View Filing Data

$ 2,205

$ 2,317

$ 2,996

$ 2,453

$ 3,819

$ 4,616

$ 4,412

$ 4,171

$ 9,971

$ 17,018

$ 15,073

100

206

119

299

409

306

515

1,070

1,566

Total Revenues

10,486

18,088

16,639

Cost of products sold

9,145

16,877

15,600

Operating expenses

164

172

122

103

118

Impairment charge and other matters (Notes 2 and 6)

382

296

265

118

103

(100)

258

162

^[1]

258

^[1]

9,956

17,721

16,079

Interest cost to affiliates, net (Note 4)

307

(112)

172

180

127

530

367

560

(1)

(210)

(146)

(97)

Capitalized interest

Other income

418

325

504

(21)

(25)

(30)

Net income attributable to noncontrolling interests

277

(125)

157

158

110

397

^[2]

300

^[2]

474

^[2]

(1)

(2)

(3)

(9)

(11)

Net income attributable to redeemable noncontrolling interests (Note 3)

(1)

Net Income Attributable to Sunoco Logistics Partners L.P.

276

(127)

155

156

107

393

291

463

Less: General Partner's interest

(83)

(74)

(71)

(60)

(50)

(49)

(44)

(38)

(288)

(181)

(124)

Limited Partners’ interest

$ (58)

$ (18)

$ 205

$ (24)

$ (177)

$ 106

$ 112

$ 69

$ 105

$ 110

$ 339

Net Income attributable to Sunoco Logistics Partners L.P per Limited Partner unit (Note 5):

Basic (in dollars per unit)

$ (0.21)

$ (0.07)

$ 0.83

$ (0.10)

$ (0.80)

$ 0.50

$ 0.54

$ 0.33

$ 0.42

^[3]

$ 0.52

^[3]

$ 1.63

^[3]

Diluted (in dollars per unit)

$ (0.21)

$ (0.07)

$ 0.83

$ (0.10)

$ (0.80)

$ 0.50

$ 0.53

$ 0.33

$ 0.42

^[3]

$ 0.51

^[3]

$ 1.63

^[3]

Weighted Average Limited Partners Units Outstanding [Abstract]

Basic (in units)

^[3]

250.9

212.9

207.6

Diluted (in units)

^[3]

251.7

214.1

208.6

$ (1)

$ 1

$ 0

Less: Comprehensive income attributable to noncontrolling interests

(1)

Comprehensive Income

396

301

474

(3)

(9)

(11)

Less: Comprehensive income attributable to redeemable noncontrolling interests

(1)

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

$ 392

$ 292

$ 463

[1]	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.
[2]	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.
[3]	Amounts reflect the second quarter 2014 two-for-one stock split.

Consolidated Statements of Comprehensive Income (Parenthetical)		3 Months Ended
	Jun. 12, 2014	Jun. 30, 2014
Statement of Comprehensive Income Parenthetical [Abstract]
Stock split conversion ratio	2	2

Consolidated Balance Sheets - USD ($)

Dec. 31, 2015

Dec. 31, 2014

Assets

Accounts receivable, affiliated companies (Note 4)

$ 37,000,000

$ 101,000,000

20,000,000

9,000,000

1,165,000,000

1,766,000,000

Inventories (Note 6)

607,000,000

470,000,000

Other current assets

19,000,000

3,000,000

1,848,000,000

2,349,000,000

Less accumulated depreciation and amortization

11,527,000,000

9,358,000,000

^[1]

(835,000,000)

(509,000,000)

^[1]

Properties, plants and equipment, net (Note 7)

10,692,000,000

8,849,000,000

^[1]

Investment in affiliates (Note 8)

802,000,000

226,000,000

Goodwill (Note 9)

1,358,000,000

Intangible assets, net (Note 9)

718,000,000

770,000,000

71,000,000

66,000,000

15,489,000,000

^[2]

13,618,000,000

^[3]

Liabilities and Equity

Accounts payable, affiliated companies (Note 4)

1,251,000,000

1,934,000,000

39,000,000

21,000,000

Accrued taxes payable (Note 2)

329,000,000

304,000,000

44,000,000

52,000,000

Other deferred credits and liabilities

1,663,000,000

2,311,000,000

Long-term debt (Note 10)

5,591,000,000

4,234,000,000

125,000,000

71,000,000

Deferred income taxes (Note 2)

254,000,000

249,000,000

Commitments and contingent liabilities (Note 11)

7,633,000,000

6,865,000,000

Redeemable noncontrolling interests (Note 3)

15,000,000

Redeemable Limited Partners' interests (9,416,196 Class B units outstanding at December 31, 2015) (Note 12)

286,000,000

Equity

Limited Partners' interests (268,849,818 and 226,072,578 units outstanding at December 31, 2015 and 2014, respectively)

6,577,000,000

5,753,000,000

General Partner's interest

944,000,000

925,000,000

7,521,000,000

6,678,000,000

Noncontrolling interests

34,000,000

60,000,000

7,555,000,000

6,738,000,000

Net Cash Provided by (Used in) Operating Activities [Abstract]

$ 15,489,000,000

$ 13,618,000,000

[1]	December 31, EstimatedUseful Lives 2015 2014 (in years) (in millions)Land and land improvements (including rights-of-way) (1) — $1,286 $1,212Pipelines and related assets 16 - 39 5,943 4,253Terminals and storage facilities 20 - 41 1,985 1,457Buildings and improvements 25 - 32 509 245Other 3 - 20 177 133Construction-in-progress (2) 1,627 2,058Total properties, plants and equipment 11,527 9,358Less: Accumulated depreciation and amortization (835) (509)Total properties, plants and equipment, net $10,692 $8,849
[2]	Sales and other operating revenue for the periods presented includes the following amounts from ETP and its affiliates: Year Ended December 31, 2015 2014 2013 (in millions)Crude Oil $193 $866 $1,418Natural Gas Liquids 204 134 63Refined Products 118 70 85Total sales and other operating revenue $515 $1,070 $1,566Total sales and other operating revenue exclude $404, $309 and $280 million attributable to intrasegment activity for the years ended December 31, 2015, 2014 and 2013, respectively.
[3]	Total identifiable assets include the Partnership's unallocated $47 million cash and cash equivalents, $124 million of properties, plants and equipment, net, and $9 million of other assets.

Consolidated Balance Sheets (Parentheticals)	Dec. 31, 2015 shares	Dec. 31, 2014 shares
Consolidated Balance Sheets Parenthetical [Abstract]
Limited Partners' interests, units outstanding	268,849,818	226,072,578

Consolidated Statements of Cash Flows - USD ($)

12 Months Ended

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]

^[1]

$ 397,000,000

$ 300,000,000

$ 474,000,000

382,000,000

296,000,000

265,000,000

Deferred income tax expense (benefit)

^[2]

162,000,000

258,000,000

5,000,000

(4,000,000)

6,000,000

Amortization of bond premium

(13,000,000)

(14,000,000)

(23,000,000)

Non-cash compensation expense (Note 14)

17,000,000

16,000,000

14,000,000

Equity in earnings of unconsolidated affiliates

(24,000,000)

(25,000,000)

(21,000,000)

Distributions from unconsolidated affiliates

23,000,000

14,000,000

Increase (Decrease) in Operating Capital [Abstract]

(11,000,000)

4,000,000

8,000,000

602,000,000

445,000,000

(351,000,000)

Accounts payable and accrued liabilities

(299,000,000)

(105,000,000)

(117,000,000)

(667,000,000)

(570,000,000)

468,000,000

Accounts payable, affiliated companies

18,000,000

4,000,000

2,000,000

Accrued taxes payable

(8,000,000)

(19,000,000)

11,000,000

Unrealized (gains) losses on commodity risk management activities

4,000,000

(17,000,000)

(1,000,000)

Net cash provided by operating activities

10,000,000

(17,000,000)

598,000,000

566,000,000

749,000,000

Net Cash Provided by (Used in) Investing Activities [Abstract]

Acquisitions (Notes 3 and 8)

(2,706,000,000)

(2,416,000,000)

(897,000,000)

(131,000,000)

(433,000,000)

(60,000,000)

Change in long-term note receivable

(17,000,000)

Net cash used in investing activities

(2,854,000,000)

(2,866,000,000)

(957,000,000)

Net Cash Provided by (Used in) Financing Activities [Abstract]

Distributions paid to limited and general partners

(686,000,000)

(468,000,000)

(353,000,000)

Distributions paid to noncontrolling interests

(3,000,000)

(4,000,000)

(13,000,000)

Contributions from general partner

2,000,000

Net proceeds from issuance of limited partner units

1,519,000,000

839,000,000

Payments of statutory withholding on net issuance of limited partner units under LTIP

(11,000,000)

(9,000,000)

(3,000,000)

Repayments under credit facilities

(3,662,000,000)

(2,845,000,000)

(119,000,000)

Borrowings under credit facilities

4,039,000,000

2,795,000,000

215,000,000

Net proceeds from issuance of long-term debt

991,000,000

1,976,000,000

691,000,000

Repayments of senior notes

(175,000,000)

Advances to affiliated companies, net

239,000,000

(183,000,000)

Contributions attributable to acquisition from affiliate

11,000,000

12,000,000

9,000,000

Net cash provided by financing activities

(6,000,000)

2,192,000,000

2,362,000,000

244,000,000

Net change in cash and cash equivalents

(64,000,000)

62,000,000

36,000,000

Cash and cash equivalents at beginning of period

101,000,000

39,000,000

3,000,000

Cash and cash equivalents at end of period

$ 37,000,000

$ 101,000,000

$ 39,000,000

[1]	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.
[2]	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.

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

Total

General Partner [Member]

Common Stock [Member]

Limited Partner [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

Noncontrolling Interest [Member]

Balance, beginning (in units) at Dec. 31, 2012

$ 474

$ 124

$ 339

$ 11

^[1]

207.7

Balance, beginning at Dec. 31, 2012

6,195

897

$ 5,175

123

Increase (Decrease) in Stockholders' Equity [Roll Forward]

Total comprehensive income

$ 474

124

$ 339

$ 0

Non-cash compensation expense (in units)

0.1

0.0

^[1]

Distribution equivalent rights

$ 14

(2)

Payments of statutory withholding on net issuance of limited partner units under LTIP

(3)

Distributions

(366)

(110)

(243)

(13)

Contributions attributable to acquisition from affiliate

Increase attributable to acquisition from affiliate

Balance, ending (in units) at Dec. 31, 2013

$ (1)

^[1]

207.7

Balance, ending at Dec. 31, 2013

6,325

912

$ 5,292

121

Increase (Decrease) in Stockholders' Equity [Roll Forward]

300

181

110

Total comprehensive income

301

181

$ 110

Issuance of limited partner units to the public (in units)

^[1]

18.0

Issuance of limited partner units to the public

$ 841

$ 839

Non-cash compensation expense (in units)

0.4

^[1]

Distribution equivalent rights

$ 16

(4)

Payments of statutory withholding on net issuance of limited partner units under LTIP

(9)

Distributions

(472)

(166)

(302)

(4)

Contributions attributable to acquisition from affiliate

Increase attributable to acquisition from affiliate

Acquisition of a noncontrolling interest in consolidated subsidiary

(325)

(5)

(254)

(66)

Balance, ending (in units) at Dec. 31, 2014

$ (1)

^[1]

226.1

Balance, ending at Dec. 31, 2014

6,738

925

$ 5,752

Increase (Decrease) in Stockholders' Equity [Roll Forward]

396

288

105

Total comprehensive income

(1)

396

Total comprehensive income (loss)

395

288

$ 105

(1)

Issuance of limited partner units to the public (in units)

^[1]

42.3

Issuance of limited partner units to the public

$ 1,519

Non-cash compensation expense (in units)

0.4

^[1]

Distribution equivalent rights

$ 17

(2)

Payments of statutory withholding on net issuance of limited partner units under LTIP

(11)

Distributions

(689)

(261)

(425)

(3)

Contributions attributable to acquisition from affiliate

Increase attributable to acquisition from affiliate

Acquisition of a noncontrolling interest in consolidated subsidiary

(131)

(2)

(103)

(26)

Decrease attributable to issuance of Class B units (Note 12)

(292)

(5)

(287)

Balance, ending (in units) at Dec. 31, 2015

(1)

$ 1

^[1]

268.8

Balance, ending at Dec. 31, 2015

$ 7,555

$ 944

$ 6,577

$ 0

$ 34

[1]	Amounts reflect the second quarter 2014 two-for-one stock split.

Consolidated Statements of Equity (Parenthetical) (Parentheticals)		3 Months Ended
	Jun. 12, 2014	Jun. 30, 2014
Consolidated Statements of Partners' Capital Parenthetical [Abstract]
Stock split conversion ratio	2	2

Organization and Basis of Presentation	12 Months Ended
Organization and Basis of Presentation	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Organization and Basis of Presentation Sunoco Logistics Partners L.P. (the "Partnership" or "SXL") is a publicly traded Delaware limited partnership that owns and operates a logistics business, consisting of a geographically diverse portfolio of integrated pipeline, terminalling, and acquisition and marketing assets which are used to facilitate the purchase and sale of crude oil, natural gas liquids ("NGLs") and refined products. The Partnership conducts its business activities in 35 states located throughout the United States. Sunoco Partners LLC, a Pennsylvania limited liability company and the general partner of the Partnership, is a consolidated subsidiary of Energy Transfer Partners, L.P. ("ETP"), a publicly traded Delaware limited partnership. During the fourth quarter 2015, the Partnership realigned its reporting segments as a result of the continued investment in its organic growth capital program which has served to increase the integration that exists between its assets that service each commodity. This has also resulted in a shift in Management's strategic decision making process, resource allocation methodology, and assessment of the Partnership's financial results. The updated reporting segments are: Crude Oil, Natural Gas Liquids and Refined Products. The new segmentation will provide the Partnership's investors with a more meaningful view of its business that is consistent with that of Management. 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 earnings.

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2015

Accounting Policies [Abstract]

Significant Accounting Policies

Summary of Significant Accounting Policies

Principles of Consolidation

The consolidated financial statements reflect the results of the Partnership and its wholly-owned subsidiaries, including Sunoco Logistics Partners Operations L.P. (the "Operating Partnership"), 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. At December 31, 2015, the Partnership held a controlling financial interest in Inland Corporation ("Inland"), Mid-Valley Pipeline Company ("Mid-Valley"), and Price River Terminal, LLC ("PRT"), as well as a wholly-owned interest in West Texas Gulf Pipe Line Company ("West Texas Gulf"), and as such, these entities are reflected as consolidated subsidiaries of the Partnership. The Partnership is not the primary beneficiary of any variable-interest entities ("VIEs"). All significant intercompany accounts and transactions are eliminated in consolidation and noncontrolling interests in net income and equity are shown separately in the consolidated statements of comprehensive income and balance sheets. Equity ownership interests in corporate joint ventures in which the Partnership does not have a controlling financial interest, but over which the Partnership can exercise significant influence, are accounted for under the equity method of accounting.

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 amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.

Reclassification

Certain amounts in the prior years’ consolidated financial statements have been reclassified to conform to the current year presentation. The changes did not impact reported net income for any periods presented.

New Accounting Pronouncements

In the fourth quarter 2015, the Partnership adjusted its presentation of costs associated with issuances of debt in response to the early adoption of Accounting Standards Update ("ASU") 2015-03. This guidance requires costs incurred to issue certain debt instruments to be reflected as a reduction of the reported long-term debt liability within the consolidated balance sheet, as opposed to being reported as an asset. This change was retrospectively applied to all prior reporting periods presented, but did not impact the Partnership's overall financial position or results of operations.

The Partnership also adjusted its balance sheet presentation of deferred tax assets and liabilities in response to the early adoption of ASU 2015-17. This guidance requires all deferred tax assets and liabilities to be presented as noncurrent within the consolidated balance sheet, and is retrospectively applied to all prior reporting periods presented. This change did not impact the Partnership's financial position or results of operations.

In May 2014, the Financial Accounting Standards Board ("FASB") codified guidance in ASU 2014-09 related to the recognition of revenue from contracts with customers. The new guidance outlines the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration which the entity expects to be entitled in exchange for those goods or services. The guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods, with early adoption permitted. The Partnership is currently assessing the impact, if any, that adoption of new guidance will have on its consolidated financial position and results of operations.

Revenue Recognition

Pipeline revenues are recognized upon delivery of the barrels to the location designated by the shipper. Acquisition and marketing revenues for crude oil, NGLs and refined products are recognized when title to and risk of loss of the product is transferred to the customer. Terminalling and storage revenues are recognized at the time the services are provided. Revenues are not recognized for exchange transactions, which are entered into primarily to acquire a commodity 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 to cost of products sold in the consolidated statements of comprehensive income.

Affiliated revenues are generated from sales of crude oil, NGLs and refined products, as well as pipeline transportation, terminalling and storage services to ETP and its affiliates. Sales of crude oil, NGLs and refined products to affiliated entities are priced using market-based rates. Affiliated entities pay fees for transportation or terminalling services based on the terms and conditions of established agreements or 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, 2015 and 2014, cash equivalents consisted of time deposits and money market investments.

Accounts Receivable, Net

Accounts receivable represent valid claims against non-affiliated customers (see Note 4 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 customers' credit ratings. Outstanding customer receivable balances are regularly reviewed for possible non-payment indicators and reserves are recorded for doubtful accounts based upon management's expectations regarding collectability. Actual receivable 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, NGLs 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.

For the periods ended December 31, 2014 and 2015, a lower of cost or market ("LCM") adjustment was applied to the Partnership's crude oil, NGLs and refined products inventories due to the decline in market prices. Write downs are calculated based upon current replacement costs.

See Notes 6 and 18 for additional information on changes to the Partnership's inventory pools in connection with the realignment of its reporting segments and related to the LCM reserves and their impact to the Partnership's net income.

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 determined 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 estimated useful lives of the related assets.

Capitalized Interest

The Partnership capitalizes interest incurred on funds borrowed for contributions to joint venture interests and to certain capital projects during periods in which construction activities are in progress to bring those projects to their intended use.

Investment in Affiliates

Investment in affiliates, which consist of corporate joint ventures in which the Partnership does not have a controlling financial interest, but over which the Partnership can exercise significant influence, are accounted for under the equity method of accounting. Under this method, an investment is carried at cost, adjusted for the equity in income (loss), reduced for dividends received and adjusted for changes in accumulated other comprehensive income (loss). Income recognized from the Partnership's corporate joint venture interests is presented within other income in the consolidated statements of comprehensive 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 also presented within other income in the consolidated statements of comprehensive income.

Acquisitions

The Partnership records third-party business combinations 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 results of current operations. The results of operations of acquired businesses are included in the Partnership's results from the dates of acquisition.

Assets acquired and liabilities assumed in connection with acquisitions from entities under common control are recorded by the Partnership at the common control entity's net carrying value. The Partnership records any difference between the consideration paid and the carrying value of the net assets and liabilities as a distribution from, or contribution to, redeemable limited partner interests or equity, as applicable.

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. The Partnership's fair value measurements are classified within the fair value hierarchy established by GAAP based on the lowest level (least observable) input that is significant to the measurement in its entirety.

See Note 3 for additional information concerning the Partnership's recent acquisitions.

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.

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 in the fourth quarter, or more often if events or changes in circumstances indicate that the carrying value of goodwill may exceed its estimated fair value. The Partnership's general partner was acquired and became a consolidated subsidiary of ETP in the fourth quarter 2012. In connection with the acquisition, the Partnership elected to apply "push-down accounting" which required the Partnership's assets and liabilities to be adjusted to fair value on the closing date of the acquisition, which included an increase to the Partnership's goodwill balance of approximately $1.3 billion.

Management's process for evaluating goodwill for impairment involves estimating the fair value of the Partnership's reporting units that include goodwill. During the fourth quarter 2015, the Partnership realigned its reporting segments and, in accordance with accounting guidance, was required to test its goodwill balance for impairment both before and after the change in its reportable segments. As a result of the recent volatility within the energy markets, the Partnership utilized the assistance of a third party valuation firm to develop models to estimate the fair value of each of its reporting units that contain goodwill.

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

During 2015, fair value of the reporting units was estimated using a combination of the discounted cash flow and market multiple methodologies. Under the discounted cash flow methodology, fair value was estimated using the present value of Management's projected cash flows for each reporting unit which was calculated using the expected return a market participant would require for each reporting unit. Under the market multiple methodology, a selection of peer group companies, which are similar from an operational or industry perspective, were considered in estimating market multiples. These multiples were applied to Management's projected Adjusted EBITDA in order to estimate fair value. For the 2015 impairment test, the fair value of the Partnership's legacy Crude Oil Acquisition and Marketing segment was determined to be approximately 3 percent less than its carrying value. In accordance with accounting guidance, if the fair value of the reporting unit is estimated to be less than its carrying value, a second test is performed to estimate the fair value of the reporting unit's assets and liabilities, which includes determining an implied goodwill value. The Partnership performed the second test and determined that the implied fair value of the Crude Oil Acquisition and Marketing segment's goodwill exceeded its current carrying value. As a result, the Partnership determined that its goodwill balance was not impaired for the period ended December 31, 2015.

Prior to 2015, the Partnership utilized a market multiple methodology to estimate the fair value of its reporting units. Under this approach, ratios of business enterprise value to EBITDA of comparable companies was used to estimate the fair value. Management established the estimated fair value by comparing the reporting unit to other companies that are similar, from an operational or industry perspective, and by considering risk characteristics in order to determine the risk profile relative to the comparable companies as a group. For the periods ended December 31, 2013 and 2014, the Partnership determined that goodwill was not impaired.

See Note 9 for additional information on the Partnership's goodwill balance.

Intangible Assets

The Partnership has acquired intangible assets, such as customer relationships 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 comprehensive 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 amounts reflected in the Partnership's consolidated financial statements are related to the operations of Inland, Mid-Valley and West Texas Gulf, all of which are 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.

The following table presents the components of income tax expense for the periods presented:



	Year Ended December 31,
	2015		2014			2013
	(in millions)
Federal
Current	$	15	$	24		$	21
Deferred	6		(5		)	6
State
Current	—		6			3
Deferred	—		—			—
Total income tax expense	$	21	$	25		$	30

The income taxes paid by Inland, Mid-Valley, and West Texas Gulf approximated current income tax expense for each year presented.

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, 2015 and 2014, the Partnership had $254 and $249 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 Inland, Mid-Valley, and West Texas Gulf.

Long-Term Incentive Plan

The Partnership accounts for the compensation cost associated with all unit-based payment awards at fair value and reports the related expense within operating expenses and selling, general and administrative expenses in the consolidated statements of comprehensive income. Unit-based compensation cost for all outstanding awards of restricted units is based on the grant date market price of the underlying unit. The Partnership recognizes unit-based compensation expense on a straight-line basis over the requisite service period. In accordance with the terms of certain awards, the recognition of compensation expense is accelerated for participants who become retirement-eligible during the applicable vesting period.

Asset Retirement Obligations

Asset retirement obligations ("AROs") represent the fair value of expected liabilities related to the future retirement of long-lived assets and are recorded at the time in which a legal obligation is incurred. A corresponding asset is recorded concurrently and is depreciated over the anticipated active life of the related long-lived asset. The value of the ARO is determined based on estimates and assumptions regarding ongoing maintenance and repair, asset repurposing costs, disposal costs and associated contractual obligations related to the Partnership's pipelines, terminal facilities, storage tanks, truck and leased assets. The Partnership bases these estimates on historical and budgeted costs, future inflation rates and credit-adjusted risk-free interest rates. These fair value assessments are considered to be level 3 measurements, as they are based on both observable and unobservable inputs.

The Partnership's consolidated balance sheets include AROs as a component of other deferred credits and liabilities of $88 and $41 million at December 31, 2015 and 2014, respectively. The increase in 2015 is primarily related to additional obligations associated with expansion capital and growth projects recently placed into service. 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 FASB. The Partnership generally applies a "market approach" to determine fair value. This method uses pricing and other information related to 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.

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 an 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 of 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. ("net income attributable to SXL") per limited partner unit by dividing net income attributable to SXL, after deducting the amounts allocated to the general partner’s interest and incentive distribution rights ("IDRs"), by the weighted average number of limited partner units and Class B 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 B unitholders based on the contractual terms of the partnership agreement. See Note 12 for additional information on the terms of the Class B units.

Acquisitions

12 Months Ended

Dec. 31, 2015

Business Combination and Asset Acquisition [Abstract]

Business Combination and Asset Acquisition

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 years ended December 31, 2015, 2014 and 2013:

•

In December 2014, the Partnership acquired an additional 28.3 percent ownership interest in the West Texas Gulf from Chevron Pipe Line Company for $325 million, increasing the Partnership's controlling financial interest to 88.6 percent. In January 2015, the Partnership acquired the remaining noncontrolling ownership interest in West Texas Gulf for $131 million. As these transactions represented the acquisition of ownership interest in a consolidated subsidiary, noncontrolling interest and partners’ equity were reduced by $92 and $364 million, respectively, in accordance with applicable accounting guidance. West Texas Gulf is reflected as a consolidated subsidiary within the Crude Oil segment.

•

In the second quarter 2014, the Partnership acquired a crude oil purchasing and marketing business from EDF Trading North America, LLC ("EDF"). The purchase consisted of a crude oil acquisition and marketing business and related assets which handle 20 thousand barrels per day. The acquisition also included a promissory note that was convertible to an equity interest in a rail facility (see below). The acquisition is included in the Crude Oil segment.

•

In the second quarter 2014, the Partnership acquired a 55 percent economic and voting interest in PRT, a rail facility in Wellington, Utah. As the Partnership acquired a controlling financial interest in PRT, the entity is reflected as a consolidated subsidiary of the Partnership from the acquisition date and is included in the Crude Oil segment. The terms of the acquisition provide PRT’s noncontrolling interest holders the option to sell their interests to the Partnership at a price defined in the purchase agreement. As a result, the noncontrolling interests attributable to PRT are excluded from the Partnership's total equity and are instead reflected as redeemable interests in the consolidated balance sheet.

The $65 million purchase price for the EDF and PRT acquisitions (net of cash received) consisted primarily of net working capital largely attributable to inventory ($24 million), properties, plants and equipment ($14 million), and intangible assets ($28 million). These fair value allocations also resulted in an increase to goodwill ($12 million) and redeemable noncontrolling interests ($15 million).

•

In the second quarter 2013, the Partnership acquired Sunoco, Inc.'s ("Sunoco") Marcus Hook Industrial Complex and related assets (the "Marcus Hook Industrial Complex") for $60 million in cash, including acquisition costs. The acquisition included terminalling and storage assets located in Pennsylvania and Delaware and commercial agreements, including a reimbursement agreement under which Sunoco will reimburse the Partnership $40 million for certain operating expenses of the Marcus Hook Industrial Complex through March 31, 2017. The reimbursement proceeds are reflected as contributions to equity. The Partnership will be indemnified against environmental liabilities resulting from events which occurred at the Marcus Hook Industrial Complex prior to the closing of the transaction. Since the transaction was with an entity under common control, the assets acquired and liabilities assumed were recorded by the Partnership at Sunoco's net carrying value plus acquisition costs. The difference between Sunoco's net carrying value and the consideration transferred was recorded by the Partnership as an increase to equity. The acquisition is included within the Natural Gas Liquids segment.

The $60 million purchase price for this acquisition (net of cash received) consisted primarily of current and long-term assets ($14 million) and properties, plants and equipment ($66 million); offset by on-taking of current and long term liabilities ($16 million).

No pro forma information has been presented as the impact of the acquisitions during 2015, 2014 and 2013 was not material in relation to the Partnership's consolidated results of operations or financial position.

Related Party Transactions

12 Months Ended

Dec. 31, 2015

Related Party Transactions

Acquisition of Sunoco

ETP acquired the Partnership's general partner interest in the fourth quarter 2012. The Partnership has various operating and administrative agreements with ETP and its affiliates, including the agreements described below. ETP and its affiliates perform the administrative functions defined in such agreements on the Partnership’s behalf.

Service and Commodity Sales Agreements

The Partnership is party to various agreements with ETP and its affiliates to provide pipeline, terminalling and storage services, in addition to agreements for the purchase and sale of crude oil, NGLs and refined products. This activity is reflected in affiliated revenues in the consolidated statements of comprehensive income.

The Partnership is party to the following commercial agreements with its affiliated entities:


•	Pipeline Operator Agreement: The Partnership has agreements with certain of its joint venture interests to serve as operators of their respective pipeline systems. The agreements include a specified management fee and have either a defined termination date or are able to be terminated by both parties in certain cases.


•	Refined Products Terminal Services Agreement: The Partnership has a five-year refined products terminal services agreement with Sunoco under which Sunoco may throughput refined products at the Partnership's terminals. The agreement contains no minimum throughput obligations for Sunoco. The agreement runs through February 2017.

•

Fort Mifflin Terminal Services Agreement: The Partnership has an agreement with Philadelphia Energy Solutions ("PES") relating to the Fort Mifflin terminal complex. Under this agreement, PES will deliver an average of 300 thousand barrels per day of crude oil and refined products per contract year at the Fort Mifflin facility. PES 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 PES to meet its minimum requirements under the agreement. The Partnership executed the ten-year agreement with PES in September 2012. The Partnership had a previous agreement with Sunoco, with terms similar to those contained in the agreement with PES.

These agreements also provide PES with the option to purchase the Fort Mifflin and Belmont terminals if certain triggering events occur, including a sale of substantially all of the assets or operations of the Philadelphia refinery, an initial public offering, or a public debt filing of more than $200 million. The purchase price for each facility would be established based on a fair value amount determined by designated third parties.

•

Inter-Refinery Pipeline Lease: In September 2012, Sunoco assigned its lease for the use of the Partnership's inter-refinery pipelines between the Philadelphia refinery and the Marcus Hook Industrial Complex to PES. Under the twenty-year lease agreement which expires in February 2022, PES leases the inter-refinery pipelines for an annual fee which escalates at 1.67 percent each January 1 for the term of the agreement. The lease agreement also requires PES 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 the years 2013 through 2015.


•	Marcus Hook Industrial Complex Storage and Terminalling Services: In connection with the 2013 acquisition of the Marcus Hook Industrial Complex, the Partnership assumed an agreement to provide butane storage and terminal services to PES at the facility. The 10 year agreement extends through September 2022.


•	Refined Products Storage Agreements: The Partnership has agreements with an affiliated entity to utilize storage services at the Mont Belvieu, Texas and Hattiesburg, Mississippi terminal locations. The agreements run through November 2018.


•	Purchase and Sale Agreements: The Partnership has agreements for the purchase and sale of crude oil, NGLs and refined products with affiliated entities. These agreements are negotiated at market-based rates, do not extend beyond 2016, and can be terminated by either party in certain cases.

•

Terminalling Services: The Partnership has agreements with affiliates for the use of its terminal assets, as well as its use of an affiliated terminal asset to facilitate the Partnership's acquisition and marketing activities. The agreements are based on market terms and negotiated based on the respective term. These agreements vary in duration and can be terminated by either party in certain cases.


•	Petroleum Products Supply Agreements: The Partnership has agreements to supply crude oil and condensate products to affiliated parties from their Texas terminalling facilities. The agreement is based on market terms and can be terminated by either party on a monthly basis.


•	Pipeline Agreements: The Partnership has agreements with affiliated parties to utilize its pipelines to supply their business needs. All pipeline movements are on the same terms that would be available to unaffiliated customers under similar terms and are based on published tariff rates on the respective pipeline.

Advances to/from Affiliate

The Partnership previously participated in Sunoco's centralized cash management program pursuant to a treasury services agreement. Under the program, the Partnership's cash receipts and cash disbursements were processed, together with those of Sunoco and its other subsidiaries, through Sunoco's cash accounts with a corresponding credit or charge to an affiliated account. The Partnership established separate cash accounts in the fourth quarter 2013, and ceased participation in Sunoco's cash management program in 2014.

Administrative Services

The Partnership has no employees. The operations of the Partnership are carried out by employees of the general partner. The Partnership reimburses the general partner and its affiliates for certain costs and other direct expenses incurred on the Partnership's behalf. These costs may be increased if the acquisition or construction of new assets or businesses requires an increase in the level of services received by the Partnership. Additional general and administrative costs incurred are paid directly by the Partnership.

Under the Omnibus Agreement, the Partnership pays ETP an annual administrative fee that includes expenses incurred by ETP and its affiliates to perform certain centralized corporate functions, such as legal, accounting, engineering, information technology, insurance, office space rental, and other corporate services, including the administration of employee benefit plans. The 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. These fees do 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 amounts incurred in connection with the centralized corporate functions and shared insurance costs were not material to the Partnership's results of operations during the three year period ended December 31, 2015.

The Partnership participates in various employee benefit plans with ETP and its affiliates, including employee and retiree medical, dental and life insurance plans, defined contribution 401(k) plans, incentive compensation plans and other such benefits. The total expense of benefit plan participation was $54, $45, and $36 million for the years ended December 31, 2015, 2014 and 2013, respectively. These expenses are reflected in operating expenses and selling, general and administrative expenses in the consolidated statements of comprehensive income.

Affiliated Revenues and Accounts Receivable, Affiliated Companies

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

Contributions Attributable to Acquisition from Affiliate

In the fourth quarter 2014, the Partnership acquired land at Eagle Point from Sunoco under a purchase option embedded in an existing lease. As a transaction between entities under common control, the land was recorded at Sunoco's historical carrying value, resulting in an increase to equity of $54 million.

Capital Contributions

During the years ended December 31, 2015, 2014 and 2013, the Partnership issued 0.4, 0.4 and less than 0.1 million limited partnership units, respectively, to participants in the Sunoco Partners LLC Long-Term Incentive Plan upon completion of award vesting requirements. As a result of these issuances of limited partnership units, the general partner contributed less than $0.5 million to the Partnership in 2014 and 2013 to maintain its two percent general partner interest. The Partnership recorded these amounts as capital contributions to equity within its consolidated financial statements. These contributions were previously required for the general partner to maintain its two percent general partner interest. In July 2014, the Partnership agreement was amended to remove the obligation of the general partner to make capital contributions upon the issuance of limited partner units to retain a two percent interest. Prior to this amendment, the general partner contributed $2 million in connection with the Partnership's issuance of limited partner units under its at-the-market equity offering program ("ATM" program) in 2014. The general partner did not make any capital contributions to the Partnership in 2015.

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

The entire disclosure for related party transactions. 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.

+ References + Details

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

12 Months Ended

Dec. 31, 2015

Earnings Per Share [Abstract]

The general partner's interest in net income attributable to SXL consists of its approximate two percent general partner interest and "incentive distributions," which are increasing percentages, up to 50 percent of quarterly distributions in excess of $0.0833 per limited partner unit (Note 13). The general partner was allocated net income attributable to SXL of $288 million (representing 73 percent of total net income attributable to SXL) for the year ended December 31, 2015; $181 million (representing 62 percent of total net income attributable to SXL) for the year ended December 31, 2014; $124 million (representing 27 percent of total net income attributable to SXL) for the year ended December 31, 2013. Diluted net income attributable to SXL per limited partner unit is calculated by dividing the limited partners' interest in net income attributable to SXL by the sum of the weighted average number of limited partner and Class B units outstanding, and the dilutive effect of incentive unit awards (Note 14).

The following table sets forth the reconciliation of the weighted average number of limited partner and Class B 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 periods presented:



	Year Ended December 31,
	2015	2014	2013
	(in millions)
Weighted average number of units outstanding—basic ⁽¹⁾	250.9	212.9	207.6
Add effect of dilutive incentive awards ⁽¹⁾	0.8	1.2	1.0
Weighted average number of units—diluted ⁽¹⁾	251.7	214.1	208.6


⁽¹⁾	Amounts reflect the second quarter 2014 two-for-one unit split (Note 12).

Inventories

12 Months Ended

Dec. 31, 2015

Inventory Disclosure [Abstract]

Property, Plant and Equipment [Abstract]

The components of inventories are as follows:



	December 31,
	2015		2014
	(in millions)
Crude oil	$	424	$	364
NGLs	83		90
Refined products	83		—
Refined products additives	3		4
Materials, supplies and other	14		12
Total Inventories	$	607	$	470

In connection with the realignment of the Partnership's reporting segments, a new refined products inventory pool was established during the fourth quarter 2015 which includes inventories such as gasoline and distillates. Previously, the volumes of these products being marketed under refined products strategies was not material to the Partnership's financial position or results of operations. The Partnership's investment in assets which facilitate the acquisition and marketing of refined products is expected to increase its volumes sold under these strategies. This change in the Partnership's asset capabilities, combined with the anticipated increase in volumes and significant pricing differentials between the refined products and NGLs commodities that the Partnership markets, resulted in the establishment of refined products inventories in a separate inventory pool. This will allow for better matching of revenues and expenses as these commodities are bought and sold. The inventory pool which was previously disclosed as Refined Products and NGLs, has been renamed to NGLs and includes butane blending activities and the acquisition and marketing of NGLs such as butane, propane and ethane.

In the fourth quarter 2014, the Partnership established LCM reserves of $231 and $27 million, respectively, on its crude oil and NGLs inventories as a result of declining commodity prices. The LCM reserves totaled $381, $37 and $2 million at December 31, 2015, on the Partnership's crude oil, NGLs and refined products inventories, respectively.

Properties, Plants and Equipment

12 Months Ended

Dec. 31, 2015

Properties, Plants and Equipment

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



		December 31,
	Estimated Useful Lives	2015			2014
	(in years)	(in millions)
Land and land improvements (including rights-of-way) ⁽¹⁾	—	$	1,286		$	1,212
Pipelines and related assets	16 - 39	5,943			4,253
Terminals and storage facilities	20 - 41	1,985			1,457
Buildings and improvements	25 - 32	509			245
Other	3 - 20	177			133
Construction-in-progress ⁽²⁾		1,627			2,058
Total properties, plants and equipment		11,527			9,358
Less: Accumulated depreciation and amortization		(835		)	(509		)
Total properties, plants and equipment, net		$	10,692		$	8,849


⁽¹⁾	As of December 31, 2015 and 2014, the Partnership had rights-of-way with a book value of $1.1 and $1.0 billion, respectively.


⁽²⁾	As of December 31, 2015 and 2014, accrued capital expenditures were $286 and $283 million, respectively.

Investment in Affiliates

12 Months Ended

Dec. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Investment in Affiliates

The Partnership's ownership percentages in equity ownership interests as of December 31, 2015 and 2014 were as follows:



	December 31,
	2015	2014
Explorer Pipeline Company	13.3%	13.3%
Yellowstone Pipe Line Company	14.0%	14.0%
West Shore Pipe Line Company	17.1%	17.1%
Wolverine Pipe Line Company	31.5%	31.5%
Bayview Refining Company, LLC	49.0%	49.0%
SunVit Pipeline LLC	50.0%	50.0%
Bayou Bridge Pipeline LLC	30.0%	—%
Bakken Holdings Company LLC ("Bakken HoldCo") ⁽¹⁾	40.0%	—%


⁽¹⁾	The investment in Bakken HoldCo provides the Partnership with a 30 percent overall ownership interest in the Bakken pipeline project through its ownership in the subsidiary companies which will operate the pipeline system.

In October 2015, the Partnership finalized its participation in the Bakken pipeline project with ETP and Phillips 66. The Partnership obtained a 30 percent economic interest in the project which, combined with ETP's 45 percent interest, will be a consolidated subsidiary of ETP. The project consists of existing and newly constructed pipelines that are expected to provide aggregate takeaway capacity of approximately 450 thousand barrels per day of crude oil from the Bakken/Three Forks production area in North Dakota to key refinery and terminalling hubs in the Midwest and Gulf Coast, including the Partnership's Nederland terminal. The ultimate takeaway capacity target for the project is 570 thousand barrels per day. The Partnership expects to reach agreement to become the operator of the pipeline system, which is expected to begin commercial operations in the fourth quarter of 2016.

In exchange for its 30 percent economic interest in the project, the Partnership issued 9.4 million Class B units to ETP, representing limited partner interests in the Partnership, and paid $382 million in cash representing the Partnership’s proportionate share of contributions at the time of closing. Since the interest in the project was acquired from a related party, the Partnership's investment was recorded at ETP's historical carrying value. Subsequent contributions will be made by the joint partners in proportion to their respective economic ownership interests. The Partnership's investment in the Bakken Pipeline project is reflected as an equity method investment within the Crude Oil segment. See Note 12 for additional information on the issuance of the Class B units.

In July 2015, the Partnership entered into an agreement with ETP and Phillips 66 to participate in the Bayou Bridge Pipeline project. The Partnership obtained a 30 percent economic interest in the project, which combined with ETP's 30 percent ownership interest, will be a consolidated subsidiary of ETP. The project consists of a newly constructed pipeline that will deliver crude oil from Nederland, Texas to refinery markets in Louisiana. Commercial operations are expected to begin in the first quarter 2016. The Partnership will be the operator of the pipeline and will fund its proportionate share of the cost of the project, which will be accounted for as an equity method investment within the Partnership’s Crude Oil segment.

In the second quarter 2014, the Partnership entered into a joint agreement for a 49 percent economic and voting interest in Bayview Refining Company, LLC ("Bayview"). Bayview constructed the facility to process crude oil into intermediate petroleum products. The entity is a variable interest entity for which the Partnership is not the primary beneficiary. Construction was completed and the facility commenced operations in the third quarter 2015. The Partnership's investment in Bayview is reflected as an equity method investment within the Crude Oil segment.

In connection with the formation of Bayview, the joint owners agreed to guarantee the obligations of the entity with respect to certain third-party operating agreements over a ten-year term. The fair value of the liability recognized in connection with the guarantee was not material in relation to the Partnership’s financial position at December 31, 2015. The Partnership's note receivable from the joint owner of Bayview is reflected in other assets in the consolidated balance sheet.

In the first quarter 2014, the Partnership exercised its rights to acquire an additional ownership interest in Explorer Pipeline Company ("Explorer") from an affiliate of Chevron for $42 million, increasing the Partnership's ownership interest from 9.4 to 13.3 percent. Explorer owns a refined products pipeline running from the Gulf Coast of the United States to the Chicago, Illinois area. The fair value of the investment was estimated based on the fair value of the consideration transferred. The investment continues to be accounted for as an equity method investment within the Partnership's Refined Products segment, with the equity income recorded based on the Partnership's ownership percentage for each period presented.

At December 31, 2015, the Partnership's investments in Explorer Pipeline Company, Yellowstone Pipe Line Company, West Shore Pipe Line Company and Wolverine Pipe Line Company included net excess investment amounts of $123 million. The excess investment is the difference between the investment balances and the Partnership's equity in the net assets of the entities. The Partnership has not provided additional financial support to any of the Refined Products joint ventures during the 2013 through 2015 periods.

The Partnership had $52 million of undistributed earnings from its investments in corporate joint ventures within equity at December 31, 2015. During the years ended December 31, 2015, 2014 and 2013, the Partnership recorded equity income of $24, $25, and $21 million, respectively, and received dividends of $23, $14, and $14 million, respectively, from its investments in corporate joint ventures.

Goodwill and Other Intangible Assets

12 Months Ended

Dec. 31, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

Goodwill

In connection with the change in the Partnership's reporting segments in the fourth quarter 2015, goodwill was reassigned to the new reporting segments. The Partnership's legacy Crude Oil Pipelines, Crude Oil Acquisition and Marketing, and Terminal Facilities segments included goodwill of $200, $557, and $601 million, respectively. The goodwill related to the legacy Crude Oil Pipelines and Crude Oil Acquisition and Marketing segments was combined under the Partnership's new segment alignment, while the goodwill related to the legacy Terminal Facilities segment was allocated to the new segments based on a relative fair value basis. Subsequent to the realignment of its reporting segments, the Partnership's Crude Oil, Natural Gas Liquids, and Refined Products segments include goodwill of $912, $357 and $89 million, respectively.

The Partnership will continue to monitor the volatility in the energy markets and the impact it could have on the estimated fair value of its reporting segments. It is possible that continued negative volatility within these markets could change the Partnership's conclusion regarding whether goodwill is impaired.

Identifiable Intangible Assets

The Partnership's identifiable intangible assets are comprised of customer relationships and 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 17 years. Amortization expense related to these intangibles was $52, $52, and $49 million for the years ended December 31, 2015, 2014 and 2013, 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. The customer relationship intangible assets are amortized on a straight-line basis over their respective economic lives. Technology-related intangible assets consist of the Partnership's patents for blending of butane into refined products. These patents are amortized over their remaining legal lives.



	Weighted Average Amortization Period	December 31,
	Weighted Average Amortization Period	2015			2014
	(in years)	(in millions)
Gross
Customer relationships	18	$	836		$	836
Technology	10	47			47
Total gross		883			883
Accumulated amortization
Customer relationships		(149		)	(102		)
Technology		(16		)	(11		)
Total accumulated amortization		(165		)	(113		)
Total Net		$	718		$	770

The Partnership forecasts $51 million of annual amortization expense for each year through the year 2020 for its intangible assets.

Intangible assets attributable to rights-of-way are included in properties, plants and equipment in the Partnership's consolidated balance sheets at December 31, 2015 and 2014 (Note 7).

Commitments and Contingencies Disclosure [Abstract]

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.

+ References + Details

Debt

12 Months Ended

Dec. 31, 2015

Debt Disclosure [Abstract]

Debt

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



	December 31,
	2015			2014
	(in millions)
Credit Facilities
$2.50 billion Credit Facility, due March 2020	$	562		$	150
$35 million Credit Facility, matured and repaid April 2015	—			35
Senior Notes
Senior Notes - 6.125%, due May 2016 ⁽¹⁾	175			175
Senior Notes - 5.50%, due February 2020	250			250
Senior Notes - 4.40%, due April 2021	600			—
Senior Notes - 4.65%, due February 2022	300			300
Senior Notes - 3.45%, due January 2023	350			350
Senior Notes - 4.25%, due April 2024	500			500
Senior Notes - 5.95%, due December 2025	400			—
Senior Notes - 6.85%, due February 2040	250			250
Senior Notes - 6.10%, due February 2042	300			300
Senior Notes - 4.95%, due January 2043	350			350
Senior Notes - 5.30%, due April 2044	700			700
Senior Notes - 5.35%, due May 2045	800			800
Unamortized fair value adjustments ⁽²⁾	93			106
Total debt	5,630			4,266
Less:
Unamortized bond discount and debt issuance costs ⁽³⁾	(39		)	(32		)
Long-term debt	$	5,591		$	4,234


⁽¹⁾	The 6.125 percent Senior Notes were classified as long-term debt at December 31, 2015 as the Partnership has the ability and intent to refinance such borrowings on a long-term basis.


⁽²⁾	Represents fair value adjustments on senior notes resulting from the application of push-down accounting in connection with the acquisition of the Partnership's general partner by ETP on October 5, 2012.


⁽³⁾	In the fourth quarter 2015, the Partnership adopted accounting guidance which requires certain debt issuance costs to be reflected as a reduction in the total long-term debt liability for all periods presented. The net long-term debt balance now includes $32 and $26 million of debt issuance costs at December 31, 2015 and 2014, respectively. Refer to Note 2 for additional information.

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



Year Ended December 31,	(in millions)
2016	$	175
2017	—
2018	—
2019	—
2020	812
Thereafter	4,550
Total	$	5,537

Cash payments for interest related to long-term debt instruments, net of capitalized interest (Note 2), were $137, $64, and $83 million for the years ended December 31, 2015, 2014 and 2013, respectively.

Credit Facilities

In March 2015, the Operating Partnership amended and restated its $1.50 billion Credit Facility, which was scheduled to mature in November 2018. The amended and restated credit facility is a $2.50 billion unsecured revolving credit agreement (the "$2.50 billion Credit Facility"), which matures in March 2020, will continue to fund the Partnership's working capital requirements, finance acquisitions and capital projects, and be used for general partnership purposes. The $2.50 billion Credit Facility contains an "accordion" feature, under which the total aggregate commitment may be extended to $3.25 billion under certain conditions. In June 2015, the $2.50 billion Credit Facility was amended to create a segregated tranche of borrowings that will be guaranteed by ETP in connection with the Partnership's investment in the Bakken pipeline project. The amendment did not modify the outstanding borrowings, total capacity or terms of the facility. In September 2015, the Operating Partnership initiated a commercial paper program under the borrowing limits established by its $2.50 billion Credit Facility. As of December 31, 2015, there were no outstanding borrowings related to the commercial paper program. The facility bears interest at LIBOR or the Base Rate (as defined in the facility), each plus an applicable margin. The credit facility may be repaid at any time. Outstanding borrowings under this credit facility were $562 and $150 million at December 31, 2015 and 2014, respectively.

The $2.50 billion Credit Facility contains various covenants including limitations on the creation of indebtedness and liens, and related to the operation and conduct of the business of the Partnership and its subsidiaries. The credit facility also limits the Partnership, on a rolling four quarter basis, to a maximum total consolidated debt to consolidated Adjusted EBITDA ratio, as defined in the underlying credit agreement, of 5.0 to 1, which can generally be increased to 5.5 to 1 during an acquisition period. The Partnership's ratio of total consolidated debt, excluding net unamortized fair value adjustments, to consolidated Adjusted EBITDA was 3.6 to 1 at December 31, 2015, as calculated in accordance with the credit agreement.

The West Texas Gulf $35 million revolving credit facility matured in April 2015 and was repaid with borrowings from the $2.50 billion Credit Facility.

Senior Notes

The Operating Partnership had $175 million of 8.75 percent senior notes which matured and were repaid in February 2014 with borrowings under the revolving $1.50 billion Credit Facility.

In November 2015, the Partnership issued $600 million of 4.40 percent senior notes and $400 million of 5.95 percent senior notes (the "2021 and 2025 Senior Notes"), due April 2021 and December 2025, respectively.

In November 2014, the Partnership issued $200 million of 4.25 percent senior notes and $800 million of 5.35 percent senior notes (the "2024 and 2045 Senior Notes"), due April 2024 and May 2045, respectively.

In April 2014, the Partnership issued $300 million of 4.25 percent senior notes and $700 million of 5.30 percent senior notes (the "2024 and 2044 Senior Notes"), due April 2024 and April 2044, respectively.

The net proceeds of $991 million and $1.98 billion from the 2015 and 2014 senior notes offerings, respectively, were used to repay outstanding borrowings on the $2.50 billion Credit Facility and for general partnership purposes. The terms and conditions of these senior notes offerings are comparable to those under other outstanding senior notes.

Debt Guarantee

The Partnership currently serves as guarantor of the senior notes and of any obligations under the $2.50 billion Credit Facility. This guarantee is full and unconditional. See Note 20 for supplemental condensed consolidating financial information.

Commitments and Contingent Liabilities

12 Months Ended

Dec. 31, 2015

Commitments and Contingencies Disclosure

Commitments and Contingent Liabilities

Total rental expense for the years ended December 31, 2015, 2014 and 2013 amounted to $22, $18, and $12 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, 2015 is as follows:



Year Ended December 31,	(in millions)
2016	$	8
2017	8
2018	4
2019	3
2020	3
Thereafter	—
Total	$	26

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, 2015 and 2014, there were accrued liabilities for environmental remediation in the consolidated balance sheets of $6 and $14 million, respectively. The accrued liabilities for environmental remediation do not include any amounts attributable to unasserted claims, since there are no unasserted claims that are probable of settlement or reasonably estimable, nor have any recoveries from insurance been assumed. Charges against income for environmental remediation totaled $8, $15, and $10, million for the years ended December 31, 2015, 2014, and 2013, respectively. The Partnership maintains insurance programs that cover certain of its existing or potential environmental liabilities. Claims for recovery of environmental liabilities and previous expenditures that are probable of realization were not material in relation to the Partnership's consolidated financial position at December 31, 2015 and 2014.

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, 2015, the aggregate of the estimated maximum additional reasonably possible losses, which relate to numerous individual sites, totaled $9 million.

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. 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, 2015. 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 financial position, results of operations or cash flows.

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 also indemnified the Partnership for 100 percent of all losses asserted within the first 21 years after the closing of the IPO. Sunoco's share of liability for claims asserted thereafter will decrease by 10 percent per 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.

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 Partnership's financial position, results of operations or cash flows at December 31, 2015. 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 Partnership's financial position, results of operations or cash flows at December 31, 2015.

Equity Offerings	12 Months Ended
Equity Offerings	Dec. 31, 2015
Equity [Abstract]
Equity Offerings	Equity Offerings In 2014, the Partnership established an at-the-market equity offering program which allows the Partnership to issue common units directly to the public and raise capital in a timely and efficient manner to finance its growth capital program, while supporting the Partnership's investment grade credit ratings. In the third quarters of 2014 and 2015, respectively, the Partnership filed registration statements which each established an additional $1.0 billion of capacity under the ATM program. For the years ended December 31, 2015 and 2014, the Partnership issued 26.8 and 10.3 million common units under this program, for proceeds of $890 and $477 million, net of $10 and $6 million in fees and commissions to managers, respectively. In March 2015, the Partnership completed an overnight public offering of 13.5 million common units for net proceeds of $547 million. In April 2015, an additional 2.0 million common units were issued for net proceeds of $82 million related to the exercise of an option in connection with the March 2015 offering. The net proceeds from these offerings were used to repay outstanding borrowings under the Partnership's revolving credit facility and for general partnership purposes. In September 2014, the Partnership completed an overnight public offering of 7.7 million common units for net proceeds of $362 million. The net proceeds from this offering were used to repay outstanding borrowings under the preceding $1.50 billion Credit Facility and for general partnership purposes. Issuance of Redeemable Limited Partners' Interests In October 2015, the Partnership issued 9.4 million Class B units to ETP in conjunction with the purchase of a 30 percent ownership interest in the Bakken pipeline. The Class B units represent 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 common units. The Class B units will automatically convert to common units on a one-for-one basis in the third quarter 2017. However, the Partnership can exercise an option to call the Class B units for $300 million. If not exercised, ETP can exercise a put right during the third quarter 2017, effective prior to the one-for-one conversion date, for the greater of $313.5 million or the fair market value of the units, as defined in the unitholder agreement. As a result of the available put option, the amount attributable to the Class B units is excluded from total equity and instead reflected as redeemable interests in the Partnership’s consolidated balance sheet.

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

Reference 1: 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.(d),(e))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21484-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SAB TOPIC 4.E)
-URI http://asc.fasb.org/extlink&oid=27010918&loc=d3e74512-122707

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21488-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.29-31)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 4
-Subparagraph (SAB TOPIC 4.C)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187143-122770

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6405834&loc=d3e23285-112656

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Preferred Stock
-URI http://asc.fasb.org/extlink&oid=6521494

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21463-112644

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21564-112644

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section E

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section C

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Cash Distributions

12 Months Ended

Dec. 31, 2015

Equity [Abstract]

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 $0.0833 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.

The following table shows the target distribution levels and distribution "splits" between the general partner and the holders of the Partnership's common units at December 31, 2015:



	Total Quarterly Distribution Target Amount	Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount	General Partner			Unitholders
Minimum Quarterly Distribution	$0.0750	2	%		98%
First Target Distribution	up to $0.0833	2	%		98%
Second Target Distribution	above $0.0833 up to $0.0958	15	%	⁽¹⁾	85%
Third Target Distribution	above $0.0958 up to $0.2638	37	%	⁽¹⁾	63%
Thereafter	above $0.2638	50	%	⁽¹⁾	50%


⁽¹⁾	Includes general partner interest.

Distributions paid by the Partnership on its common units for the periods presented were as follows:



Cash Distribution Payment Date	Cash Distribution per Limited Partner Unit ⁽¹⁾		Annualized Cash Distribution per Limited Partner Unit ⁽¹⁾		Total Cash Distribution to the Limited Partners		Total Cash Distribution to the General Partner
					(in millions)		(in millions)
November 13, 2015	$	0.4580	$	1.8320	$	119	$	76
August 14, 2015	$	0.4380	$	1.7520	$	111	$	69
May 15, 2015	$	0.4190	$	1.6760	$	103	$	62
February 13, 2015	$	0.4000	$	1.6000	$	92	$	54
November 14, 2014	$	0.3825	$	1.5300	$	84	$	49
August 14, 2014	$	0.3650	$	1.4600	$	77	$	43
May 15, 2014	$	0.3475	$	1.3900	$	72	$	39
February 14, 2014	$	0.3312	$	1.3248	$	69	$	35
November 14, 2013	$	0.3150	$	1.2600	$	65	$	32
August 14, 2013	$	0.3000	$	1.2000	$	62	$	29
May 15, 2013	$	0.2863	$	1.1452	$	59	$	26
February 14, 2013	$	0.2725	$	1.0900	$	57	$	23


⁽¹⁾	Amounts reflect the second quarter 2014 two-for-one unit split (Note 12).

On January 28, 2016, the Partnership declared a cash distribution of $0.479 per unit ($1.92 per unit, annualized) on its outstanding common units, representing the distribution for the quarter ended December 31, 2015. The $216 million distribution, including $85 million to the general partner, was paid on February 12, 2016 to unitholders of record at the close of business on February 8, 2016.

Management Incentive Plan

12 Months Ended

Dec. 31, 2015

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.

In December 2015, the Partnership's unitholders approved the Sunoco Partners LLC Long-Term Incentive Plan, as amended and restated (the "Restated LTIP"), which was previously approved by the board of directors of Sunoco Partners LLC, the Partnership's general partner. The Restated LTIP authorized an additional 10.0 million common units to be available under the plan; added additional types of awards that can be granted under the plan, such as phantom unit awards, unit appreciation rights, unrestricted unit awards and other unit-based awards ("plan awards"); added a prohibition on repricing of unit options and unit appreciation rights without the approval of the unitholders; provided for termination of the plan at the earliest date it is terminated by the board of directors, the date no more units remain available for grants, and December 1, 2025; and incorporated certain other administrative changes.

The Restated LTIP benefits eligible employees and directors of the general partner and its affiliates who perform services for the Partnership. The Restated 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 general partner's board of directors with respect to awards granted to the independent directors. At December 31, 2015, there were 9.7 million plan awards available for future grants under the Restated LTIP.

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. Such grants may include requirements related to the attainment of predetermined performance targets. The Compensation Committee may make additional grants under the Restated LTIP to employees and directors containing such terms as defined by the Compensation Committee. 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, at its discretion, may grant tandem distribution equivalent rights ("DERs") related 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. All units granted during the periods presented below included tandem DERs.

The Partnership's outstanding restricted unit awards are time-vested grants, the vesting of which occurs over a five-year period, and is conditioned solely upon continued employment or service as of the applicable vesting date.

The following table summarizes information regarding restricted unit award activity for the periods presented:



	Number of Units ⁽¹⁾		Weighted Average Grant Date Fair Value ⁽¹⁾
Granted, non-vested and outstanding, December 31, 2012	855,220		$	19.48
Granted	858,246		$	30.00
Performance factor adjustment ⁽²⁾	202,620		$	15.76
Vested	(563,668	)	$	18.33
Cancelled/forfeited	(73,256	)	$	24.19
Granted, non-vested and outstanding, December 31, 2013	1,279,162		$	26.19
Granted	719,009		$	41.59
Performance factor adjustment ⁽²⁾	229,828		$	17.52
Vested	(693,326	)	$	20.26
Cancelled/forfeited	(72,872	)	$	30.10
Granted, non-vested and outstanding, December 31, 2014	1,461,801		$	35.01
Granted	1,412,257		$	29.54
Vested	(245,563	)	$	22.08
Cancelled/forfeited	(90,776	)	$	36.83
Granted, non-vested and outstanding, December 31, 2015	2,537,719		$	33.16


⁽¹⁾	The unit volumes and fair values have been adjusted to reflect the June 12, 2014 two-for-one unit split.

⁽²⁾

Certain awards granted prior to October 5, 2012 were 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 caused the actual amount of units that ultimately vested to range between 0 to 200 percent of the original units granted.

The total fair value of restricted unit awards vested for the years ended December 31, 2015, 2014 and 2013, was $8, $30 and $21 million, respectively. As of December 31, 2015, estimated compensation cost related to non-vested awards not yet recognized was $52 million, and the weighted average period over which this cost is expected to be recognized in expense is 3.0 years. The fair value of the Partnership's time-vested awards is based on the grant date market price of the Partnership's common units.

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.

Based on the unit grants and performance factor adjustments outlined in the table above, the Partnership recognized unit-based compensation expense related to the awards granted under the LTIP and Restated LTIP within operating expenses and selling, general and administrative expenses in the consolidated statements of comprehensive income of $17, $16, and $14 million for the years ended December 31, 2015, 2014 and 2013, respectively. The tandem DERs associated with the restricted unit grants are recognized as a reduction of equity when earned.

Derivatives and Risk Management

12 Months Ended

Dec. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Risk Management

The Partnership is exposed to various risks, including volatility in the prices of the products that the Partnership markets, counterparty credit risk and changes in interest rates.

Price Risk Management

The Partnership is exposed to risks associated with changes in the market price of crude oil, NGLs and refined 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. In order to manage such exposure, the Partnership's policy is (i) to only purchase crude oil, NGLs 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) to not 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.

The physical contracts related to the Partnership's commodity purchase and sale activities that qualify as derivatives have been designated as normal purchases and sales and are accounted for using accrual accounting under United States' generally accepted accounting principles. The Partnership accounts for derivatives that do not qualify as normal purchases or sales at fair value. The Partnership currently does not utilize derivative instruments to manage its exposure to prices related to crude oil purchase and sale activities. All derivative balances are presented on a gross basis.

Pursuant to the Partnership's approved risk management policy, derivative contracts, such as swaps, futures and other derivative instruments, may be used to hedge or reduce exposure to price risk associated with acquired inventory or forecasted physical transactions. The Partnership utilizes derivative instruments to mitigate the risk associated with market movements in the price of NGLs, refined products, and other commodities as necessary. 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. Since 2013, the Partnership has not designated any of its derivative contracts as hedges for accounting purposes. Therefore, all realized and unrealized gains and losses from these derivative contracts are recognized in the consolidated statement of comprehensive income in the period in which they occur. The hedge ineffectiveness assessed on derivative contracts was not material during 2015, 2014 or 2013. All realized gains and losses associated with the Partnership's 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).

The Partnership had open derivative positions on 9.2 and 3.6 million barrels of NGLs and refined products at December 31, 2015 and 2014, respectively. The derivatives outstanding at December 31, 2015 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), of which positions at December 31, 2015 and 2014 were primarily categorized at level 2. As of December 31, 2015 and 2014, the fair values of the Partnership's derivative assets and liabilities were:



	December 31,
	2015			2014
	(in millions)
Derivative assets	$	30		$	29
Derivative liabilities	(18		)	(14		)
	$	12		$	15

Derivative asset and liability balances are recorded in accounts receivable and accrued liabilities, respectively, in the consolidated balance sheets.

The Partnership's derivative positions are comprised of commodity contracts. The following table sets forth the impact of derivatives on the Partnership's results of operations for the periods presented:



	Location of Gains (Losses) Recognized in Earnings	Gains (Losses) Recognized in Earnings
		(in millions)
Year Ended December 31, 2015
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	47
Commodity contracts	Cost of products sold	(26		)
Commodity contracts	Operating expenses	(1		)
		$	20
Year Ended December 31, 2014
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	81
Commodity contracts	Cost of products sold	(20		)
		$	61
Year Ended December 31, 2013
Derivatives designated as cash flow hedging instruments:
Commodity contracts	Sales and other operating revenue	$	(1	)
Commodity contracts	Cost of products sold	—
		$	(1	)
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	(7	)
Commodity contracts	Cost of products sold	1
		$	(6	)

Credit Risk Management

The Partnership maintains credit policies with regard to its counterparties that management believes minimize the overall credit risk through credit analysis, credit approvals, credit limits and monitoring procedures. The credit positions of the Partnership's customers are analyzed prior to the extension of credit and periodically after credit has been extended. 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, as the counterparties may be similarly affected by changes in economic, regulatory or other conditions.

Interest Rate Risk Management

The Partnership has interest rate risk exposure for changes in interest rates related to its outstanding borrowings. The Partnership manages its exposure to changes in interest rates through the use of a combination of fixed-rate and variable-rate financial instruments. At December 31, 2015, the Partnership had $562 million of consolidated variable-rate borrowings under the $2.50 billion Credit Facility.

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

Reference 1: 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

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624171-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41620-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624163-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5579240-113959

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4D
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624177-113959

Reference 7: 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=35736893&loc=d3e80784-113994

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41641-113959

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5579245-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4H
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624258-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80748-113994

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5708775-113959

Reference 13: 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=56946850&loc=SL5708773-113959

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5618551-113959

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5580258-113959

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4E
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624181-113959

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41638-113959

Reference 19: 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=26873400&loc=d3e23780-122690

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Disclosures	Fair Value Measurements The estimated fair value of the Partnership's financial instruments has been determined based on management's assessment of available market information and appropriate valuation methodologies. The Partnership's current assets (other than derivatives and inventories) and current liabilities (other than derivatives) 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. The estimated fair value of the Partnership's senior notes is determined using observable market prices, as these notes are actively traded (level 1). The estimated aggregate fair value of the senior notes at December 31, 2015 was $4.2 billion, compared to the carrying amount of $5.1 billion. The estimated aggregate fair value of the senior notes at December 31, 2014 was $4.1 billion, compared to the carrying amount of $4.1 billion.

Business Segment Information

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.

+ References + Details

Concentration of Credit Risk	12 Months Ended
Concentration of Credit Risk	Dec. 31, 2015
Risks and Uncertainties [Abstract]
Concentration Risk Disclosure	Concentration of Credit Risk The Partnership's 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 as the customers may be similarly affected by changes in economic, regulatory or other factors. The Partnership maintains credit policies with regard to its counterparties that management believes minimize the overall credit risk through credit analysis, credit approvals, credit limits and monitoring procedures. The credit positions of the Partnership's customers are analyzed prior to the extension of credit and periodically after it has been extended. For certain transactions, the Partnership may utilize letters of credit, prepayments, guarantees and secured interests in assets. In 2015 and 2014, approximately 23 and 25 percent of the Partnership's total revenues, respectively, were derived from two investment grade customers with crude oil sales and other revenues comprising greater than 10 percent of total revenues. While this concentration has the ability to negatively impact revenues going forward, management does not anticipate a material adverse effect in the Partnership's financial position, results of operations or cash flows as the absolute price levels for crude oil normally do not bear a relationship to gross profit. In addition, these customers are subject to netting arrangements which allow the Partnership to offset payable activities and mitigate credit exposure.

Business Segment Information

12 Months Ended

Dec. 31, 2015

Segment Reporting [Abstract]

The Partnership operates in 35 states throughout the United States and in three principal business segments.

During the fourth quarter 2015, the Partnership realigned its reporting segments as a result of the continued investment in its organic growth capital program which has served to increase the integration that exists between its assets that service each commodity. This has also resulted in a shift in Management's strategic decision making process, resource allocation methodology, and assessment of the Partnership's financial results. The updated reporting segments are: Crude Oil, Natural Gas Liquids and Refined Products. The new segmentation will provide the Partnership's investors with a more meaningful view of its business that is consistent with that of Management. 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 earnings.

•

The Crude Oil segment provides transportation, terminalling and acquisition and marketing services to crude oil markets throughout the southwest, midwest and northeastern United States. Included within the segment is approximately 5,900 miles of crude oil trunk and gathering pipelines in the southwest and midwest United States and equity ownership interests in three crude oil pipelines. Our crude oil terminalling services operate with an aggregate storage capacity of approximately 28 million barrels, including approximately 24 million barrels at our Gulf Coast terminal in Nederland, Texas and approximately 3 million barrels at our Fort Mifflin terminal complex in Pennsylvania. Our crude oil acquisition and marketing activities utilize our pipeline and terminal assets, our proprietary fleet crude oil tractor trailers and truck unloading facilities, as well as third-party assets, to service crude oil markets principally in the mid-continent United States.

•

The Natural Gas Liquids segment transports, stores, and executes acquisition and marketing activities utilizing a complementary network of pipelines, storage and blending facilities, and strategic off-take locations that provide access to multiple NGLs markets. The segment contains approximately 900 miles of NGLs pipelines, primarily related to our Mariner systems located in the northeast and southwest United States. Terminalling services are facilitated by approximately 5 million barrels of NGLs storage capacity, including approximately 1 million barrels of storage at our Nederland, Texas terminal facility and 3 million barrels at our Marcus Hook, Pennsylvania terminal facility (the "Marcus Hook Industrial Complex"). This segment also carries out our NGLs blending activities, including utilizing our patented butane blending technology.

•

The Refined Products segment provides transportation and terminalling services, utilizing approximately 1,800 miles of refined products pipelines and approximately 40 active refined products marketing terminals. Our marketing terminals are located primarily in the northeast, midwest and southeast United States, with approximately 8 million barrels of refined products storage capacity. The Refined Products segment includes our Eagle Point facility in New Jersey, which has approximately 6 million barrels of refined products storage capacity. The segment also includes our equity ownership interests in four refined products pipeline companies. The segment also performs terminalling activities at our Marcus Hook Industrial Complex. The Refined Products segment utilizes our integrated pipeline and terminalling assets, as well as acquisition and marketing activities, to service refined products markets in several regions of the United States.

The following table sets forth consolidated statement of comprehensive income information concerning the Partnership's business segments and reconciles total segment Adjusted EBITDA to net income attributable to SXL for the periods presented:



	Year Ended December 31,
	2015			2014			2013
	(in millions)
Sales and other operating revenue ⁽¹⁾
Crude Oil	$	8,956		$	16,899		$	15,953
Natural Gas Liquids	1,165			959			447
Refined Products	365			230			239
Total sales and other operating revenue	$	10,486		$	18,088		$	16,639
Depreciation and amortization
Crude Oil	$	216		$	191		$	176
Natural Gas Liquids	76			30			21
Refined Products	90			75			68
Total depreciation and amortization	$	382		$	296		$	265
Impairment charge and other matters ⁽²⁾
Crude Oil	$	150		$	231		$	—
Natural Gas Liquids	10			27			—
Refined Products	2			—			—
Total impairment charge and other matters	$	162		$	258		$	—
Capital expenditures ⁽³⁾
Crude Oil	$	1,377		$	801		$	369
Natural Gas Liquids	1,111			1,210			476
Refined Products	197			534			155
Corporate	24			14			18
Total capital expenditures	$	2,709		$	2,559		$	1,018
Adjusted EBITDA
Crude Oil	$	656		$	669		$	701
Natural Gas Liquids	333			203			73
Refined Products	164			99			97
Total Adjusted EBITDA	1,153			971			871
Interest expense, net	(134		)	(67		)	(77		)
Depreciation and amortization expense	(382		)	(296		)	(265		)
Impairment charge and other matters	(162		)	(258		)	—
Provision for income taxes	(21		)	(25		)	(30		)
Non-cash compensation expense	(17		)	(16		)	(14		)
Unrealized gain (loss) on commodity risk management activities	(4		)	17			1
Amortization of excess equity method investment	(2		)	(2		)	(2		)
Proportionate share of unconsolidated affiliates' interest, depreciation and provision for income taxes	(34		)	(24		)	(20		)
Non-cash accrued liability adjustment	—			—			10
Net Income ⁽⁴⁾	397			300			474
Net income attributable to noncontrolling interests	3			9			11
Net income attributable to redeemable noncontrolling interests	1			—			—
Net Income Attributable to Sunoco Logistics Partners L.P.	$	393		$	291		$	463


⁽¹⁾	Sales and other operating revenue for the periods presented includes the following amounts from ETP and its affiliates:



	Year Ended December 31,
	2015		2014		2013
	(in millions)
Crude Oil	$	193	$	866	$	1,418
Natural Gas Liquids	204		134		63
Refined Products	118		70		85
Total sales and other operating revenue	$	515	$	1,070	$	1,566

Total sales and other operating revenue exclude $404, $309 and $280 million attributable to intrasegment activity for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽²⁾	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.


⁽³⁾	Total capital expenditures exclude acquisitions and investments in equity ownership interests of $131, $448 and $60 million for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽⁴⁾	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.

The following table provides consolidated balance sheet information concerning the Partnership's business segments as of December 31, 2015, 2014 and 2013, respectively:



	Crude Oil		Natural Gas Liquids		Refined Products		Total
	(in millions)
As of December 31, 2015
Investment in affiliates	$	623	$	—	$	179	$	802
Goodwill	$	912	$	357	$	89	$	1,358
Identifiable assets ⁽¹⁾	$	8,802	$	3,764	$	2,747	$	15,489
As of December 31, 2014
Investment in affiliates	$	53	$	—	$	173	$	226
Goodwill	$	912	$	357	$	89	$	1,358
Identifiable assets ⁽²⁾	$	8,579	$	2,401	$	2,458	$	13,618
As of December 31, 2013
Investment in affiliates	$	3	$	—	$	122	$	125
Goodwill	$	900	$	357	$	89	$	1,346
Identifiable assets ⁽³⁾	$	8,233	$	1,442	$	1,894	$	11,890


⁽¹⁾	Total identifiable assets include the Partnership's unallocated $36 million cash and cash equivalents, $133 million of properties, plants and equipment, net, and $7 million of other assets.


⁽²⁾	Total identifiable assets include the Partnership's unallocated $47 million cash and cash equivalents, $124 million of properties, plants and equipment, net, and $9 million of other assets.


⁽³⁾	Total identifiable assets include the Partnership's unallocated $12 million cash and cash equivalents, $239 million of advances to affiliates, $66 million of properties, plants and equipment, net and $4 million of other assets.

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 Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8906-108599

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2015

Quarterly Financial Data

Quarterly Financial Data (Unaudited)

Summarized quarterly financial data is as follows:



	1st Quarter			2nd Quarter			3rd Quarter			4th Quarter
	(in millions, except per unit amounts)
2015
Sales and other operating revenue:
Unaffiliated customers	$	2,453		$	2,996		$	2,317		$	2,205
Affiliates	$	119		$	206		$	90		$	100
Gross profit ⁽¹⁾	$	214		$	326		$	325		$	312
Impairment charge and other matters	$	41		$	(100	)	$	103		$	118
Operating income	$	66		$	307		$	94		$	63
Net Income	$	37		$	277		$	57		$	26
Net income attributable to noncontrolling interests	1			—			1			1
Net income attributable to redeemable noncontrolling interests	—			1			—			—
Net Income Attributable to Sunoco Logistics Partners L.P.	$	36		$	276		$	56		$	25
Less: General Partner's interest	(60		)	(71		)	(74		)	(83		)
Limited Partners' interest	$	(24	)	$	205		$	(18	)	$	(58	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	(0.10	)	$	0.83		$	(0.07	)	$	(0.21	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	(0.10	)	$	0.83		$	(0.07	)	$	(0.21	)



	1st Quarter			2nd Quarter			3rd Quarter			4th Quarter
	(in millions, except per unit amounts)
2014
Sales and other operating revenue:
Unaffiliated customers	$	4,171		$	4,412		$	4,616		$	3,819
Affiliates	$	306		$	409		$	299		$	56
Gross profit ⁽¹⁾	$	226		$	276		$	279		$	258
Impairment charge and other matters	$	—		$	—		$	—		$	258
Operating income (loss)	$	127		$	180		$	172		$	(112	)
Net Income (Loss)	$	110		$	158		$	157		$	(125	)
Net income attributable to noncontrolling interests	3			2			2			2
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	107		$	156		$	155		$	(127	)
Less: General Partner's interest	(38		)	(44		)	(49		)	(50		)
Limited Partners' interest	$	69		$	112		$	106		$	(177	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.33		$	0.54		$	0.50		$	(0.80	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.33		$	0.53		$	0.50		$	(0.80	)


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

Supplemental Condensed Consolidating Financial Information

12 Months Ended

Dec. 31, 2015

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

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.

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2015

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	9,971		$	—		$	9,971
Affiliates	—		—			515			—			515
Total Revenues	—		—			10,486			—			10,486
Costs and Expenses
Cost of products sold	—		—			9,145			—			9,145
Operating expenses	—		—			164			—			164
Selling, general and administrative expenses	—		1			102			—			103
Depreciation and amortization expense	—		—			382			—			382
Impairment charge and other matters	—		—			162			—			162
Total Costs and Expenses	—		1			9,955			—			9,956
Operating Income (Loss)	—		(1		)	531			—			530
Other interest cost and debt expense, net	—		(209		)	(1		)	—			(210		)
Capitalized interest	—		76			—			—			76
Other income	—		—			22			—			22
Equity in earnings of subsidiaries	393		526			—			(919		)	—
Income (Loss) Before Provision for Income Taxes	393		392			552			(919		)	418
Provision for income taxes	—		—			(21		)	—			(21		)
Net Income (Loss)	393		392			531			(919		)	397
Net income attributable to noncontrolling interests	—		—			(3		)	—			(3		)
Net income attributable to redeemable noncontrolling interests	—		—			(1		)	—			(1		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	393	$	392		$	527		$	(919	)	$	393

Net Income (Loss)	$	393	$	392		$	531		$	(919	)	$	397
Adjustment to affiliate's pension funded status	—		—			(1		)	—			(1		)
Other Comprehensive Income (Loss)	—		—			(1		)	—			(1		)
Comprehensive Income (Loss)	393		392			530			(919		)	396
Less: Comprehensive income attributable to noncontrolling interests	—		—			(3		)	—			(3		)
Less: Comprehensive income attributable to redeemable noncontrolling interests	—		—			(1		)	—			(1		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	393	$	392		$	526		$	(919	)	$	392

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2014

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	17,018		$	—		$	17,018
Affiliates	—		—			1,070			—			1,070
Total Revenues	—		—			18,088			—			18,088
Costs and Expenses
Cost of products sold	—		—			16,877			—			16,877
Operating expenses	—		—			172			—			172
Selling, general and administrative expenses	—		—			118			—			118
Depreciation and amortization expense	—		—			296			—			296
Impairment charge and other matters	—		—			258			—			258
Total Costs and Expenses	—		—			17,721			—			17,721
Operating Income	—		—			367			—			367
Net interest income (cost) to affiliates	—		5			(4		)	—			1
Other interest cost and debt expense, net	—		(146		)	—			—			(146		)
Capitalized interest	—		78			—			—			78
Other income	—		—			25			—			25
Equity in earnings of subsidiaries	291		354			—			(645		)	—
Income (Loss) Before Provision for Income Taxes	291		291			388			(645		)	325
Provision for income taxes	—		—			(25		)	—			(25		)
Net Income (Loss)	291		291			363			(645		)	300
Net Income attributable to noncontrolling interests	—		—			(9		)	—			(9		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	291	$	291		$	354		$	(645	)	$	291

Net Income (Loss)	$	291	$	291		$	363		$	(645	)	$	300
Adjustment to affiliate's pension funded status	—		—			1			—			1
Other Comprehensive Income (Loss)	—		—			1			—			1
Comprehensive Income (Loss)	291		291			364			(645		)	301
Less: Comprehensive income attributable to noncontrolling interests	—		—			(9		)	—			(9		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	291	$	291		$	355		$	(645	)	$	292

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2013

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	15,073		$	—		$	15,073
Affiliates	—		—			1,566			—			1,566
Total Revenues	—		—			16,639			—			16,639
Costs and Expenses
Cost of products sold	—		—			15,600			—			15,600
Operating expenses	—		—			122			—			122
Selling, general and administrative expenses	—		—			92			—			92
Depreciation and amortization expense	—		—			265			—			265
Total Costs and Expenses	—		—			16,079			—			16,079
Operating Income	—		—			560			—			560
Net interest income (cost) to affiliates	—		3			(4		)	—			(1		)
Other interest cost and debt expense, net	—		(96		)	(1		)	—			(97		)
Capitalized interest	—		21			—			—			21
Other income	—		—			21			—			21
Equity in earnings of subsidiaries	463		535			—			(998		)	—
Income (Loss) Before Provision for Income Taxes	463		463			576			(998		)	504
Provision for income taxes	—		—			(30		)	—			(30		)
Net Income (Loss)	463		463			546			(998		)	474
Net Income attributable to noncontrolling interests	—		—			(11		)	—			(11		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	463	$	463		$	535		$	(998	)	$	463

Net Income (Loss)	$	463	$	463		$	546		$	(998	)	$	474
Other Comprehensive Income (Loss)	—		—			—			—			—
Comprehensive Income (Loss)	463		463			546			(998		)	474
Less: Comprehensive income attributable to noncontrolling interests	—		—			(11		)	—			(11		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	463	$	463		$	535		$	(998	)	$	463

Consolidating Balance Sheet

December 31, 2015

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	37		$	—	$	—		$	37
Accounts receivable, affiliated companies	—			3			17		—			20
Accounts receivable, net	—			—			1,165		—			1,165
Inventories	—			—			607		—			607
Other current assets	—			—			19		—			19
Total Current Assets	—			40			1,808		—			1,848
Properties, plants and equipment, net	—			—			10,692		—			10,692
Investment in affiliates	6,488			9,692			802		(16,180		)	802
Goodwill	—			—			1,358		—			1,358
Intangible assets, net	—			—			718		—			718
Other assets	—			6			65		—			71
Total Assets	$	6,488		$	9,738		$	15,443	$	(16,180	)	$	15,489
Liabilities and Equity
Accounts payable	$	—		$	1		$	1,250	$	—		$	1,251
Accounts payable, affiliated companies	—			—			39		—			39
Accrued liabilities	1			66			262		—			329
Accrued taxes payable	—			—			44		—			44
Intercompany	(1,320		)	(2,408		)	3,728		—			—
Total Current Liabilities	(1,319		)	(2,341		)	5,323		—			1,663
Long-term debt	—			5,591			—		—			5,591
Other deferred credits and liabilities	—			—			125		—			125
Deferred income taxes	—			—			254		—			254
Total Liabilities	(1,319		)	3,250			5,702		—			7,633
Redeemable noncontrolling interests	—			—			15		—			15
Redeemable Limited Partners' interests	286			—			—		—			286
Equity
Sunoco Logistics Partners L.P. equity	7,521			6,488			9,692		(16,180		)	7,521
Noncontrolling interests	—			—			34		—			34
Total Equity	7,521			6,488			9,726		(16,180		)	7,555
Total Liabilities and Equity	$	6,488		$	9,738		$	15,443	$	(16,180	)	$	15,489

Consolidating Balance Sheet

December 31, 2014

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	101		$	—	$	—		$	101
Accounts receivable, affiliated companies	—			3			6		—			9
Accounts receivable, net	—			—			1,766		—			1,766
Inventories	—			—			470		—			470
Other current assets	—			—			3		—			3
Total Current Assets	—			104			2,245		—			2,349
Properties, plants and equipment, net	—			—			8,849		—			8,849
Investment in affiliates	6,189			9,168			226		(15,357		)	226
Goodwill	—			—			1,358		—			1,358
Intangible assets, net	—			—			770		—			770
Other assets	—			2			64		—			66
Total Assets	$	6,189		$	9,274		$	13,512	$	(15,357	)	$	13,618
Liabilities and Equity
Accounts payable	$	—		$	—		$	1,934	$	—		$	1,934
Accounts payable, affiliated companies	—			—			21		—			21
Accrued liabilities	—			58			246		—			304
Accrued taxes payable	—			—			52		—			52
Intercompany	(489		)	(1,172		)	1,661		—			—
Total Current Liabilities	(489		)	(1,114		)	3,914		—			2,311
Long-term debt	—			4,199			35		—			4,234
Other deferred credits and liabilities	—			—			71		—			71
Deferred income taxes	—			—			249		—			249
Total Liabilities	(489		)	3,085			4,269		—			6,865
Redeemable noncontrolling interests	—			—			15		—			15
Equity
Sunoco Logistics Partners L.P. equity	6,678			6,189			9,168		(15,357		)	6,678
Noncontrolling interests	—			—			60		—			60
Total Equity	6,678			6,189			9,228		(15,357		)	6,738
Total Liabilities and Equity	$	6,189		$	9,274		$	13,512	$	(15,357	)	$	13,618

Consolidating Statement of Cash Flows

Year Ended December 31, 2015

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	393		$	388		$	736		$	(919	)	$	598
Cash Flows from Investing Activities:
Capital expenditures	—			—			(2,706		)	—			(2,706		)
Acquisitions	—						(131		)	—			(131		)
Change in long-term note receivable	—			—			(17		)	—			(17		)
Intercompany	(1,223		)	(1,814		)	2,118			919			—
Net cash provided by (used in) investing activities	(1,223		)	(1,814		)	(736		)	919			(2,854		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(686		)	—			—			—			(686		)
Distributions paid to noncontrolling interests	(3		)	—			—			—			(3		)
Net proceeds from issuance of limited partner units	1,519			—			—			—			1,519
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(11		)	—			(11		)
Repayments under credit facilities	—			(3,662		)	—			—			(3,662		)
Borrowings under credit facilities	—			4,039			—			—			4,039
Net proceeds from issuance of long-term debt	—			991			—			—			991
Contributions attributable to acquisition from affiliate	—			—			11			—			11
Other	—			(6		)	—			—			(6		)
Net cash provided by financing activities	830			1,362			—			—			2,192
Net change in cash and cash equivalents	—			(64		)	—			—			(64		)
Cash and cash equivalents at beginning of period	—			101			—			—			101
Cash and cash equivalents at end of period	$	—		$	37		$	—		$	—		$	37

Consolidating Statement of Cash Flows

Year Ended December 31, 2014

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	290		$	271		$	649		$	(644	)	$	566
Cash Flows from Investing Activities:
Capital expenditures	—			—			(2,416		)	—			(2,416		)
Acquisitions	—			—			(433		)	—			(433		)
Change in long-term not receivable, affiliated companies	—			—			(17		)	—			(17		)
Intercompany	(876		)	(2,012		)	2,244			644			—
Net cash provided by (used in) investing activities	(876		)	(2,012		)	(622		)	644			(2,866		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(468		)	—			—			—			(468		)
Distributions paid to noncontrolling interests	(4		)	—			—			—			(4		)
Contributions from general partner	2			—			—			—			2
Net proceeds from issuance of limited partner units	839												839
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(9		)	—			(9		)
Repayments under credit facilities	—			(2,845		)	—			—			(2,845		)
Borrowings under credit facilities	—			2,795			—			—			2,795
Net proceeds from issuance of long-term debt	—			1,976			—			—			1,976
Repayment of senior notes	—			(175		)	—			—			(175		)
Advances to affiliated companies, net	217			79			(57		)	—			239
Contributions attributable to acquisition from affiliate	—			—			12			—			12
Net cash provided by (used in) financing activities	586			1,830			(54		)	—			2,362
Net change in cash and cash equivalents	—			89			(27		)	—			62
Cash and cash equivalents at beginning of period	—			12			27			—			39
Cash and cash equivalents at end of period	$	—		$	101		$	—		$	—		$	101

Consolidating Statement of Cash Flows

Year Ended December 31, 2013

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	463		$	446		$	838		$	(998	)	$	749
Cash Flows from Investing Activities:
Capital expenditures	—			—			(897		)	—			(897		)
Acquisitions	—			—			(60		)	—			(60		)
Intercompany	95			(1,177		)	84			998			—
Net cash provided by (used in) investing activities	95			(1,177		)	(873		)	998			(957		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(353		)	—			—			—			(353		)
Distributions paid to noncontrolling interests	(13		)	—			—			—			(13		)
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(3		)	—			(3		)
Repayments under credit facilities	—			(119		)	—			—			(119		)
Borrowings under credit facilities	—			200			15			—			215
Net proceeds from issuance of long-term debt	—			691			—			—			691
Advances to affiliated companies, net	(192		)	(31		)	40			—			(183		)
Contributions attributable to acquisition from affiliate	—			—			9			—			9
Net cash provided by (used in) financing activities	(558		)	741			61			—			244
Net change in cash and cash equivalents	—			10			26			—			36
Cash and cash equivalents at beginning of period	—			2			1			—			3
Cash and cash equivalents at end of period	$	—		$	12		$	27		$	—		$	39

Summary of Significant Accounting Policies (Policies)	12 Months Ended
Summary of Significant Accounting Policies (Policies)	Dec. 31, 2015
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The consolidated financial statements reflect the results of the Partnership and its wholly-owned subsidiaries, including Sunoco Logistics Partners Operations L.P. (the "Operating Partnership"), 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. At December 31, 2015, the Partnership held a controlling financial interest in Inland Corporation ("Inland"), Mid-Valley Pipeline Company ("Mid-Valley"), and Price River Terminal, LLC ("PRT"), as well as a wholly-owned interest in West Texas Gulf Pipe Line Company ("West Texas Gulf"), and as such, these entities are reflected as consolidated subsidiaries of the Partnership. The Partnership is not the primary beneficiary of any variable-interest entities ("VIEs"). All significant intercompany accounts and transactions are eliminated in consolidation and noncontrolling interests in net income and equity are shown separately in the consolidated statements of comprehensive income and balance sheets. Equity ownership interests in corporate joint ventures in which the Partnership does not have a controlling financial interest, but over which the Partnership can exercise significant influence, are accounted for under the equity method of accounting.
Use of Estimates	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 amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.
Reclassifications	Reclassification Certain amounts in the prior years’ consolidated financial statements have been reclassified to conform to the current year presentation. The changes did not impact reported net income for any periods presented.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In the fourth quarter 2015, the Partnership adjusted its presentation of costs associated with issuances of debt in response to the early adoption of Accounting Standards Update ("ASU") 2015-03. This guidance requires costs incurred to issue certain debt instruments to be reflected as a reduction of the reported long-term debt liability within the consolidated balance sheet, as opposed to being reported as an asset. This change was retrospectively applied to all prior reporting periods presented, but did not impact the Partnership's overall financial position or results of operations. The Partnership also adjusted its balance sheet presentation of deferred tax assets and liabilities in response to the early adoption of ASU 2015-17. This guidance requires all deferred tax assets and liabilities to be presented as noncurrent within the consolidated balance sheet, and is retrospectively applied to all prior reporting periods presented. This change did not impact the Partnership's financial position or results of operations. In May 2014, the Financial Accounting Standards Board ("FASB") codified guidance in ASU 2014-09 related to the recognition of revenue from contracts with customers. The new guidance outlines the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration which the entity expects to be entitled in exchange for those goods or services. The guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods, with early adoption permitted. The Partnership is currently assessing the impact, if any, that adoption of new guidance will have on its consolidated financial position and results of operations.
Revenue Recognition	Revenue Recognition Pipeline revenues are recognized upon delivery of the barrels to the location designated by the shipper. Acquisition and marketing revenues for crude oil, NGLs and refined products are recognized when title to and risk of loss of the product is transferred to the customer. Terminalling and storage revenues are recognized at the time the services are provided. Revenues are not recognized for exchange transactions, which are entered into primarily to acquire a commodity 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 to cost of products sold in the consolidated statements of comprehensive income. Affiliated revenues are generated from sales of crude oil, NGLs and refined products, as well as pipeline transportation, terminalling and storage services to ETP and its affiliates. Sales of crude oil, NGLs and refined products to affiliated entities are priced using market-based rates. Affiliated entities pay fees for transportation or terminalling services based on the terms and conditions of established agreements or published tariffs.
Cash Equivalents	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, 2015 and 2014, cash equivalents consisted of time deposits and money market investments.
Accounts Receivable, Net	Accounts Receivable, Net Accounts receivable represent valid claims against non-affiliated customers (see Note 4 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 customers' credit ratings. Outstanding customer receivable balances are regularly reviewed for possible non-payment indicators and reserves are recorded for doubtful accounts based upon management's expectations regarding collectability. Actual receivable balances are charged against the reserve when all collection efforts have been exhausted.
Inventories	Inventories Inventories are valued at the lower of cost or market. Crude oil, NGLs 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. For the periods ended December 31, 2014 and 2015, a lower of cost or market ("LCM") adjustment was applied to the Partnership's crude oil, NGLs and refined products inventories due to the decline in market prices. Write downs are calculated based upon current replacement costs. See Notes 6 and 18 for additional information on changes to the Partnership's inventory pools in connection with the realignment of its reporting segments and related to the LCM reserves and their impact to the Partnership's net income.
Properties, Plants and Equipment	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 determined 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 estimated useful lives of the related assets.
Capitalized Interest	Capitalized Interest The Partnership capitalizes interest incurred on funds borrowed for contributions to joint venture interests and to certain capital projects during periods in which construction activities are in progress to bring those projects to their intended use.
Investment in Affiliates	Investment in Affiliates Investment in affiliates, which consist of corporate joint ventures in which the Partnership does not have a controlling financial interest, but over which the Partnership can exercise significant influence, are accounted for under the equity method of accounting. Under this method, an investment is carried at cost, adjusted for the equity in income (loss), reduced for dividends received and adjusted for changes in accumulated other comprehensive income (loss). Income recognized from the Partnership's corporate joint venture interests is presented within other income in the consolidated statements of comprehensive 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 also presented within other income in the consolidated statements of comprehensive income.
Acquisitions	Acquisitions The Partnership records third-party business combinations 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 results of current operations. The results of operations of acquired businesses are included in the Partnership's results from the dates of acquisition. Assets acquired and liabilities assumed in connection with acquisitions from entities under common control are recorded by the Partnership at the common control entity's net carrying value. The Partnership records any difference between the consideration paid and the carrying value of the net assets and liabilities as a distribution from, or contribution to, redeemable limited partner interests or equity, as applicable. 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. The Partnership's fair value measurements are classified within the fair value hierarchy established by GAAP based on the lowest level (least observable) input that is significant to the measurement in its entirety. See Note 3 for additional information concerning the Partnership's recent acquisitions.
Impairment of Long-Lived Assets	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.
Goodwill	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 in the fourth quarter, or more often if events or changes in circumstances indicate that the carrying value of goodwill may exceed its estimated fair value. The Partnership's general partner was acquired and became a consolidated subsidiary of ETP in the fourth quarter 2012. In connection with the acquisition, the Partnership elected to apply "push-down accounting" which required the Partnership's assets and liabilities to be adjusted to fair value on the closing date of the acquisition, which included an increase to the Partnership's goodwill balance of approximately $1.3 billion. Management's process for evaluating goodwill for impairment involves estimating the fair value of the Partnership's reporting units that include goodwill. During the fourth quarter 2015, the Partnership realigned its reporting segments and, in accordance with accounting guidance, was required to test its goodwill balance for impairment both before and after the change in its reportable segments. As a result of the recent volatility within the energy markets, the Partnership utilized the assistance of a third party valuation firm to develop models to estimate the fair value of each of its reporting units that contain goodwill. Inherent in estimating fair value for each reporting unit are certain judgments and estimates relating the market multiples for comparable businesses, management's interpretation of current economic indicators, and market conditions and assumptions about the Partnership's strategic plans with regards to its operations. To the extent additional information arises, market conditions change or the Partnership's strategies change, it is possible the conclusion regarding whether the goodwill is impaired could change and result in future goodwill impairment charges. During 2015, fair value of the reporting units was estimated using a combination of the discounted cash flow and market multiple methodologies. Under the discounted cash flow methodology, fair value was estimated using the present value of Management's projected cash flows for each reporting unit which was calculated using the expected return a market participant would require for each reporting unit. Under the market multiple methodology, a selection of peer group companies, which are similar from an operational or industry perspective, were considered in estimating market multiples. These multiples were applied to Management's projected Adjusted EBITDA in order to estimate fair value. For the 2015 impairment test, the fair value of the Partnership's legacy Crude Oil Acquisition and Marketing segment was determined to be approximately 3 percent less than its carrying value. In accordance with accounting guidance, if the fair value of the reporting unit is estimated to be less than its carrying value, a second test is performed to estimate the fair value of the reporting unit's assets and liabilities, which includes determining an implied goodwill value. The Partnership performed the second test and determined that the implied fair value of the Crude Oil Acquisition and Marketing segment's goodwill exceeded its current carrying value. As a result, the Partnership determined that its goodwill balance was not impaired for the period ended December 31, 2015. Prior to 2015, the Partnership utilized a market multiple methodology to estimate the fair value of its reporting units. Under this approach, ratios of business enterprise value to EBITDA of comparable companies was used to estimate the fair value. Management established the estimated fair value by comparing the reporting unit to other companies that are similar, from an operational or industry perspective, and by considering risk characteristics in order to determine the risk profile relative to the comparable companies as a group. For the periods ended December 31, 2013 and 2014, the Partnership determined that goodwill was not impaired. See Note 9 for additional information on the Partnership's goodwill balance.
Intangible Assets	Intangible Assets The Partnership has acquired intangible assets, such as customer relationships 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 comprehensive income.
Environmental Remediation	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	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 amounts reflected in the Partnership's consolidated financial statements are related to the operations of Inland, Mid-Valley and West Texas Gulf, all of which are 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.
Long-Term Incentive Plan	Long-Term Incentive Plan The Partnership accounts for the compensation cost associated with all unit-based payment awards at fair value and reports the related expense within operating expenses and selling, general and administrative expenses in the consolidated statements of comprehensive income. Unit-based compensation cost for all outstanding awards of restricted units is based on the grant date market price of the underlying unit. The Partnership recognizes unit-based compensation expense on a straight-line basis over the requisite service period. In accordance with the terms of certain awards, the recognition of compensation expense is accelerated for participants who become retirement-eligible during the applicable vesting period.
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations ("AROs") represent the fair value of expected liabilities related to the future retirement of long-lived assets and are recorded at the time in which a legal obligation is incurred. A corresponding asset is recorded concurrently and is depreciated over the anticipated active life of the related long-lived asset. The value of the ARO is determined based on estimates and assumptions regarding ongoing maintenance and repair, asset repurposing costs, disposal costs and associated contractual obligations related to the Partnership's pipelines, terminal facilities, storage tanks, truck and leased assets. The Partnership bases these estimates on historical and budgeted costs, future inflation rates and credit-adjusted risk-free interest rates. These fair value assessments are considered to be level 3 measurements, as they are based on both observable and unobservable inputs. The Partnership's consolidated balance sheets include AROs as a component of other deferred credits and liabilities of $88 and $41 million at December 31, 2015 and 2014, respectively. The increase in 2015 is primarily related to additional obligations associated with expansion capital and growth projects recently placed into service. 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	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 FASB. The Partnership generally applies a "market approach" to determine fair value. This method uses pricing and other information related to 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.
Lease Accounting	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 an 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 of 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	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. ("net income attributable to SXL") per limited partner unit by dividing net income attributable to SXL, after deducting the amounts allocated to the general partner’s interest and incentive distribution rights ("IDRs"), by the weighted average number of limited partner units and Class B 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 B unitholders based on the contractual terms of the partnership agreement. See Note 12 for additional information on the terms of the Class B units.

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2015

Accounting Policies [Abstract]

Components of Income Tax Expense

The following table presents the components of income tax expense for the periods presented:



	Year Ended December 31,
	2015		2014			2013
	(in millions)
Federal
Current	$	15	$	24		$	21
Deferred	6		(5		)	6
State
Current	—		6			3
Deferred	—		—			—
Total income tax expense	$	21	$	25		$	30

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

12 Months Ended

Dec. 31, 2015

Earnings Per Share [Abstract]

Schedule of Weighted Average Number of Basic and Diluted Shares



	Year Ended December 31,
	2015	2014	2013
	(in millions)
Weighted average number of units outstanding—basic ⁽¹⁾	250.9	212.9	207.6
Add effect of dilutive incentive awards ⁽¹⁾	0.8	1.2	1.0
Weighted average number of units—diluted ⁽¹⁾	251.7	214.1	208.6

Inventories (Tables)

12 Months Ended

Dec. 31, 2015

Inventory Disclosure [Abstract]

Schedule of Inventories

The components of inventories are as follows:



	December 31,
	2015		2014
	(in millions)
Crude oil	$	424	$	364
NGLs	83		90
Refined products	83		—
Refined products additives	3		4
Materials, supplies and other	14		12
Total Inventories	$	607	$	470

Properties, Plants and Equipment (Tables)

12 Months Ended

Dec. 31, 2015

Property, Plant and Equipment [Abstract]

Schedule of Properties, Plants and Equipment

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



		December 31,
	Estimated Useful Lives	2015			2014
	(in years)	(in millions)
Land and land improvements (including rights-of-way) ⁽¹⁾	—	$	1,286		$	1,212
Pipelines and related assets	16 - 39	5,943			4,253
Terminals and storage facilities	20 - 41	1,985			1,457
Buildings and improvements	25 - 32	509			245
Other	3 - 20	177			133
Construction-in-progress ⁽²⁾		1,627			2,058
Total properties, plants and equipment		11,527			9,358
Less: Accumulated depreciation and amortization		(835		)	(509		)
Total properties, plants and equipment, net		$	10,692		$	8,849


⁽¹⁾	As of December 31, 2015 and 2014, the Partnership had rights-of-way with a book value of $1.1 and $1.0 billion, respectively.


⁽²⁾	As of December 31, 2015 and 2014, accrued capital expenditures were $286 and $283 million, respectively.

Investment in Affiliates (Tables)

12 Months Ended

Dec. 31, 2015

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Partnership's Ownership Percentages Not Holding Controlling Financial Interest

The Partnership's ownership percentages in equity ownership interests as of December 31, 2015 and 2014 were as follows:



	December 31,
	2015	2014
Explorer Pipeline Company	13.3%	13.3%
Yellowstone Pipe Line Company	14.0%	14.0%
West Shore Pipe Line Company	17.1%	17.1%
Wolverine Pipe Line Company	31.5%	31.5%
Bayview Refining Company, LLC	49.0%	49.0%
SunVit Pipeline LLC	50.0%	50.0%
Bayou Bridge Pipeline LLC	30.0%	—%
Bakken Holdings Company LLC ("Bakken HoldCo") ⁽¹⁾	40.0%	—%

Goodwill and Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Components of Intangible Assets



	Weighted Average Amortization Period	December 31,
	Weighted Average Amortization Period	2015			2014
	(in years)	(in millions)
Gross
Customer relationships	18	$	836		$	836
Technology	10	47			47
Total gross		883			883
Accumulated amortization
Customer relationships		(149		)	(102		)
Technology		(16		)	(11		)
Total accumulated amortization		(165		)	(113		)
Total Net		$	718		$	770

Debt (Tables)

12 Months Ended

Dec. 31, 2015

Debt Disclosure [Abstract]

Partnership's Debt Balances

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



	December 31,
	2015			2014
	(in millions)
Credit Facilities
$2.50 billion Credit Facility, due March 2020	$	562		$	150
$35 million Credit Facility, matured and repaid April 2015	—			35
Senior Notes
Senior Notes - 6.125%, due May 2016 ⁽¹⁾	175			175
Senior Notes - 5.50%, due February 2020	250			250
Senior Notes - 4.40%, due April 2021	600			—
Senior Notes - 4.65%, due February 2022	300			300
Senior Notes - 3.45%, due January 2023	350			350
Senior Notes - 4.25%, due April 2024	500			500
Senior Notes - 5.95%, due December 2025	400			—
Senior Notes - 6.85%, due February 2040	250			250
Senior Notes - 6.10%, due February 2042	300			300
Senior Notes - 4.95%, due January 2043	350			350
Senior Notes - 5.30%, due April 2044	700			700
Senior Notes - 5.35%, due May 2045	800			800
Unamortized fair value adjustments ⁽²⁾	93			106
Total debt	5,630			4,266
Less:
Unamortized bond discount and debt issuance costs ⁽³⁾	(39		)	(32		)
Long-term debt	$	5,591		$	4,234


⁽¹⁾	The 6.125 percent Senior Notes were classified as long-term debt at December 31, 2015 as the Partnership has the ability and intent to refinance such borrowings on a long-term basis.


⁽²⁾	Represents fair value adjustments on senior notes resulting from the application of push-down accounting in connection with the acquisition of the Partnership's general partner by ETP on October 5, 2012.


⁽³⁾	In the fourth quarter 2015, the Partnership adopted accounting guidance which requires certain debt issuance costs to be reflected as a reduction in the total long-term debt liability for all periods presented. The net long-term debt balance now includes $32 and $26 million of debt issuance costs at December 31, 2015 and 2014, respectively. Refer to Note 2 for additional information.

Long-Term Debt Maturities Aggregate Amount

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



Year Ended December 31,	(in millions)
2016	$	175
2017	—
2018	—
2019	—
2020	812
Thereafter	4,550
Total	$	5,537

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

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.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=34725769&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingent Liabilities (Tables)

12 Months Ended

Dec. 31, 2015

Future Minimum Annual Rental Aggregate Amount

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, 2015 is as follows:



Year Ended December 31,	(in millions)
2016	$	8
2017	8
2018	4
2019	3
2020	3
Thereafter	—
Total	$	26

Cash Distributions (Tables)

12 Months Ended

Dec. 31, 2015

Equity [Abstract]

Schedule Of Distributions Made To General And Limited Partner



	Total Quarterly Distribution Target Amount	Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount	General Partner			Unitholders
Minimum Quarterly Distribution	$0.0750	2	%		98%
First Target Distribution	up to $0.0833	2	%		98%
Second Target Distribution	above $0.0833 up to $0.0958	15	%	⁽¹⁾	85%
Third Target Distribution	above $0.0958 up to $0.2638	37	%	⁽¹⁾	63%
Thereafter	above $0.2638	50	%	⁽¹⁾	50%

Schedule Of Cash Distributions Made To Partners By Distribution



Cash Distribution Payment Date	Cash Distribution per Limited Partner Unit ⁽¹⁾		Annualized Cash Distribution per Limited Partner Unit ⁽¹⁾		Total Cash Distribution to the Limited Partners		Total Cash Distribution to the General Partner
					(in millions)		(in millions)
November 13, 2015	$	0.4580	$	1.8320	$	119	$	76
August 14, 2015	$	0.4380	$	1.7520	$	111	$	69
May 15, 2015	$	0.4190	$	1.6760	$	103	$	62
February 13, 2015	$	0.4000	$	1.6000	$	92	$	54
November 14, 2014	$	0.3825	$	1.5300	$	84	$	49
August 14, 2014	$	0.3650	$	1.4600	$	77	$	43
May 15, 2014	$	0.3475	$	1.3900	$	72	$	39
February 14, 2014	$	0.3312	$	1.3248	$	69	$	35
November 14, 2013	$	0.3150	$	1.2600	$	65	$	32
August 14, 2013	$	0.3000	$	1.2000	$	62	$	29
May 15, 2013	$	0.2863	$	1.1452	$	59	$	26
February 14, 2013	$	0.2725	$	1.0900	$	57	$	23

Management Incentive Plan (Tables)

12 Months Ended

Dec. 31, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Summarized Information Restricted Unit Award Activity



	Number of Units ⁽¹⁾		Weighted Average Grant Date Fair Value ⁽¹⁾
Granted, non-vested and outstanding, December 31, 2012	855,220		$	19.48
Granted	858,246		$	30.00
Performance factor adjustment ⁽²⁾	202,620		$	15.76
Vested	(563,668	)	$	18.33
Cancelled/forfeited	(73,256	)	$	24.19
Granted, non-vested and outstanding, December 31, 2013	1,279,162		$	26.19
Granted	719,009		$	41.59
Performance factor adjustment ⁽²⁾	229,828		$	17.52
Vested	(693,326	)	$	20.26
Cancelled/forfeited	(72,872	)	$	30.10
Granted, non-vested and outstanding, December 31, 2014	1,461,801		$	35.01
Granted	1,412,257		$	29.54
Vested	(245,563	)	$	22.08
Cancelled/forfeited	(90,776	)	$	36.83
Granted, non-vested and outstanding, December 31, 2015	2,537,719		$	33.16

Derivatives and Risk Management (Tables)

12 Months Ended

Dec. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Partnership's Derivative Assets and Liabilities

As of December 31, 2015 and 2014, the fair values of the Partnership's derivative assets and liabilities were:



	December 31,
	2015			2014
	(in millions)
Derivative assets	$	30		$	29
Derivative liabilities	(18		)	(14		)
	$	12		$	15

Schedule of Derivative Instruments, (Gain) Loss



	Location of Gains (Losses) Recognized in Earnings	Gains (Losses) Recognized in Earnings
		(in millions)
Year Ended December 31, 2015
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	47
Commodity contracts	Cost of products sold	(26		)
Commodity contracts	Operating expenses	(1		)
		$	20
Year Ended December 31, 2014
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	81
Commodity contracts	Cost of products sold	(20		)
		$	61
Year Ended December 31, 2013
Derivatives designated as cash flow hedging instruments:
Commodity contracts	Sales and other operating revenue	$	(1	)
Commodity contracts	Cost of products sold	—
		$	(1	)
Derivatives not designated as hedging instruments:
Commodity contracts	Sales and other operating revenue	$	(7	)
Commodity contracts	Cost of products sold	1
		$	(6	)

Business Segment Information (Tables)

12 Months Ended

Dec. 31, 2015

Segment Reporting [Abstract]

Segment Reporting Information



	Year Ended December 31,
	2015			2014			2013
	(in millions)
Sales and other operating revenue ⁽¹⁾
Crude Oil	$	8,956		$	16,899		$	15,953
Natural Gas Liquids	1,165			959			447
Refined Products	365			230			239
Total sales and other operating revenue	$	10,486		$	18,088		$	16,639
Depreciation and amortization
Crude Oil	$	216		$	191		$	176
Natural Gas Liquids	76			30			21
Refined Products	90			75			68
Total depreciation and amortization	$	382		$	296		$	265
Impairment charge and other matters ⁽²⁾
Crude Oil	$	150		$	231		$	—
Natural Gas Liquids	10			27			—
Refined Products	2			—			—
Total impairment charge and other matters	$	162		$	258		$	—
Capital expenditures ⁽³⁾
Crude Oil	$	1,377		$	801		$	369
Natural Gas Liquids	1,111			1,210			476
Refined Products	197			534			155
Corporate	24			14			18
Total capital expenditures	$	2,709		$	2,559		$	1,018
Adjusted EBITDA
Crude Oil	$	656		$	669		$	701
Natural Gas Liquids	333			203			73
Refined Products	164			99			97
Total Adjusted EBITDA	1,153			971			871
Interest expense, net	(134		)	(67		)	(77		)
Depreciation and amortization expense	(382		)	(296		)	(265		)
Impairment charge and other matters	(162		)	(258		)	—
Provision for income taxes	(21		)	(25		)	(30		)
Non-cash compensation expense	(17		)	(16		)	(14		)
Unrealized gain (loss) on commodity risk management activities	(4		)	17			1
Amortization of excess equity method investment	(2		)	(2		)	(2		)
Proportionate share of unconsolidated affiliates' interest, depreciation and provision for income taxes	(34		)	(24		)	(20		)
Non-cash accrued liability adjustment	—			—			10
Net Income ⁽⁴⁾	397			300			474
Net income attributable to noncontrolling interests	3			9			11
Net income attributable to redeemable noncontrolling interests	1			—			—
Net Income Attributable to Sunoco Logistics Partners L.P.	$	393		$	291		$	463


⁽¹⁾	Sales and other operating revenue for the periods presented includes the following amounts from ETP and its affiliates:



	Year Ended December 31,
	2015		2014		2013
	(in millions)
Crude Oil	$	193	$	866	$	1,418
Natural Gas Liquids	204		134		63
Refined Products	118		70		85
Total sales and other operating revenue	$	515	$	1,070	$	1,566

Total sales and other operating revenue exclude $404, $309 and $280 million attributable to intrasegment activity for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽²⁾	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.


⁽³⁾	Total capital expenditures exclude acquisitions and investments in equity ownership interests of $131, $448 and $60 million for the years ended December 31, 2015, 2014 and 2013, respectively.


⁽⁴⁾	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.

Sales And Other Operating Revenue By Segment



	Year Ended December 31,
	2015		2014		2013
	(in millions)
Crude Oil	$	193	$	866	$	1,418
Natural Gas Liquids	204		134		63
Refined Products	118		70		85
Total sales and other operating revenue	$	515	$	1,070	$	1,566

Schedule Of Segment Reporting Information Balance Sheet Data By Segment Table

The following table provides consolidated balance sheet information concerning the Partnership's business segments as of December 31, 2015, 2014 and 2013, respectively:



	Crude Oil		Natural Gas Liquids		Refined Products		Total
	(in millions)
As of December 31, 2015
Investment in affiliates	$	623	$	—	$	179	$	802
Goodwill	$	912	$	357	$	89	$	1,358
Identifiable assets ⁽¹⁾	$	8,802	$	3,764	$	2,747	$	15,489
As of December 31, 2014
Investment in affiliates	$	53	$	—	$	173	$	226
Goodwill	$	912	$	357	$	89	$	1,358
Identifiable assets ⁽²⁾	$	8,579	$	2,401	$	2,458	$	13,618
As of December 31, 2013
Investment in affiliates	$	3	$	—	$	122	$	125
Goodwill	$	900	$	357	$	89	$	1,346
Identifiable assets ⁽³⁾	$	8,233	$	1,442	$	1,894	$	11,890


⁽¹⁾	Total identifiable assets include the Partnership's unallocated $36 million cash and cash equivalents, $133 million of properties, plants and equipment, net, and $7 million of other assets.


⁽²⁾	Total identifiable assets include the Partnership's unallocated $47 million cash and cash equivalents, $124 million of properties, plants and equipment, net, and $9 million of other assets.


⁽³⁾	Total identifiable assets include the Partnership's unallocated $12 million cash and cash equivalents, $239 million of advances to affiliates, $66 million of properties, plants and equipment, net and $4 million of other assets.

Quarterly Financial Data (Unaudited) - (Tables)

12 Months Ended

Dec. 31, 2015

Quarterly Financial Information Disclosure [Abstract]

Summarized Quarterly Financial Data



	1st Quarter			2nd Quarter			3rd Quarter			4th Quarter
	(in millions, except per unit amounts)
2015
Sales and other operating revenue:
Unaffiliated customers	$	2,453		$	2,996		$	2,317		$	2,205
Affiliates	$	119		$	206		$	90		$	100
Gross profit ⁽¹⁾	$	214		$	326		$	325		$	312
Impairment charge and other matters	$	41		$	(100	)	$	103		$	118
Operating income	$	66		$	307		$	94		$	63
Net Income	$	37		$	277		$	57		$	26
Net income attributable to noncontrolling interests	1			—			1			1
Net income attributable to redeemable noncontrolling interests	—			1			—			—
Net Income Attributable to Sunoco Logistics Partners L.P.	$	36		$	276		$	56		$	25
Less: General Partner's interest	(60		)	(71		)	(74		)	(83		)
Limited Partners' interest	$	(24	)	$	205		$	(18	)	$	(58	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	(0.10	)	$	0.83		$	(0.07	)	$	(0.21	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	(0.10	)	$	0.83		$	(0.07	)	$	(0.21	)



	1st Quarter			2nd Quarter			3rd Quarter			4th Quarter
	(in millions, except per unit amounts)
2014
Sales and other operating revenue:
Unaffiliated customers	$	4,171		$	4,412		$	4,616		$	3,819
Affiliates	$	306		$	409		$	299		$	56
Gross profit ⁽¹⁾	$	226		$	276		$	279		$	258
Impairment charge and other matters	$	—		$	—		$	—		$	258
Operating income (loss)	$	127		$	180		$	172		$	(112	)
Net Income (Loss)	$	110		$	158		$	157		$	(125	)
Net income attributable to noncontrolling interests	3			2			2			2
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	107		$	156		$	155		$	(127	)
Less: General Partner's interest	(38		)	(44		)	(49		)	(50		)
Limited Partners' interest	$	69		$	112		$	106		$	(177	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic	$	0.33		$	0.54		$	0.50		$	(0.80	)
Net Income (Loss) attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted	$	0.33		$	0.53		$	0.50		$	(0.80	)


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

Supplemental Condensed Consolidating Financial Information (Tables)

12 Months Ended

Dec. 31, 2015

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Consolidating Statement of Comprehensive Income (Loss)

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2015

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	9,971		$	—		$	9,971
Affiliates	—		—			515			—			515
Total Revenues	—		—			10,486			—			10,486
Costs and Expenses
Cost of products sold	—		—			9,145			—			9,145
Operating expenses	—		—			164			—			164
Selling, general and administrative expenses	—		1			102			—			103
Depreciation and amortization expense	—		—			382			—			382
Impairment charge and other matters	—		—			162			—			162
Total Costs and Expenses	—		1			9,955			—			9,956
Operating Income (Loss)	—		(1		)	531			—			530
Other interest cost and debt expense, net	—		(209		)	(1		)	—			(210		)
Capitalized interest	—		76			—			—			76
Other income	—		—			22			—			22
Equity in earnings of subsidiaries	393		526			—			(919		)	—
Income (Loss) Before Provision for Income Taxes	393		392			552			(919		)	418
Provision for income taxes	—		—			(21		)	—			(21		)
Net Income (Loss)	393		392			531			(919		)	397
Net income attributable to noncontrolling interests	—		—			(3		)	—			(3		)
Net income attributable to redeemable noncontrolling interests	—		—			(1		)	—			(1		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	393	$	392		$	527		$	(919	)	$	393

Net Income (Loss)	$	393	$	392		$	531		$	(919	)	$	397
Adjustment to affiliate's pension funded status	—		—			(1		)	—			(1		)
Other Comprehensive Income (Loss)	—		—			(1		)	—			(1		)
Comprehensive Income (Loss)	393		392			530			(919		)	396
Less: Comprehensive income attributable to noncontrolling interests	—		—			(3		)	—			(3		)
Less: Comprehensive income attributable to redeemable noncontrolling interests	—		—			(1		)	—			(1		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	393	$	392		$	526		$	(919	)	$	392

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2014

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	17,018		$	—		$	17,018
Affiliates	—		—			1,070			—			1,070
Total Revenues	—		—			18,088			—			18,088
Costs and Expenses
Cost of products sold	—		—			16,877			—			16,877
Operating expenses	—		—			172			—			172
Selling, general and administrative expenses	—		—			118			—			118
Depreciation and amortization expense	—		—			296			—			296
Impairment charge and other matters	—		—			258			—			258
Total Costs and Expenses	—		—			17,721			—			17,721
Operating Income	—		—			367			—			367
Net interest income (cost) to affiliates	—		5			(4		)	—			1
Other interest cost and debt expense, net	—		(146		)	—			—			(146		)
Capitalized interest	—		78			—			—			78
Other income	—		—			25			—			25
Equity in earnings of subsidiaries	291		354			—			(645		)	—
Income (Loss) Before Provision for Income Taxes	291		291			388			(645		)	325
Provision for income taxes	—		—			(25		)	—			(25		)
Net Income (Loss)	291		291			363			(645		)	300
Net Income attributable to noncontrolling interests	—		—			(9		)	—			(9		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	291	$	291		$	354		$	(645	)	$	291

Net Income (Loss)	$	291	$	291		$	363		$	(645	)	$	300
Adjustment to affiliate's pension funded status	—		—			1			—			1
Other Comprehensive Income (Loss)	—		—			1			—			1
Comprehensive Income (Loss)	291		291			364			(645		)	301
Less: Comprehensive income attributable to noncontrolling interests	—		—			(9		)	—			(9		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	291	$	291		$	355		$	(645	)	$	292

Consolidating Statement of Comprehensive Income (Loss)

Year Ended December 31, 2013

(in millions)



	Parent Guarantor		Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Revenues
Sales and other operating revenue:
Unaffiliated customers	$	—	$	—		$	15,073		$	—		$	15,073
Affiliates	—		—			1,566			—			1,566
Total Revenues	—		—			16,639			—			16,639
Costs and Expenses
Cost of products sold	—		—			15,600			—			15,600
Operating expenses	—		—			122			—			122
Selling, general and administrative expenses	—		—			92			—			92
Depreciation and amortization expense	—		—			265			—			265
Total Costs and Expenses	—		—			16,079			—			16,079
Operating Income	—		—			560			—			560
Net interest income (cost) to affiliates	—		3			(4		)	—			(1		)
Other interest cost and debt expense, net	—		(96		)	(1		)	—			(97		)
Capitalized interest	—		21			—			—			21
Other income	—		—			21			—			21
Equity in earnings of subsidiaries	463		535			—			(998		)	—
Income (Loss) Before Provision for Income Taxes	463		463			576			(998		)	504
Provision for income taxes	—		—			(30		)	—			(30		)
Net Income (Loss)	463		463			546			(998		)	474
Net Income attributable to noncontrolling interests	—		—			(11		)	—			(11		)
Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	463	$	463		$	535		$	(998	)	$	463

Net Income (Loss)	$	463	$	463		$	546		$	(998	)	$	474
Other Comprehensive Income (Loss)	—		—			—			—			—
Comprehensive Income (Loss)	463		463			546			(998		)	474
Less: Comprehensive income attributable to noncontrolling interests	—		—			(11		)	—			(11		)
Comprehensive Income (Loss) Attributable to Sunoco Logistics Partners L.P.	$	463	$	463		$	535		$	(998	)	$	463

Condensed Consolidating Balance Sheet

Consolidating Balance Sheet

December 31, 2015

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	37		$	—	$	—		$	37
Accounts receivable, affiliated companies	—			3			17		—			20
Accounts receivable, net	—			—			1,165		—			1,165
Inventories	—			—			607		—			607
Other current assets	—			—			19		—			19
Total Current Assets	—			40			1,808		—			1,848
Properties, plants and equipment, net	—			—			10,692		—			10,692
Investment in affiliates	6,488			9,692			802		(16,180		)	802
Goodwill	—			—			1,358		—			1,358
Intangible assets, net	—			—			718		—			718
Other assets	—			6			65		—			71
Total Assets	$	6,488		$	9,738		$	15,443	$	(16,180	)	$	15,489
Liabilities and Equity
Accounts payable	$	—		$	1		$	1,250	$	—		$	1,251
Accounts payable, affiliated companies	—			—			39		—			39
Accrued liabilities	1			66			262		—			329
Accrued taxes payable	—			—			44		—			44
Intercompany	(1,320		)	(2,408		)	3,728		—			—
Total Current Liabilities	(1,319		)	(2,341		)	5,323		—			1,663
Long-term debt	—			5,591			—		—			5,591
Other deferred credits and liabilities	—			—			125		—			125
Deferred income taxes	—			—			254		—			254
Total Liabilities	(1,319		)	3,250			5,702		—			7,633
Redeemable noncontrolling interests	—			—			15		—			15
Redeemable Limited Partners' interests	286			—			—		—			286
Equity
Sunoco Logistics Partners L.P. equity	7,521			6,488			9,692		(16,180		)	7,521
Noncontrolling interests	—			—			34		—			34
Total Equity	7,521			6,488			9,726		(16,180		)	7,555
Total Liabilities and Equity	$	6,488		$	9,738		$	15,443	$	(16,180	)	$	15,489

Consolidating Balance Sheet

December 31, 2014

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries		Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	101		$	—	$	—		$	101
Accounts receivable, affiliated companies	—			3			6		—			9
Accounts receivable, net	—			—			1,766		—			1,766
Inventories	—			—			470		—			470
Other current assets	—			—			3		—			3
Total Current Assets	—			104			2,245		—			2,349
Properties, plants and equipment, net	—			—			8,849		—			8,849
Investment in affiliates	6,189			9,168			226		(15,357		)	226
Goodwill	—			—			1,358		—			1,358
Intangible assets, net	—			—			770		—			770
Other assets	—			2			64		—			66
Total Assets	$	6,189		$	9,274		$	13,512	$	(15,357	)	$	13,618
Liabilities and Equity
Accounts payable	$	—		$	—		$	1,934	$	—		$	1,934
Accounts payable, affiliated companies	—			—			21		—			21
Accrued liabilities	—			58			246		—			304
Accrued taxes payable	—			—			52		—			52
Intercompany	(489		)	(1,172		)	1,661		—			—
Total Current Liabilities	(489		)	(1,114		)	3,914		—			2,311
Long-term debt	—			4,199			35		—			4,234
Other deferred credits and liabilities	—			—			71		—			71
Deferred income taxes	—			—			249		—			249
Total Liabilities	(489		)	3,085			4,269		—			6,865
Redeemable noncontrolling interests	—			—			15		—			15
Equity
Sunoco Logistics Partners L.P. equity	6,678			6,189			9,168		(15,357		)	6,678
Noncontrolling interests	—			—			60		—			60
Total Equity	6,678			6,189			9,228		(15,357		)	6,738
Total Liabilities and Equity	$	6,189		$	9,274		$	13,512	$	(15,357	)	$	13,618

Condensed Consolidating Statement of Cash Flows

Consolidating Statement of Cash Flows

Year Ended December 31, 2015

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	393		$	388		$	736		$	(919	)	$	598
Cash Flows from Investing Activities:
Capital expenditures	—			—			(2,706		)	—			(2,706		)
Acquisitions	—						(131		)	—			(131		)
Change in long-term note receivable	—			—			(17		)	—			(17		)
Intercompany	(1,223		)	(1,814		)	2,118			919			—
Net cash provided by (used in) investing activities	(1,223		)	(1,814		)	(736		)	919			(2,854		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(686		)	—			—			—			(686		)
Distributions paid to noncontrolling interests	(3		)	—			—			—			(3		)
Net proceeds from issuance of limited partner units	1,519			—			—			—			1,519
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(11		)	—			(11		)
Repayments under credit facilities	—			(3,662		)	—			—			(3,662		)
Borrowings under credit facilities	—			4,039			—			—			4,039
Net proceeds from issuance of long-term debt	—			991			—			—			991
Contributions attributable to acquisition from affiliate	—			—			11			—			11
Other	—			(6		)	—			—			(6		)
Net cash provided by financing activities	830			1,362			—			—			2,192
Net change in cash and cash equivalents	—			(64		)	—			—			(64		)
Cash and cash equivalents at beginning of period	—			101			—			—			101
Cash and cash equivalents at end of period	$	—		$	37		$	—		$	—		$	37

Consolidating Statement of Cash Flows

Year Ended December 31, 2014

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	290		$	271		$	649		$	(644	)	$	566
Cash Flows from Investing Activities:
Capital expenditures	—			—			(2,416		)	—			(2,416		)
Acquisitions	—			—			(433		)	—			(433		)
Change in long-term not receivable, affiliated companies	—			—			(17		)	—			(17		)
Intercompany	(876		)	(2,012		)	2,244			644			—
Net cash provided by (used in) investing activities	(876		)	(2,012		)	(622		)	644			(2,866		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(468		)	—			—			—			(468		)
Distributions paid to noncontrolling interests	(4		)	—			—			—			(4		)
Contributions from general partner	2			—			—			—			2
Net proceeds from issuance of limited partner units	839												839
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(9		)	—			(9		)
Repayments under credit facilities	—			(2,845		)	—			—			(2,845		)
Borrowings under credit facilities	—			2,795			—			—			2,795
Net proceeds from issuance of long-term debt	—			1,976			—			—			1,976
Repayment of senior notes	—			(175		)	—			—			(175		)
Advances to affiliated companies, net	217			79			(57		)	—			239
Contributions attributable to acquisition from affiliate	—			—			12			—			12
Net cash provided by (used in) financing activities	586			1,830			(54		)	—			2,362
Net change in cash and cash equivalents	—			89			(27		)	—			62
Cash and cash equivalents at beginning of period	—			12			27			—			39
Cash and cash equivalents at end of period	$	—		$	101		$	—		$	—		$	101

Consolidating Statement of Cash Flows

Year Ended December 31, 2013

(in millions)



	Parent Guarantor			Subsidiary Issuer			Non-Guarantor Subsidiaries			Consolidating Adjustments			Total
Net Cash Flows from Operating Activities	$	463		$	446		$	838		$	(998	)	$	749
Cash Flows from Investing Activities:
Capital expenditures	—			—			(897		)	—			(897		)
Acquisitions	—			—			(60		)	—			(60		)
Intercompany	95			(1,177		)	84			998			—
Net cash provided by (used in) investing activities	95			(1,177		)	(873		)	998			(957		)
Cash Flows from Financing Activities:
Distributions paid to limited and general partners	(353		)	—			—			—			(353		)
Distributions paid to noncontrolling interests	(13		)	—			—			—			(13		)
Payments of statutory withholding on net issuance of limited partner units under LTIP	—			—			(3		)	—			(3		)
Repayments under credit facilities	—			(119		)	—			—			(119		)
Borrowings under credit facilities	—			200			15			—			215
Net proceeds from issuance of long-term debt	—			691			—			—			691
Advances to affiliated companies, net	(192		)	(31		)	40			—			(183		)
Contributions attributable to acquisition from affiliate	—			—			9			—			9
Net cash provided by (used in) financing activities	(558		)	741			61			—			244
Net change in cash and cash equivalents	—			10			26			—			36
Cash and cash equivalents at beginning of period	—			2			1			—			3
Cash and cash equivalents at end of period	$	—		$	12		$	27		$	—		$	39

Organization and Basis of Presentation - Additional Information (Details)	Dec. 31, 2015 state
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of states in which the partnership operates	35

Summary of Significant Accounting Policies - Components of Income Tax Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accounting Policies [Abstract]
Current, Federal	$ 15	$ 24	$ 21
Deferred, Federal	6	(5)	6
Current, State	0	6	3
Deferred, State	0	0	0
Total income tax expense	$ 21	$ 25	$ 30

Summary of Significant Accounting Policies - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Oct. 05, 2012
Significant Accounting Policies [Line Items]
Asset Retirement Obligation	$ 88	$ 41
Push down accounting fair value goodwill			$ 1,300
Controlling financial interest evidenced by a voting interest greater than certain percent	50.00%
Federal statutory rate	35.00%
Tax benefits recognized	50.00%
Net deferred tax	$ 254	$ 249
Maximum [Member]
Significant Accounting Policies [Line Items]
Investment in affiliates, pipeline and related assets, useful life	40 years

Acquisitions - Additional Information (Details)
bbl in Thousands, $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 31, 2015

USD ($)

Dec. 31, 2014

USD ($)

Jun. 30, 2014

USD ($)

bbl

Jun. 30, 2013

USD ($)

Dec. 31, 2015

USD ($)

Dec. 31, 2014

USD ($)

Dec. 31, 2013

USD ($)

Schedule of Acquisitions, By Acquisition [Line Items]

Acquisition of a noncontrolling interest in consolidated subsidiary

$ 131

$ 325

$ 8,849

^[1]

10,692

8,849

^[1]

1,358

$ 1,346

Payments to acquire net assets

$ 15

$ 60

West Texas Gulf Pipeline [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Owner interest percentage

28.30%

Ownership interest percentage

88.60%

Acquisition of a noncontrolling interest in consolidated subsidiary

$ 131

$ 325

EDF [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Barrels per day, in barrels | bbl

PRT [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Owner interest percentage

55.00%

EDF and PRT [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Payments for acquisition, net of cash acquired

$ 65

Inventory, Gross

Intangible assets

Marcus Hook Facility [Member]

$ 15

Schedule of Acquisitions, By Acquisition [Line Items]

Payments to acquire net assets

$ 66

Contributions attributable to acquisition from affliate (total to be received)

Current and long-term assets

Current and long-term liabilities

$ 16

Noncontrolling Interest [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Acquisition of a noncontrolling interest in consolidated subsidiary

$ 26

$ 66

Noncontrolling Interest [Member] | West Texas Gulf Pipeline [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Acquisition of a noncontrolling interest in consolidated subsidiary

Partners Equity [Member] | West Texas Gulf Pipeline [Member]

Schedule of Acquisitions, By Acquisition [Line Items]

Acquisition of a noncontrolling interest in consolidated subsidiary

$ 364

[1]

December 31, EstimatedUseful Lives 2015 2014 (in years) (in millions)Land and land improvements (including rights-of-way) (1) — $1,286 $1,212Pipelines and related assets 16 - 39 5,943 4,253Terminals and storage facilities 20 - 41 1,985 1,457Buildings and improvements 25 - 32 509 245Other 3 - 20 177 133Construction-in-progress (2) 1,627 2,058Total properties, plants and equipment 11,527 9,358Less: Accumulated depreciation and amortization (835) (509)Total properties, plants and equipment, net $10,692 $8,849

Related Party Transactions - Additional Information (Details) bbl in Thousands, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015 USD ($) shares bbl	Dec. 31, 2014 USD ($) shares	Dec. 31, 2013 USD ($) shares	Jul. 30, 2014 USD ($)
Related Party Transaction [Line Items]
Public debt filling amount	$ 200.0
Allocated employee benefits expense	54.0	$ 45.0	$ 36.0
Increase attributable to acquisition from affiliate	$ 54.0	54.0	4.0
Contributions from general partner (less than $0.5 million for each period for each period presented related to issuance of LTIP units)		$ 0.5	$ 0.5
Non-cash compensation expense (in units) (less than 0.1 million for the year ended December 31, 2013) \| shares	0.4	0.4	0.1
Sunoco Partners LLC [Member] \| Product Terminal Services Agreement [Member]
Related Party Transaction [Line Items]
Related party agreement period, in years	5 years
Philadelphia Energy Solutions [Member] \| Fort Mifflin Terminal Complex Terminal Services Agreement [Member]
Related Party Transaction [Line Items]
Related party agreement period, in years	10 years
Barrels per day, in barrels \| bbl	300
Philadelphia Energy Solutions [Member] \| Lease for use of Inter-refinery Pipelines [Member]
Related Party Transaction [Line Items]
Annual fee escalation percentage	1.67%
Marcus Hook Facility [Member]
Related Party Transaction [Line Items]
Related party agreement period, in years	10 years
Issuance of LTIP Units [Member]
Related Party Transaction [Line Items]
Contributions from general partner (less than $0.5 million for each period for each period presented related to issuance of LTIP units)	$ 0.5
At-the-Market Offering [Member]
Related Party Transaction [Line Items]
Contributions from general partner (less than $0.5 million for each period for each period presented related to issuance of LTIP units)				$ 2.0

Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit - Schedule of Weighted Average Number of Basic and Diluted (Details) - shares
shares in Millions

12 Months Ended

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Earnings Per Share [Abstract]

Weighted average number of units outstanding, basic (in units)

^[1]

250.9

212.9

207.6

Add effect of dilutive incentive awards (in units)

^[1]

0.8

1.2

1.0

Weighted average number of units, diluted (in units)

^[1]

251.7

214.1

208.6

[1]	Amounts reflect the second quarter 2014 two-for-one stock split.

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 - Schedule of Weighted Average Number of Basic and Diluted (Phantoms) (Details)		3 Months Ended
	Jun. 12, 2014	Jun. 30, 2014
Earnings Per Share [Abstract]
Stock split conversion ratio	2	2

Net Income Attributable to Sunoco Logistics Partners L.P. Per Limited Partner Unit - Additional Information (Detail) $ in Millions		3 Months Ended								12 Months Ended
	Jun. 12, 2014	Dec. 31, 2015 USD ($)	Sep. 30, 2015 USD ($)	Jun. 30, 2015 USD ($)	Mar. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Sep. 30, 2014 USD ($)	Jun. 30, 2014 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2015 USD ($) $ / PartnershipUnit	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Stock split conversion ratio	2							2
General partnership interest										2.00%	2.00%	2.00%
Maximum incentive percentage distribution received by general partner										50.00%
Incentive distribution, minimum threshold (in dollars per unit) \| $ / PartnershipUnit										0.0833
Net Income (loss) allocated to General Partners \| $		$ 83	$ 74	$ 71	$ 60	$ 50	$ 49	$ 44	$ 38	$ 288	$ 181	$ 124
Percentage of net income attributable to Sunoco Logistics Partners L.P.										73.00%	62.00%	27.00%

Inventories - Schedule of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Inventory Disclosure [Abstract]
Crude oil	$ 424	$ 364
NGLs	83	90
Refined products	83	0
Refined products additives	3	4
Materials, supplies and other	14	12
Total Inventories	$ 607	$ 470

Inventories - Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Crude Oil [Member]
Business Segments for Inventory Write Down [Line Items]
Inventory Valuation Reserves	$ 381	$ 231
Natural Gas Liquids [Member]
Business Segments for Inventory Write Down [Line Items]
Inventory Valuation Reserves	37	$ 27
Refined Products Segment [Member]
Business Segments for Inventory Write Down [Line Items]
Inventory Valuation Reserves	$ 2

Properties, Plants and Equipment - Schedule of Properties, Plants and Equipment (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2015

Dec. 31, 2014

^[1]

Less accumulated depreciation and amortization

$ 11,527

$ 9,358

(835)

(509)

Properties, plants and equipment, net (Note 7)

10,692

8,849

Land and land improvements (including rights of way) [Member]

Pipeline and related assets [Member]

^[2]

1,286

1,212

$ 5,943

4,253

Property, plant and equipment, estimated useful lives

Property, plant and equipment, estimated useful lives

Terminals and storage facilities [Member]

Terminals and storage facilities [Member] | Minimum [Member]

$ 1,985

1,457

Property, plant and equipment, estimated useful lives

Terminals and storage facilities [Member] | Maximum [Member]

Property, plant and equipment, estimated useful lives

Building and Building Improvements [Member]

Building and Building Improvements [Member] | Minimum [Member]

$ 509

245

Property, plant and equipment, estimated useful lives

Building and Building Improvements [Member] | Maximum [Member]

Property, plant and equipment, estimated useful lives

Other [Member]

Other [Member] | Minimum [Member]

$ 177

133

Property, plant and equipment, estimated useful lives

Other [Member] | Maximum [Member]

Property, plant and equipment, estimated useful lives

Construction in progress [Member]

^[3]

$ 1,627

$ 2,058

[1]	December 31, EstimatedUseful Lives 2015 2014 (in years) (in millions)Land and land improvements (including rights-of-way) (1) — $1,286 $1,212Pipelines and related assets 16 - 39 5,943 4,253Terminals and storage facilities 20 - 41 1,985 1,457Buildings and improvements 25 - 32 509 245Other 3 - 20 177 133Construction-in-progress (2) 1,627 2,058Total properties, plants and equipment 11,527 9,358Less: Accumulated depreciation and amortization (835) (509)Total properties, plants and equipment, net $10,692 $8,849
[2]	As of December 31, 2015 and 2014, the Partnership had rights-of-way with a book value of $1.1 and $1.0 billion, respectively.
[3]	As of December 31, 2015 and 2014, accrued capital expenditures were $286 and $283 million, respectively.

Properties, Plants and Equipment Properties, Plants and Equipment - Schedule of Properties, Plants and Equipment (Phantoms) (Details) - USD ($)
$ in Millions

Dec. 31, 2015

Dec. 31, 2014

$ 11,527

$ 9,358

^[1]

Use Rights [Member]

Explorer Pipeline Company [Member]

$ 1,100

$ 1,000

[1]

Properties, Plants and Equipment - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Capital expenditures incurred but not yet paid	$ 286	$ 283

Investment in Affiliates - Schedule of Partnership's Ownership Percentages Not Controlling Financial Interest (Details)

Dec. 31, 2015

Dec. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Schedule of Equity Method Investments [Line Items]

Yellowstone Pipe Line Company [Member]

13.30%

9.40%

Schedule of Equity Method Investments [Line Items]

West Shore Pipe Line Company [Member]

14.00%

Schedule of Equity Method Investments [Line Items]

Wolverine Pipe Line Company [Member]

17.10%

Schedule of Equity Method Investments [Line Items]

Bayview Refining Company, LLC [Member]

31.50%

Schedule of Equity Method Investments [Line Items]

SunVit Pipeline LLC [Member]

49.00%

Schedule of Equity Method Investments [Line Items]

Bayou Bridge Pipeline, LLC [Member]

50.00%

Schedule of Equity Method Investments [Line Items]

Bakken Holdings Company LLC [Member]

30.00%

0.00%

Schedule of Equity Method Investments [Line Items]

^[1]

40.00%

0.00%

[1]	The investment in Bakken HoldCo provides the Partnership with a 30 percent overall ownership interest in the Bakken pipeline project through its ownership in the subsidiary companies which will operate the pipeline system.

Investment in Affiliates - Additional Information (Details) bbl in Thousands, shares in Millions, $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Oct. 31, 2015 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2015 USD ($) bbl	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)	Oct. 08, 2015 shares
Schedule of Equity Method Investments [Line Items]
Excess investment amount			$ 123
Undistributed earnings of unconsolidated affiliates			52
Equity in earnings of unconsolidated affiliates			24	$ 25	$ 21
Distributions from unconsolidated affiliates			$ 23	$ 14	$ 14
Bakken Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage			30.00%			30.00%
Issuance of Class B units \| shares						9.4
Parent company's ownership percentage in joint venture			45.00%
Expected project takeaway capacity, in barrels \| bbl			450
Target project takeaway capacity, in barrels \| bbl			570
Payments to acquire interest in joint venture	$ 382
Bayou Bridge Pipeline, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage			30.00%	0.00%
Parent company's ownership percentage in joint venture			30.00%
Bayview Refining Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage			49.00%	49.00%
Explorer Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage		13.30%	13.30%	13.30%	9.40%
Payments to acquire interest in joint venture		$ 42

Goodwill and Intangible Assets - Components of Intangible Assets (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,358	$ 1,358	$ 1,346
Total gross	883	883
Total accumulated amortization	(165)	(113)
Total Net	$ 718	770
Amortization [Abstract]
Weighted average amortization period	17 years
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Total gross	$ 836	836
Total accumulated amortization	$ (149)	(102)
Amortization [Abstract]
Weighted average amortization period	18 years
Technology [Member]
Finite-Lived Intangible Assets [Line Items]
Total gross	$ 47	47
Total accumulated amortization	$ (16)	$ (11)
Amortization [Abstract]
Weighted average amortization period	10 years

Goodwill and Other Intangible Assets Goodwill and Intangibles - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2015
Goodwill [Line Items]
Goodwill	$ 1,358	$ 1,358	$ 1,346
Amortization expense of intangible assets	52	52	49
Forecasted annual amortization expense in 2016	51
Forecasted annual amortization expense in 2017	51
Forecasted annual amortization expense in 2018	51
Forecasted annual amortization expense in 2019	51
Forecasted annual amortization expense in 2020	51
Crude Oil Pipelines [Member]
Goodwill [Line Items]
Goodwill				$ 200
Crude Oil Acquisition and Marketing [Member]
Goodwill [Line Items]
Goodwill				557
Terminal Facilities [Member]
Goodwill [Line Items]
Goodwill				$ 601
Crude Oil Segment [Member]
Goodwill [Line Items]
Goodwill	912	912	900
Natural Gas Liquids Segment [Member]
Goodwill [Line Items]
Goodwill	357	357	357
Refined Products Segment [Member]
Goodwill [Line Items]
Goodwill	$ 89	$ 89	$ 89

Debt - Partnership's Debt Balances (Details) - USD ($)
$ in Millions

Dec. 31, 2015

Dec. 31, 2014

Unamortized fair value adjustments

$ 5,100

$ 4,100

^[1]

106

Total debt

5,630

4,266

Unamortized bond discount

^[2]

(39)

(32)

$2.50 billion Credit Facility, due March 2020 [Member]

5,591

4,234

$35 million Credit Facility, due April 2015 [Member]

Credit Facility

562

150

Senior Notes - 6.125%, due May 2016 [Member]

Credit Facility

Senior Notes - 5.50%, due February 2020 [Member]

^[3]

175

Senior Notes - 4.40% due April 2021 [Member]

250

Senior Notes - 4.65%, due February 2022 [Member]

600

Senior Notes - 3.45%, due January 2023 [Member]

300

Senior Notes - 4.25%, due April 2024 [Member]

350

Senior Notes - 5.95% due December 2025 [Member]

500

Senior Notes - 6.85%, due February 2040 [Member]

400

Senior Notes - 6.10%, due February 2042 [Member]

250

Senior Notes - 4.95%, due January 2043 [Member]

300

Senior Notes - 5.30%, due April 2044 [Member]

350

Senior Notes - 5.35%, due May 2045 [Member]

700

Distribution Made to Limited Partner [Line Items]

$ 800

[1]	Represents fair value adjustments on senior notes resulting from the application of push-down accounting in connection with the acquisition of the Partnership's general partner by ETP on October 5, 2012.
[2]	In the fourth quarter 2015, the Partnership adopted accounting guidance which requires certain debt issuance costs to be reflected as a reduction in the total long-term debt liability for all periods presented. The net long-term debt balance now includes $32 and $26 million of debt issuance costs at December 31, 2015 and 2014, respectively. Refer to Note 2 for additional information.
[3]	The 6.125 percent Senior Notes were classified as long-term debt at December 31, 2015 as the Partnership has the ability and intent to refinance such borrowings on a long-term basis.

Debt - Partnership's Debt Balances (Phantoms) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Nov. 17, 2015	Nov. 17, 2014	Apr. 03, 2014
Debt Instrument [Line Items]
Debt Issuance Cost	$ 32,000,000	$ 26,000,000
$2.50 billion Credit Facility, due March 2020 [Member]
Debt Instrument [Line Items]
Revolving credit facility	$ 2,500,000,000.00	$ 2,500,000,000.00
Debt instrument maturity	March 2020	March 2020
$35 million Credit Facility, due April 2015 [Member]
Debt Instrument [Line Items]
Revolving credit facility	$ 35,000,000	$ 35,000,000
Debt instrument maturity		April 2015
Senior Notes - 6.125%, due May 2016 [Member]
Debt Instrument [Line Items]
Interest rate	6.125%	6.125%
Debt instrument maturity	May 2016	May 2016
Senior Notes - 5.50%, due February 2020 [Member]
Debt Instrument [Line Items]
Interest rate	5.50%	5.50%
Debt instrument maturity	February 2020	February 2020
Senior Notes - 4.40% due April 2021 [Member]
Debt Instrument [Line Items]
Interest rate	4.40%		4.40%
Debt instrument maturity	April 2021
Senior Notes - 4.65%, due February 2022 [Member]
Debt Instrument [Line Items]
Interest rate	4.65%	4.65%
Debt instrument maturity	February 2022	February 2022
Senior Notes - 3.45%, due January 2023 [Member]
Debt Instrument [Line Items]
Interest rate	3.45%	3.45%
Debt instrument maturity	January 2023	January 2023
Senior Notes - 4.25%, due April 2024 [Member]
Debt Instrument [Line Items]
Interest rate	4.25%	4.25%		4.25%	4.25%
Debt instrument maturity	April 2024	April 2024
Senior Notes - 5.95% due December 2025 [Member]
Debt Instrument [Line Items]
Interest rate	5.95%		5.95%
Debt instrument maturity	December 2025
Senior Notes - 6.85%, due February 2040 [Member]
Debt Instrument [Line Items]
Interest rate	6.85%	6.85%
Debt instrument maturity	February 2040	February 2040
Senior Notes - 6.10%, due February 2042 [Member]
Debt Instrument [Line Items]
Interest rate	6.10%	6.10%
Debt instrument maturity	February 2042	February 2042
Senior Notes - 4.95%, due January 2043 [Member]
Debt Instrument [Line Items]
Interest rate	4.95%	4.95%
Debt instrument maturity	January 2043	January 2043
Senior Notes - 5.30%, due April 2044 [Member]
Debt Instrument [Line Items]
Interest rate	5.30%	5.30%			5.30%
Debt instrument maturity	April 2044	April 2044
Senior Notes - 5.35%, due May 2045 [Member]
Debt Instrument [Line Items]
Interest rate	5.35%	5.35%		5.35%
Debt instrument maturity	April 2045	April 2045

Debt - Long-Term Debt Maturities (Details) $ in Millions	Dec. 31, 2015 USD ($)
Debt Disclosure [Abstract]
2016	$ 175
2017	0
2018	0
2019	0
2020	812
Thereafter	4,550
Total	$ 5,537

Debt - Additional Information (Details)	1 Months Ended	12 Months Ended
Debt - Additional Information (Details)	Feb. 28, 2014 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)	Nov. 17, 2015 USD ($)	Nov. 17, 2014 USD ($)	Sep. 30, 2014 USD ($)	Apr. 03, 2014 USD ($)
Debt Instrument [Line Items]
Interest paid, net of capitalized interest		$ 137,000,000	$ 64,000,000	$ 83,000,000
Long-term Line of Credit [Abstract]
Line of credit facility, maximum borrowing capacity under certain conditions		3.25
Senior Notes [Abstract]
Repayments of senior notes	$ 175,000,000	0	175,000,000	0
Net proceeds from issuance of long-term debt		991,000,000	1,976,000,000	$ 691,000,000
$1.50 billion Credit Facility, due in November 2018 [Member]
Long-term Line of Credit [Abstract]
Revolving credit facility			1,500,000,000.00				$ 1,500,000,000.00
Credit facility outstanding balance			150,000,000
$2.50 billion Credit Facility, due March 2020 [Member]
Long-term Line of Credit [Abstract]
Revolving credit facility		2,500,000,000.00	2,500,000,000.00
Credit facility outstanding balance		$ 562,000,000	$ 150,000,000
Increased consolidated debt to consolidated EBITDA ratio, high end of range		5.0
Increased consolidated debt to consolidated EBITDA ratio, high end of range (during acquisition period)		5.5
Total debt, excluding net unamortized fair value adjustments, to EBTIDA		3.6
Debt instrument maturity		March 2020	March 2020
$35 million Credit Facility, due April 2015 [Member]
Long-term Line of Credit [Abstract]
Revolving credit facility		$ 35,000,000	$ 35,000,000
Credit facility outstanding balance		$ 0	$ 35,000,000
Debt instrument maturity			April 2015
Senior Notes - 4.25%, due April 2024 [Member]
Long-term Line of Credit [Abstract]
Debt instrument maturity		April 2024	April 2024
Senior Notes [Abstract]
Senior notes principal amount						$ 200,000,000		$ 300,000,000
Interest rate		4.25%	4.25%			4.25%		4.25%
Senior Notes - 5.35%, due May 2045 [Member]
Long-term Line of Credit [Abstract]
Debt instrument maturity		April 2045	April 2045
Senior Notes [Abstract]
Senior notes principal amount						$ 800,000,000
Interest rate		5.35%	5.35%			5.35%
Senior Notes - 5.30%, due April 2044 [Member]
Long-term Line of Credit [Abstract]
Debt instrument maturity		April 2044	April 2044
Senior Notes [Abstract]
Senior notes principal amount								$ 700,000,000
Interest rate		5.30%	5.30%					5.30%
Senior Notes - 8.75%, due February 2014 [Member]
Senior Notes [Abstract]
Interest rate	8.75%
Senior Notes - 4.40% due April 2021 [Member]
Long-term Line of Credit [Abstract]
Debt instrument maturity		April 2021
Senior Notes [Abstract]
Senior notes principal amount					$ 600
Interest rate		4.40%			4.40%
Senior Notes - 5.95% due December 2025 [Member]
Long-term Line of Credit [Abstract]
Debt instrument maturity		December 2025
Senior Notes [Abstract]
Senior notes principal amount					$ 400
Interest rate		5.95%			5.95%

Commitments and Contingent Liabilities - Schedule of Future Minimum Rental Payments (Details) $ in Millions	Dec. 31, 2015 USD ($)
Commitments and Contingencies Disclosure [Abstract]
2016	$ 8
2017	8
2018	4
2019	3
2020	3
Thereafter	0
Total	$ 26

Commitments and Contingent Liabilities - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]
Rent expense	$ 22	$ 18	$ 12
Accrued liabilities for environmental remediation	6	14
Environmental remediation expense	8	$ 15	$ 10
Estimated maximum additional reasonable possible losses	$ 9
Indemnified period for Partnership from environmental and toxic tort liabilities	30 years
Percent indemnification for first 21 years after IPO	100.00%
Time period of 100% indemnification after IPO	21 years
Annual increase of Partnership liability for claims asserted	10.00%

Equity Offerings - Additional Information (Details) - USD ($) shares in Millions	1 Months Ended	3 Months Ended			9 Months Ended	12 Months Ended
	Apr. 30, 2015	Sep. 30, 2015	Mar. 31, 2015	Sep. 30, 2014	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Oct. 08, 2015
Partnership Equity And Distribution [Line Items]
Net proceeds from issuance of limited partner units						$ 1,519,000,000	$ 839,000,000	$ 0
At-the-Market Offering [Member]
Partnership Equity And Distribution [Line Items]
Aggregate equity offering		$ 1,000,000,000		$ 1,000,000,000
Issuance of limited partner units to the public (in units)						26.8	10.3
Net proceeds from issuance of limited partner units						$ 890,000,000	$ 477,000,000
ATM fees						$ 10,000,000	6,000,000
Overnight Public Offering [Member]
Partnership Equity And Distribution [Line Items]
Issuance of limited partner units to the public (in units)	2.0		13.5		7.7
Net proceeds from issuance of limited partner units	$ 82,000,000		$ 547,000,000		$ 362,000,000
$1.50 billion Credit Facility, due in November 2018 [Member]
Partnership Equity And Distribution [Line Items]
Revolving credit facility				$ 1,500,000,000.00	$ 1,500,000,000.00		$ 1,500,000,000.00
Common Class B [Member]
Partnership Equity And Distribution [Line Items]
Issuance of Class B units									9.4
Bakken Pipeline [Member]
Partnership Equity And Distribution [Line Items]
Issuance of Class B units									9.4
Class B units, call option									$ 300,000,000
Class B units, put option									$ 313,500,000
Equity method investment, ownership percentage						30.00%			30.00%

Cash Distributions - Schedule of Cash Distribution to Limited and General Partners (Details) - Cash Distribution [Member] - USD ($)
$ / shares in Units, $ in Millions

Nov. 13, 2015

Aug. 14, 2015

May 15, 2015

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

May 15, 2014

Feb. 14, 2014

Nov. 14, 2013

Aug. 14, 2013

May 15, 2013

Feb. 14, 2013

Cash Distribution per Limited Partner Unit (1)

^[1]

$ 0.4580

$ 0.4380

$ 0.4190

$ 0.4000

$ 0.3825

$ 0.3650

$ 0.3475

$ 0.3312

$ 0.3150

$ 0.3000

$ 0.2863

$ 0.2725

Annualized Cash Distribution per Limited Partner Unit (1)

^[1]

$ 1.8320

$ 1.7520

$ 1.6760

$ 1.6000

$ 1.5300

$ 1.4600

$ 1.3900

$ 1.3248

$ 1.2600

$ 1.2000

$ 1.1452

$ 1.0900

Total Cash Distribution to the Limited Partners

$ 119

$ 111

$ 103

$ 92

$ 84

$ 77

$ 72

$ 69

$ 65

$ 62

$ 59

$ 57

Total Cash Distribution to the General Partner

$ 76

$ 69

$ 62

$ 54

$ 49

$ 43

$ 39

$ 35

$ 32

$ 29

$ 26

$ 23

[1]	Amounts reflect the second quarter 2014 two-for-one stock split.

Cash Distributions - Additional Information (Details) $ / shares in Units, $ in Millions			12 Months Ended
	Feb. 12, 2016 USD ($)	Jan. 28, 2016 $ / shares	Dec. 31, 2015 USD ($) $ / PartnershipUnit	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
Partners Capital And Distributions [Line Items]
Incentive distribution, minimum threshold (in dollars per unit) \| $ / PartnershipUnit			0.0833
Maximum incentive percentage distribution received by general partner			50.00%
Total distribution			$ 689	$ 472	$ 366
Dividend Declared [Member] \| Subsequent Event [Member]
Partners Capital And Distributions [Line Items]
Distribution made to member or limited partner, distributions declared, per unit \| $ / shares		$ 0.479
Annualized cash distribution per Limited Partner unit \| $ / shares		$ 1.92
Dividend Paid [Member] \| Subsequent Event [Member]
Partners Capital And Distributions [Line Items]
Total distribution	$ 216
General Partner [Member]
Partners Capital And Distributions [Line Items]
Total distribution			$ 261	$ 166	$ 110
General Partner [Member] \| Dividend Paid [Member] \| Subsequent Event [Member]
Partners Capital And Distributions [Line Items]
Total cash distribution to the General Partner	$ 85

Management Incentive Plan - Summarized Information Restricted Unit Award Activity (Details) - Restricted Stock Units (RSUs) [Member] - $ / shares

12 Months Ended

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]

Number of units, Non-vested and outstanding, beginning balance (units)

^[1]

1,461,801

1,279,162

855,220

Number of Units, Granted (units)

^[1]

1,412,257

719,009

858,246

Number of Units, Performance factor adjustment (units)

^[1],[2]

229,828

202,620

Number of Units, Vested (units)

^[1]

(245,563)

(693,326)

(563,668)

Number of Units, Cancelled/forfeited (units)

^[1]

(90,776)

(72,872)

(73,256)

Number of units, Non-vested and outstanding, ending balance (units)

^[1]

2,537,719

1,461,801

1,279,162

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]

Weighted Average Grant Date Fair Value, Non-vested and outstanding, beginning balance (usd per unit)

^[1]

$ 35.01

$ 26.19

$ 19.48

Weighted Average Grant Date Fair Value, Granted (usd per unit)

^[1]

29.54

41.59

30.00

Weighted Average Grant Date Fair Value, Performance factor adjustment (usd per unit)

^[1],[2]

17.52

15.76

Weighted Average Grant Date Fair Value, Vested (usd per unit)

^[1]

22.08

20.26

18.33

Weighted Average Grant Date Fair Value, Cancelled/forfeited (usd per unit)

^[1]

36.83

30.10

24.19

Weighted Average Grant Date Fair Value, Non-vested and outstanding, ending balance (usd per unit)

^[1]

$ 33.16

$ 35.01

$ 26.19

[1]

The unit volumes and fair values have been adjusted to reflect the June 12, 2014 two-for-one unit split.

[2]

Management Incentive Plan Management Incentive Plan - Summarized Information Restricted Unit Award Activity (Phantoms) (Details)		3 Months Ended	12 Months Ended
	Jun. 12, 2014	Jun. 30, 2014	Dec. 31, 2012
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock split conversion ratio	2	2
Minimum percentage of performance-based restricted shares issued			0.00%
Maximum percentage of performance-based restricted shares issued			200.00%

Management Incentive Plan - Additional Information (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Number of additional shares authorized under the LTIP	10.0
Aggregate grant of restricted units and unit options from LTIP (in units)	9.7	9.7
Restricted stock unit vesting period				5 years
Intrinsic value of restricted units		$ 8	$ 30	$ 21
Compensation cost not yet recognized	$ 52	$ 52
Compensation cost not yet recognized, period for recognition		3 years
Non-cash compensation expense		$ 17	$ 16	$ 14

Derivatives and Risk Management - Fair Values of Partnership's Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$ 30	$ 29
Derivative liabilities	(18)	(14)
Derivative assets and liabilities, net	$ 12	$ 15

Derivatives and Risk Management - Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance (Details) - Commodity Contract [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings			$ (1)
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings	$ 20	$ 61	(6)
Sales And Other Operating Revenue [Member] \| Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings			(1)
Sales And Other Operating Revenue [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings	47	81	(7)
Cost of Products Sold [Member] \| Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings			0
Cost of Products Sold [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings	(26)	$ (20)	$ 1
Operating Expense [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Losses) Recognized in Earnings	$ (1)

Derivatives and Risk Management - Additional Information (Details) bbl in Millions	Dec. 31, 2015 USD ($) bbl	Dec. 31, 2014 USD ($) bbl
Derivative [Line Items]
Open derivative positions, barrels \| bbl	9.2	3.6
Variable-rate borrowings	$ 562,000,000
$2.50 billion Credit Facility, due March 2020 [Member]
Derivative [Line Items]
Revolving credit facility	$ 2,500,000,000.00	$ 2,500,000,000.00

Fair Value Measurements - Additional Information (Details) - USD ($) $ in Billions	Dec. 31, 2015	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Aggregate fair value of the senior notes	$ 4.2	$ 4.1
Senior notes carrying amount	$ 5.1	$ 4.1

Concentration of Credit Risk - Additional Information (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Risks and Uncertainties [Abstract]
Partnership's total revenues derived from crude oil sales, percent	23.00%	25.00%

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

3 Months Ended

12 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

^[1]

$ 10,486

$ 18,088

$ 16,639

382

296

265

$ 118

$ 103

$ (100)

$ 41

$ 258

$ 0

162

^[2]

258

^[2]

^[3]

2,709

2,559

1,018

1,153

971

871

Interest expense, net

(134)

(67)

(77)

(382)

(296)

(265)

(162)

(258)

(21)

(25)

(30)

Unrealized gain (loss) on commodity risk management activities

(17)

(16)

(14)

(4)

Amortization of excess equity method investment

(2)

Proportionate share of unconsolidated affiliates' interest, depreciation and provision for income taxes

(34)

(24)

(20)

Non-cash accrued liability adjustment

Net income attributable to noncontrolling interests

277

(125)

157

158

110

397

^[4]

300

^[4]

474

^[4]

(1)

(2)

(3)

(9)

(11)

Net Income (Loss) Attributable to Redeemable Noncontrolling Interest

Net Income Attributable to Sunoco Logistics Partners L.P.

$ 25

$ 56

$ 276

$ 36

$ (127)

$ 155

$ 156

$ 107

393

291

463

Crude Oil Segment [Member]

^[1]

8,956

16,899

15,953

216

191

176

^[2]

150

231

^[3]

1,377

801

369

656

669

701

Natural Gas Liquids Segment [Member]

(216)

(191)

(176)

^[1]

1,165

959

447

^[2]

^[3]

1,111

1,210

476

333

203

Refined Products Segment [Member]

(76)

(30)

(21)

^[1]

365

230

239

^[2]

^[3]

197

534

155

164

Corporate Segment [Member]

(90)

(75)

(68)

^[3]

$ 24

$ 14

$ 18

[1]	Sales and other operating revenue for the periods presented includes the following amounts from ETP and its affiliates: Year Ended December 31, 2015 2014 2013 (in millions)Crude Oil $193 $866 $1,418Natural Gas Liquids 204 134 63Refined Products 118 70 85Total sales and other operating revenue $515 $1,070 $1,566Total sales and other operating revenue exclude $404, $309 and $280 million attributable to intrasegment activity for the years ended December 31, 2015, 2014 and 2013, respectively.
[2]	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.
[3]	Total capital expenditures exclude acquisitions and investments in equity ownership interests of $131, $448 and $60 million for the years ended December 31, 2015, 2014 and 2013, respectively.
[4]	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.

Business Segment Information - Sales and Other Operating Revenue by Segment (Detail) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Total sales and other operating revenue	$ 100	$ 90	$ 206	$ 119	$ 56	$ 299	$ 409	$ 306	$ 515	$ 1,070	$ 1,566
Crude Oil Segment [Member]
Segment Reporting Information [Line Items]
Total sales and other operating revenue									193	866	1,418
Natural Gas Liquids Segment [Member]
Segment Reporting Information [Line Items]
Total sales and other operating revenue									204	134	63
Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Total sales and other operating revenue									$ 118	$ 70	$ 85

Business Segment Information - Consolidated Balance Sheet Information by Segment (Detail) - USD ($)
$ in Millions

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

$ 802

$ 226

$ 125

1,358

1,346

Crude Oil Segment [Member]

15,489

^[1]

13,618

^[2]

11,890

^[3]

623

912

900

Natural Gas Liquids Segment [Member]

8,802

^[1]

8,579

^[2]

8,233

^[3]

357

Refined Products Segment [Member]

3,764

^[1]

2,401

^[2]

1,442

^[3]

179

173

122

$ 2,747

^[1]

$ 2,458

^[2]

$ 1,894

^[3]

[1]	Sales and other operating revenue for the periods presented includes the following amounts from ETP and its affiliates: Year Ended December 31, 2015 2014 2013 (in millions)Crude Oil $193 $866 $1,418Natural Gas Liquids 204 134 63Refined Products 118 70 85Total sales and other operating revenue $515 $1,070 $1,566Total sales and other operating revenue exclude $404, $309 and $280 million attributable to intrasegment activity for the years ended December 31, 2015, 2014 and 2013, respectively.
[2]	Total identifiable assets include the Partnership's unallocated $47 million cash and cash equivalents, $124 million of properties, plants and equipment, net, and $9 million of other assets.
[3]	Total identifiable assets include the Partnership's unallocated $12 million cash and cash equivalents, $239 million of advances to affiliates, $66 million of properties, plants and equipment, net and $4 million of other assets.

Business Segment Information - Segment Reporting Information (Phantoms) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting [Abstract]
Intrasegment revenue	$ 404	$ 309	$ 280
Payments to acquire net assets			60
Acquisitions and investments in joint ventures	131	448
Equity in earnings of unconsolidated affiliates	$ 24	$ 25	$ 21

Business Segment Information - Consolidated Balance Sheet Information by Segment (Phantoms) (Detail) - USD ($)
$ in Millions

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

$ 37

$ 101

$ 39

$ 3

Corporate Segment [Member]

10,692

8,849

^[1]

133

124

Due from affiliates

239

Quarterly Financial Information Disclosure [Abstract]

$ 7

$ 9

$ 4

[1]

Business Segment Information - Additional Information (Details) bbl in Millions	12 Months Ended
	Dec. 31, 2015 state segment mi bbl
Segment Reporting Information [Line Items]
Number of states in which the partnership operates \| state	35
Principal business segments \| segment	3
Crude Oil Segment [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| mi	5,900
Terminal storage capacity, in barrels	28
Natural Gas Liquids Segment [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| mi	900
Terminal storage capacity, in barrels	5
Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Pipeline length in miles \| mi	1,800
Nederland Terminal [Member] \| Crude Oil Segment [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, in barrels	24
Nederland Terminal [Member] \| Natural Gas Liquids Segment [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, in barrels	1
Fort Mifflin Terminal [Member] \| Crude Oil Segment [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, in barrels	3
Marcus Hook Facility [Member] \| Natural Gas Liquids Segment [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, in barrels	3
Active Marketing Terminals [Member] \| Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Number of terminals	40
Terminal storage capacity, in barrels	8
Eagle Point Terminal [Member] \| Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Terminal storage capacity, in barrels	6

Quarterly Financial Data (Unaudited) - Summarized Quarterly Financial Data (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

$ 2,205

$ 2,317

$ 2,996

$ 2,453

$ 3,819

$ 4,616

$ 4,412

$ 4,171

$ 9,971

$ 17,018

$ 15,073

Impairment charge and other matters (Notes 2 and 6)

100

206

119

299

409

306

515

1,070

1,566

Gross profit

^[1]

312

325

326

214

258

279

276

226

118

103

(100)

258

162

^[2]

258

^[2]

307

(112)

172

180

127

530

367

560

Net Income attributable to noncontrolling interests

277

(125)

157

158

110

397

^[3]

300

^[3]

474

^[3]

Net Income (Loss) Attributable to Redeemable Noncontrolling Interest

Net Income Attributable to Sunoco Logistics Partners L.P.

276

(127)

155

156

107

393

291

463

Less: General Partner's interest

(83)

(74)

(71)

(60)

(50)

(49)

(44)

(38)

(288)

(181)

(124)

Limited Partners’ interest

$ (58)

$ (18)

$ 205

$ (24)

$ (177)

$ 106

$ 112

$ 69

$ 105

$ 110

$ 339

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—basic (in usd per unit)

$ (0.21)

$ (0.07)

$ 0.83

$ (0.10)

$ (0.80)

$ 0.50

$ 0.54

$ 0.33

$ 0.42

^[4]

$ 0.52

^[4]

$ 1.63

^[4]

Net Income attributable to Sunoco Logistics Partners L.P. per Limited Partner unit—diluted (in usd per unit)

$ (0.21)

$ (0.07)

$ 0.83

$ (0.10)

$ (0.80)

$ 0.50

$ 0.53

$ 0.33

$ 0.42

^[4]

$ 0.51

^[4]

$ 1.63

^[4]

[1]	Gross profit equals sales and other operating revenue less cost of products sold and operating expenses.
[2]	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.
[3]	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.
[4]	Amounts reflect the second quarter 2014 two-for-one stock split.

Supplemental Condensed Consolidating Financial Information - Condensed Consolidating Statement of Comprehensive Income (Details) - USD ($)
$ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Revenues [Abstract]

$ 2,205

$ 2,317

$ 2,996

$ 2,453

$ 3,819

$ 4,616

$ 4,412

$ 4,171

$ 9,971

$ 17,018

$ 15,073

100

206

119

299

409

306

515

1,070

1,566

Total Revenues

10,486

18,088

16,639

Cost of products sold

9,145

16,877

15,600

Operating expenses

164

172

122

103

118

382

296

265

118

103

(100)

258

162

^[1]

258

^[1]

9,956

17,721

16,079

Interest cost to affiliates, net

307

(112)

172

180

127

530

367

560

(1)

(210)

(146)

(97)

Capitalized interest

Other income

418

325

504

(21)

(25)

(30)

277

(125)

157

158

110

397

^[2]

300

^[2]

474

^[2]

Net Income attributable to noncontrolling interests

(1)

(1)

(2)

(3)

(9)

(11)

Net income attributable to redeemable noncontrolling interests (Note 3)

(1)

Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.

$ 25

$ 56

$ 276

$ 36

$ (127)

$ 155

$ 156

$ 107

393

291

463

(1)

Less: Comprehensive income attributable to noncontrolling interests

396

301

474

(3)

(9)

(11)

Less: Comprehensive income attributable to redeemable noncontrolling interests

(1)

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

392

292

463

Parent Guarantor [Member]

393

291

463

393

291

463

Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.

393

291

463

393

291

463

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

393

291

463

393

291

463

Subsidiary Issuer [Member]

Interest cost to affiliates, net

(1)

(209)

(146)

(96)

Capitalized interest

526

354

535

392

291

463

Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.

392

291

463

392

291

463

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

392

291

463

392

291

463

Non-Guarantor Subsidiaries [Member]

Revenues [Abstract]

9,971

17,018

15,073

515

1,070

1,566

Total Revenues

10,486

18,088

16,639

Cost of products sold

9,145

16,877

15,600

Operating expenses

164

172

122

102

118

382

296

265

162

258

9,955

17,721

16,079

Interest cost to affiliates, net

531

367

560

(4)

(1)

Other income

552

388

576

(21)

(25)

(30)

531

363

546

Net Income attributable to noncontrolling interests

(1)

(3)

(9)

(11)

Net income attributable to redeemable noncontrolling interests (Note 3)

(1)

Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.

527

354

535

(1)

Less: Comprehensive income attributable to noncontrolling interests

530

364

546

(3)

(9)

(11)

Less: Comprehensive income attributable to redeemable noncontrolling interests

(1)

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

526

355

535

Consolidating Adjustments [Member]

(919)

(645)

(998)

(919)

(645)

(998)

Net Income (Loss) Attributable to Sunoco Logistics Partners L.P.

(919)

(645)

(998)

(919)

(645)

(998)

Comprehensive Income attributable to Sunoco Logistics Partners L.P.

(919)

(645)

(998)

$ (919)

$ (645)

$ (998)

[1]	Represents non-cash write downs on the Partnership's crude oil, NGLs and refined products inventories.
[2]	Net income includes $24, $25, and $21 million for the years ended December 31, 2015, 2014 and 2013, respectively, of equity income attributable to the equity ownership interest.

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

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

$ 37,000,000

$ 101,000,000

$ 39,000,000

$ 3,000,000

20,000,000

9,000,000

1,165,000,000

1,766,000,000

607,000,000

470,000,000

Other current assets

19,000,000

3,000,000

1,848,000,000

2,349,000,000

10,692,000,000

8,849,000,000

^[1]

802,000,000

226,000,000

1,358,000,000

1,346,000,000

Intangible assets, net

718,000,000

770,000,000

71,000,000

66,000,000

15,489,000,000

^[2]

13,618,000,000

^[3]

11,890,000,000

^[4]

Accounts payable, affiliated companies

1,251,000,000

1,934,000,000

39,000,000

21,000,000

329,000,000

304,000,000

Accrued taxes payable

44,000,000

52,000,000

1,663,000,000

2,311,000,000

Other deferred credits and liabilities

5,591,000,000

4,234,000,000

125,000,000

71,000,000

Deferred income taxes

254,000,000

249,000,000

7,633,000,000

6,865,000,000

Redeemable Limited Partners' interests

15,000,000

286,000,000

7,521,000,000

6,678,000,000

Noncontrolling interests

34,000,000

60,000,000

7,555,000,000

6,738,000,000

Parent Guarantor [Member]

15,489,000,000

13,618,000,000

6,488,000,000

6,189,000,000

6,488,000,000

6,189,000,000

1,000,000

(1,320,000,000)

(489,000,000)

(1,319,000,000)

(489,000,000)

Redeemable Limited Partners' interests

(1,319,000,000)

(489,000,000)

286,000,000

7,521,000,000

6,678,000,000

7,521,000,000

6,678,000,000

Subsidiary Issuer [Member]

6,488,000,000

6,189,000,000

37,000,000

101,000,000

12,000,000

2,000,000

3,000,000

40,000,000

104,000,000

9,692,000,000

9,168,000,000

6,000,000

2,000,000

9,738,000,000

9,274,000,000

1,000,000

66,000,000

58,000,000

(2,408,000,000)

(1,172,000,000)

(2,341,000,000)

(1,114,000,000)

5,591,000,000

4,199,000,000

3,250,000,000

3,085,000,000

6,488,000,000

6,189,000,000

6,488,000,000

6,189,000,000

Non-Guarantor Subsidiaries [Member]

9,738,000,000

9,274,000,000

$ 27,000,000

$ 1,000,000

17,000,000

6,000,000

1,165,000,000

1,766,000,000

607,000,000

470,000,000

Other current assets

19,000,000

3,000,000

1,808,000,000

2,245,000,000

10,692,000,000

8,849,000,000

802,000,000

226,000,000

1,358,000,000

Intangible assets, net

718,000,000

770,000,000

65,000,000

64,000,000

15,443,000,000

13,512,000,000

Accounts payable, affiliated companies

1,250,000,000

1,934,000,000

39,000,000

21,000,000

262,000,000

246,000,000

Accrued taxes payable

44,000,000

52,000,000

3,728,000,000

1,661,000,000

5,323,000,000

3,914,000,000

Other deferred credits and liabilities

35,000,000

125,000,000

71,000,000

Deferred income taxes

254,000,000

249,000,000

5,702,000,000

4,269,000,000

15,000,000

9,692,000,000

9,168,000,000

Noncontrolling interests

34,000,000

60,000,000

9,726,000,000

9,228,000,000

Consolidating Adjustments [Member]

15,443,000,000

13,512,000,000

(16,180,000,000)

(15,357,000,000)

(16,180,000,000)

(15,357,000,000)

(16,180,000,000)

(15,357,000,000)

(16,180,000,000)

(15,357,000,000)