution to general partner		$ 14,000,000
Incentive distribution, minimum threshold						$ 0.1667
February 12, 2010 [Member]
Distribution to general partner									$ 14,000,000
Senior Notes - 5.50%, Due February 2020 [Member]
Debt instrument, maturity date			Feb. 01, 2020
Senior Notes - 6.85%, Due February 2040 [Member]
Debt instrument, maturity date			Feb. 01, 2040

Cash Distributions (Schedule Of Cash Distribution To Limited And General Partners) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended	36 Months Ended
	Feb. 14, 2012	Dec. 31, 2011	Dec. 31, 2011
Distribution Made to Member or Limited Partner [Line Items]
Distribution to general partner	$ 14.0
November 14, 2011 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.4133
Annualized Cash Distribution per Limited Partner Unit			$ 1.6532
Total Cash Distribution to the Limited Partners			$ 41.0
Distribution to general partner			$ 13.0
Cash Distribution Payment Date		November 14, 2011
August 12, 2011 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.4050
Annualized Cash Distribution per Limited Partner Unit			$ 1.6200
Total Cash Distribution to the Limited Partners			$ 40.0
Distribution to general partner			$ 13.0
Cash Distribution Payment Date		August 12, 2011
May 13, 2011 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3983
Annualized Cash Distribution per Limited Partner Unit			$ 1.5932
Total Cash Distribution to the Limited Partners			$ 40.0
Distribution to general partner			$ 12.0
Cash Distribution Payment Date		May 13, 2011
February 14, 2011 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3933
Annualized Cash Distribution per Limited Partner Unit			$ 1.5732
Total Cash Distribution to the Limited Partners			$ 39.0
Distribution to general partner			$ 12.0
Cash Distribution Payment Date		February 14, 2011
November 12, 2010 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3900
Annualized Cash Distribution per Limited Partner Unit			$ 1.5600
Total Cash Distribution to the Limited Partners			$ 39.0
Distribution to general partner			$ 12.0
Cash Distribution Payment Date		November 12, 2010
August 13, 2010 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3800
Annualized Cash Distribution per Limited Partner Unit			$ 1.5200
Total Cash Distribution to the Limited Partners			$ 35.0
Distribution to general partner			$ 11.0
Cash Distribution Payment Date		August 13, 2010
May 14, 2010 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3717
Annualized Cash Distribution per Limited Partner Unit			$ 1.4867
Total Cash Distribution to the Limited Partners			$ 35.0
Distribution to general partner			$ 10.0
Cash Distribution Payment Date		May 14, 2010
February 12, 2010 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3633
Annualized Cash Distribution per Limited Partner Unit			$ 1.4533
Total Cash Distribution to the Limited Partners			$ 34.0
Distribution to general partner			$ 14.0
Cash Distribution Payment Date		February 12, 2010
November 14, 2009 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3550
Annualized Cash Distribution per Limited Partner Unit			$ 1.4200
Total Cash Distribution to the Limited Partners			$ 33.0
Distribution to general partner			$ 13.0
Cash Distribution Payment Date		November 14, 2009
August 14, 2009 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3467
Annualized Cash Distribution per Limited Partner Unit			$ 1.3867
Total Cash Distribution to the Limited Partners			$ 32.0
Distribution to general partner			$ 13.0
Cash Distribution Payment Date		August 14, 2009
May 15, 2009 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3383
Annualized Cash Distribution per Limited Partner Unit			$ 1.3533
Total Cash Distribution to the Limited Partners			$ 31.0
Distribution to general partner			$ 12.0
Cash Distribution Payment Date		May 15, 2009
February 14, 2009 [Member]
Distribution Made to Member or Limited Partner [Line Items]
Cash Distribution per Limited Partner Unit			$ 0.3300
Annualized Cash Distribution per Limited Partner Unit			$ 1.3200
Total Cash Distribution to the Limited Partners			$ 29.0
Distribution to general partner			$ 10.0
Cash Distribution Payment Date		February 14, 2009

Management Incentive Plan (Narrative) (Details)
$ in Millions

12 Months Ended

Dec. 31, 2011

USD ($)

years

Dec. 31, 2010

USD ($)

Dec. 31, 2009

USD ($)

Aggregate grant of restricted units and unit options from LTIP | shares

800,000

Shares granted | shares

^[1]

189,714

272,427

299,403

Minimum percentage of restricted shares issued

0.00%

Maximum percentage of restricted shares issued

200.00%

Intrinsic value of restricted units

$ 18

$ 9

$ 7

Compensation cost

$ 4

Recognized in expense weighted-average period (in years) | years

1.8

Distribution yield average closing period (in days)

Restricted stock unit vest period, (in years)

three

LTIP [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Recognized share-based compensation expense

$ 6

$ 5

[1]

Management Incentive Plan (Summarizes Information Restricted Unit Award Activity) (Details) - $ / shares

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Management Incentive Plan [Abstract]

Number of Units, Granted, non-vested and outstanding, Beginning Balance

444,093

467,985

402,408

Number of Units, Granted

^[1]

189,714

272,427

299,403

Number of Units, Performance Factor adjustment

184,113

131,760

149,286

Number of Units, Vested

(449,055)

(326,130)

(322,725)

Number of Units, Cancelled/forfeited

(23,010)

(101,949)

(60,387)

Number of Units, Granted, non-vested and outstanding, Ending Balance

345,855

444,093

467,985

Weighted Average Grant-Date Fair Value, Beginning Balance

$ 22.59

$ 19.13

$ 18.33

Weighted Average Grant-Date Fair Value, Granted

^[1]

31.13

24.87

19.92

Weighted Average Grant-Date Fair Value, Performance Factor adjustment

19.88

17.65

18.68

Weighted Average Grant-Date Fair Value, Vested

19.87

14.41

18.75

Weighted Average Grant-Date Fair Value, Cancelled/forfeited

27.66

20.92

18.61

Weighted Average Grant-Date Fair Value, Ending Balance

$ 28.17

$ 22.59

$ 19.13

[1]

Management Incentive Plan (Schedule Of Fair Value Assumptions) (Details) - $ / shares

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Expected unit-price volatility

24.60%

25.90%

29.10%

Distribution yield

5.40%

6.40%

7.40%

Risk-free interest rate

1.00%

1.60%

1.30%

Weighted average fair value of performance units granted during the year

^[1]

$ 31.13

$ 24.87

$ 19.92

Performance Units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Weighted average fair value of performance units granted during the year

$ 31.51

$ 25.16

$ 19.92

[1]

Derivatives And Risk Management (Narrative) (Details)	Dec. 31, 2011	Dec. 31, 2010
Derivatives And Risk Management [Abstract]
Derivative positions of refined products	1.5	0.7

Derivatives And Risk Management (Schedule Of Derivative Assets And Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2011	Dec. 31, 2010
Derivatives And Risk Management [Abstract]
Derivative assets	$ 6	$ 2
Derivative liabilities	(2)	(6)
Derivative asset and liability, Net	$ 4	$ (4)

Fair values as of the balance sheet date of all assets resulting from contracts that meet the criteria of being accounted for as derivative instruments, net of the effects of master netting arrangements.

Fair values as of the balance sheet date of all liabilities resulting from contracts that meet the criteria of being accounted for as derivative instruments, net of the effects of master netting arrangements.

Segment Reporting, Revenue Reconciling Item [Line Items]

Derivatives And Risk Management (Schedule Of Derivative Instruments, Gain (Loss) In Statement Of Financial Performance) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Derivatives Designated As Cash Flow Hedging Instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Other Comprehensive Income	$ 4
Pretax Gains (Losses) Recognized in Earnings	1
Derivatives Designated As Cash Flow Hedging Instruments [Member] \| Sales And Other Operating Revenue [Member] \| Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Other Comprehensive Income	4
Pretax Gains (Losses) Recognized in Earnings	(1)
Derivatives Designated As Cash Flow Hedging Instruments [Member] \| Cost Of Product Sold And Operating Expenses [Member] \| Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Other Comprehensive Income
Pretax Gains (Losses) Recognized in Earnings	2
Derivatives Not Designated As Hedging Instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Earnings	5	(1)
Derivatives Not Designated As Hedging Instruments [Member] \| Sales And Other Operating Revenue [Member] \| Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Earnings	6	(1)
Derivatives Not Designated As Hedging Instruments [Member] \| Cost Of Product Sold And Operating Expenses [Member] \| Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax Gains (Losses) Recognized in Other Comprehensive Income
Pretax Gains (Losses) Recognized in Earnings	$ (1)

Fair Value Measurements (Details) - USD ($) $ in Millions	Dec. 31, 2011	Dec. 31, 2010
Fair Value Measurements [Abstract]
Aggregate fair value of senior notes	$ 1,910	$ 1,250
Senior notes carrying value	$ 1,700	$ 1,100

Concentration Of Credit Risk (Details)	12 Months Ended
Concentration Of Credit Risk (Details)	Dec. 31, 2011
Concentration Of Credit Risk [Abstract]
Percentage of total revenue derived from Sunoco	4.00%

Business Segment Information (Narrative) (Details) Boe in Millions	12 Months Ended
	Dec. 31, 2011 Boe states Mi	Dec. 31, 2010
Segment Reporting Information [Line Items]
Number of states the Partnership operates \| states	29
Refined Product Harbor Pipeline [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| Mi	100
Crude Oil Trunk Pipelines [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| Mi	4,900
Mesa Pipe Line System [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| Mi	100
Crude Oil Gathering Lines [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| Mi	500
Refined Product Terminals [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	8.0
Number of terminals	42
Sunoco's Marcus Hook Refinery [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	2.0
Sunoco's Philadelphia Refinery [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	3.0
Texas Gulf Coast Terminal [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	22.0
Inland Crude Oil Terminals [Member]
Segment Reporting Information [Line Items]
Number of terminals	1
Marine Crude Oil Terminals [Member]
Segment Reporting Information [Line Items]
Number of terminals	2
Liquefied Petroleum Gas Terminal [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	1.0
Eagle Point Terminal [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, barrels	5.0
Refined Products Pipeline [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| Mi	2,500
Terminal Facilities [Member]
Segment Reporting Information [Line Items]
Number of terminals		2
Crude Oil Pipeline [Member] \| Mesa Pipe Line System [Member]
Segment Reporting Information [Line Items]
Undivided interest	37.00%
Crude Oil Acquisition And Marketing [Member]
Segment Reporting Information [Line Items]
Number of transport trucks	170
Number of truck unloading facilities	110

Business Segment Information (Segment Reporting Information) (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2010

Sep. 30, 2010

Jun. 30, 2010

Mar. 31, 2010

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

^[1]

$ 10,905

$ 7,808

$ 5,402

$ 42

^[2]

112

$ 128

$ 121

$ 75

$ 83

$ 90

$ 70

$ 58

436

301

295

Net interest expense

Income before provision for income taxes

128

347

356

250

Provision for income taxes

Net Income attributable to noncontrolling interests

^[3]

^[4]

194

^[4]

322

348

250

Net Income Attributable to Sunoco Logistics Partners L.P.

193

313

346

250

Total sales and other operating revenue from Sunoco

$ 39

$ 303

$ 437

$ 293

$ 214

$ 173

432

1,117

706

Refined Products Pipeline [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

^[1]

130

120

128

Refined products pipeline

^[5]

Terminal Facilities [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

^[1]

435

287

207

Crude Oil Pipeline [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

^[1]

319

221

185

Refined products pipeline

^[6]

181

126

123

Crude Oil Acquisition And Marketing [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

^[1]

10,163

7,282

4,990

Intersegment Eliminations [Member]

137

Segment Reporting, Revenue Reconciling Item [Line Items]

Segment Reporting, Revenue Reconciling Item [Line Items]

^[1]

(142)

(102)

(108)

Sunoco [Member]

Total sales and other operating revenue from Sunoco

432

1,117

706

Sunoco [Member] | Refined Products Pipeline [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

Total sales and other operating revenue from Sunoco

Sunoco [Member] | Terminal Facilities [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

Total sales and other operating revenue from Sunoco

115

122

100

Sunoco [Member] | Crude Oil Pipeline [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

Total sales and other operating revenue from Sunoco

Sunoco [Member] | Crude Oil Acquisition And Marketing [Member]

Segment Reporting, Revenue Reconciling Item [Line Items]

Total sales and other operating revenue from Sunoco

247

$ 894

$ 502

Segment Reporting, Revenue Reconciling Item [Line Items]

Segment Reporting, Asset Reconciling Item [Line Items]

$ 11

[1]	Sales and other operating revenue includes amounts from Sunoco for the years ended December 31, 2011, 2010 and 2009 of:
[2]	In 2011, the Partnership recognized a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[3]	Net income for the fourth quarter 2011 includes a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge is comprised of a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[4]	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.
[5]	Operating income for the Refined Products Pipelines includes $12, $14 and $12 million for the years ended December 31, 2011, 2010 and 2009, respectively of equity income attributable to the Partnership's equity ownership interest in joint ventures.
[6]	Operating income for the Crude Oil Pipelines includes $12 and $13 million for the years ended December 31, 2010 and 2009, respectively of equity income attributable to the Partnership's equity ownership interest in joint ventures.

Business Segment Information (Segment Reporting Information - Other Financial Highlights) (Details)
$ in Millions

12 Months Ended

Dec. 31, 2011

USD ($)

Dec. 31, 2010

USD ($)

Dec. 31, 2009

USD ($)

Dec. 31, 2008

USD ($)

$ 213

^[1]

$ 174

^[2]

$ 176

^[3]

5,477

^[4]

4,188

^[5]

3,099

^[6]

396

252

$ 2

107

Deferred financing costs

Refined Products Pipeline [Member]

2,522

2,128

Segment Reporting, Asset Reconciling Item [Line Items]

^[1]

^[2]

^[3]

Terminal Facilities [Member]

736

^[4]

531

^[5]

476

^[6]

Segment Reporting, Asset Reconciling Item [Line Items]

121

^[1]

110

^[2]

110

^[3]

Crude Oil Pipeline [Member]

1,053

^[4]

$ 857

^[5]

598

^[6]

Number Of Terminals

Segment Reporting, Asset Reconciling Item [Line Items]

^[1]

$ 36

^[2]

^[3]

Crude Oil Acquisition And Marketing [Member]

1,055

^[4]

1,018

^[5]

583

^[6]

Segment Reporting, Asset Reconciling Item [Line Items]

^[1]

^[2]

^[3]

Corporate Activities [Member]

2,469

^[4]

1,695

^[5]

1,405

^[6]

Segment Reporting, Asset Reconciling Item [Line Items]

$ 13

107

Deferred financing costs

Quarterly Financial Data [Line Items]

$ 40

$ 32

[1]	Total capital expenditures exclude $396 million for the acquisition of a crude oil and marketing business, a refined products terminal in East Boston, an interest in the Inland refined products pipeline system and the Eagle Point tank farm and include $5 million of capital expenditures attributable to corporate activities.
[2]	Total capital expenditures exclude $252 million for the acquisition of the butane blending business, additional ownership interests in West Shore, Mid-Valley and West Texas Gulf, and two terminals and include $9 million of capital expenditures attributable to corporate activities.
[3]	Total capital expenditures exclude $50 million for the acquisitions of the Romulus refined products terminal and the Excel crude oil pipeline and include $13 million of capital expenditures attributable to corporate activities.
[4]	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $107 million advances to affiliates, $15 million deferred financing costs, and $40 million to properties, and plants and equipment, net.
[5]	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $44 million advances to affiliates, $9 million deferred financing costs, and $32 million to properties, and plants and equipment, net.
[6]	Total identifiable assets include the Partnership's unallocated $2 million cash and cash equivalents, $9 million advances to affiliates, $4 million deferred financing costs, and $22 million to properties, plants and equipment, net.

Quarterly Financial Data (Details)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2011

USD ($)

$ / shares

Sep. 30, 2011

USD ($)

$ / shares

Jun. 30, 2011

USD ($)

$ / shares

Mar. 31, 2011

USD ($)

$ / shares

Dec. 31, 2010

USD ($)

$ / shares

Sep. 30, 2010

USD ($)

$ / shares

Jun. 30, 2010

USD ($)

$ / shares

Mar. 31, 2010

USD ($)

$ / shares

Dec. 31, 2011

USD ($)

$ / shares

Dec. 31, 2010

USD ($)

$ / shares

Dec. 31, 2009

USD ($)

$ / shares

$ 51

$ 39

$ 303

$ 437

$ 293

$ 214

$ 173

$ 432

$ 1,117

$ 706

3,325

2,808

2,385

1,955

1,786

1,583

1,815

1,507

10,473

6,691

4,696

Gross margin

^[1]

173

148

139

101

Operating income

112

128

121

436

301

295

Net Income attributable to noncontrolling interests

^[2]

^[3]

194

^[3]

322

348

250

Net Income Attributable to Sunoco Logistics Partners L.P.

193

313

346

250

Less: General Partner's interest

(14)

(12)

(15)

(11)

(10)

(54)

(48)

(52)

Limited Partners' interest

$ 62

$ 81

$ 80

$ 36

$ 47

$ 178

$ 40

$ 33

$ 259

$ 298

$ 198

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit - basic | $ / shares

0.60

0.78

0.80

0.36

0.47

1.87

0.43

0.35

2.56

^[4]

3.13

^[4]

2.17

^[4]

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit - diluted | $ / shares

0.60

0.78

0.80

0.36

0.47

1.86

0.43

0.35

2.54

^[4]

3.11

^[4]

2.16

^[4]

Gain on investments in affiliates (Note 2)

$ 128

$ 42

^[5]

$ 3

^[5]

Quarterly Financial Data [Line Items]

Condensed Financial Statements, Captions [Line Items]

$ 11

[1]	Gross margin equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.
[2]	Net income for the fourth quarter 2011 includes a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge is comprised of a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[3]	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.
[4]	Reflects the fourth quarter 2011 three-for-one unit split.
[5]	In 2011, the Partnership recognized a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.

Supplemental Condensed Consolidating Financial Information (Consolidated Statement Of Income) (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2010

Sep. 30, 2010

Jun. 30, 2010

Mar. 31, 2010

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

$ 51

$ 39

$ 303

$ 437

$ 293

$ 214

$ 173

$ 432

$ 1,117

$ 706

3,325

2,808

2,385

1,955

1,786

1,583

1,815

1,507

10,473

6,691

4,696

Other income

Cost of products sold and operating expenses

10,918

7,838

5,430

10,264

7,398

5,023

Selling, general and administrative expenses

^[1]

Total Costs and Expenses

10,482

7,537

5,135

Net interest cost to affiliates

112

128

121

436

301

295

Other interest cost and debt expense, net

Capitalized interest

(7)

(5)

(4)

128

Provision for income taxes

347

356

250

Net Income attributable to noncontrolling interests

^[2]

^[3]

194

^[3]

322

348

250

Net Income attributable to Sunoco Logistics Partners L.P.

$ 76

$ 95

$ 94

$ 48

$ 59

$ 193

$ 51

$ 43

313

346

250

Parent Guarantor [Member]

Condensed Financial Statements, Captions [Line Items]

Equity in earnings of subsidiaries

313

346

250

313

346

250

313

346

250

313

346

250

Net Income attributable to Sunoco Logistics Partners L.P.

313

346

250

313

346

250

Subsidiary Issuer [Member]

Condensed Financial Statements, Captions [Line Items]

Equity in earnings of subsidiaries

399

416

292

399

416

292

Net interest cost to affiliates

399

416

292

(1)

(3)

Other interest cost and debt expense, net

Capitalized interest

(7)

(5)

(4)

313

346

250

Net Income attributable to Sunoco Logistics Partners L.P.

313

346

250

313

346

250

Non-Guarantor Subsidiaries [Member]

Condensed Financial Statements, Captions [Line Items]

432

1,117

706

10,473

6,691

4,696

Other income

Cost of products sold and operating expenses

10,918

7,838

5,430

10,264

7,398

5,023

Selling, general and administrative expenses

Total Costs and Expenses

10,482

7,537

5,135

Net interest cost to affiliates

436

301

295

128

Provision for income taxes

433

426

292

Net Income attributable to noncontrolling interests

408

418

292

Net Income attributable to Sunoco Logistics Partners L.P.

399

416

292

Consolidating Adjustments [Member]

Condensed Financial Statements, Captions [Line Items]

Equity in earnings of subsidiaries

(712)

(762)

(542)

(712)

(762)

(542)

(712)

(762)

(542)

(712)

(762)

(542)

Net Income attributable to Sunoco Logistics Partners L.P.

(712)

(762)

(542)

$ (712)

$ (762)

$ (542)

[1]	In 2011, the Partnership recognized a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge includes a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[2]	Net income for the fourth quarter 2011 includes a charge of $42 million for certain crude oil terminal assets which would be negatively impacted if Sunoco's Philadelphia refinery is permanently idled. The charge is comprised of a $31 million non-cash impairment for asset write-downs at the Fort Mifflin Terminal Complex and $11 million for regulatory obligations which would be incurred if these assets are permanently idled.
[3]	Net income for the third quarter 2010 includes a $128 million gain on investments in affiliates recorded in connection with the consolidation of Mid-Valley and West Texas Gulf. See Note 2.

Supplemental Condensed Consolidating Financial Information (Consolidated Balance Sheet) (Details) - USD ($)
$ in Millions

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

Condensed Financial Statements, Captions [Line Items]

$ 5

$ 2

Accounts receivable, affiliated companies

107

154

2,188

1,536

206

2,506

1,799

2,522

2,128

Intangible assets, net

277

109

5,477

^[1]

4,188

^[2]

3,099

^[3]

Current portion of long-term debt

2,111

1,591

250

112

Accrued taxes payable

Long-term debt, affiliated companies

2,535

1,711

100

Long-term debt

1,448

1,129

Other deferred credits and liabilities

Deferred income taxes

222

164

4,283

3,146

1,096

965

Noncontrolling interests

1,194

1,042

862

670

Parent Guarantor [Member]

5,477

4,188

Condensed Financial Statements, Captions [Line Items]

1,007

937

1,097

965

1,096

965

1,096

965

Subsidiary Issuer [Member]

1,097

965

Condensed Financial Statements, Captions [Line Items]

$ 2

2,680

2,135

2,743

2,191

Current portion of long-term debt

250

Long-term debt, affiliated companies

288

100

Long-term debt

1,448

1,129

1,736

1,254

1,007

937

1,007

937

Non-Guarantor Subsidiaries [Member]

2,743

2,191

Condensed Financial Statements, Captions [Line Items]

Accounts receivable, affiliated companies

(31)

154

2,188

1,536

206

2,366

1,722

2,522

2,128

Intangible assets, net

277

109

5,324

4,104

2,110

1,591

Accrued taxes payable

Other deferred credits and liabilities

2,246

1,686

Deferred income taxes

222

164

2,546

1,892

2,680

2,135

Noncontrolling interests

2,778

2,212

Consolidating Adjustments [Member]

5,324

4,104

Condensed Financial Statements, Captions [Line Items]

(3,687)

(3,072)

(3,687)

(3,072)

(3,687)

(3,072)

(3,687)

(3,072)