Andeavor Logistics (ANDX) 10-K 24 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Billions, except Share data, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014	Feb. 18, 2015
Entity Registrant Name	TESORO LOGISTICS LP
Entity Central Index Key	1507615
Document Type	10-K
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float		$2.60
Common
Entity Common Stock, Units Outstanding			80,155,850
General Partner
Entity Common Stock, Units Outstanding			1,631,448

Combined_Consolidated_Statemen

Combined Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
REVENUES
Affiliate	$497	[1]	$273	[1]	$150	[1]
Third-party	103	[1]	40	[1]	14	[1]
Total Revenues	600	[1]	313	[1]	164	[1]
COSTS AND EXPENSES
Operating and maintenance expenses	290	[1]	174	[1]	87	[1]
Imbalance settlement gains and reimbursement from Tesoro	-43	[1]	-12	[1]	-12	[1]
General and administrative expenses	74	[1]	32	[1]	16	[1]
Depreciation and amortization expenses	77	[1],[2]	45	[2]	15	[2]
Loss (gain) on asset disposals and impairments	-4	[1],[2]	0	[1],[2]	1	[1],[2]
Total Costs and Expenses	394	[1]	239	[1]	107	[1]
OPERATING INCOME	206	[1]	74	[1]	57
Interest and financing costs, net	-109	[1]	-40	[1]	-9	[1]
Equity in earnings of unconsolidated affiliates	1	[1],[2]	0	[1],[2]	0	[1],[2]
Interest income	0	[1]	1	[1]	0	[1]
NET INCOME (LOSS)	98	[1],[2]	35	[1],[2]	48	[1],[2]
Loss attributable to Predecessors	4	[1],[3]	45	[1]	9	[1]
Net income attributable to noncontrolling interest	-3	[1]	0	[1]	0	[1]
Net income attributable to partners	99	[1]	80	[1]	57	[1]
General partner's interest in net income, including incentive distribution rights	-43	[1]	-12	[1]	-3	[1]
Limited partners’ interest in net income	$56	[1]	$68	[1]	$54	[1]
Net income per limited partner unit:
Common - basic (dollars per unit)	$0.96	[4]	$1.48	[4]	$1.90
Common - diluted (dollars per unit)	$0.96	[4]	$1.47	[4]	$1.89
Subordinated - basic and diluted (dollars per unit)	$0.62	[4]	$1.35	[4]	$1.47
Weighted average limited partner units outstanding:
Common units - basic (units)	54,203,508		31,545,935		16,614,668
Common units - diluted (units)	54,249,416		31,618,434		16,708,950
Subordinated units - basic and diluted (units)	5,642,220	[5]	15,254,890	[5]	15,254,890	[5]
Cash distributions paid per unit	$2.41		$2.02		$1.61
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[3]	Amounts attributable to Predecessors have been reflected in the Parent column.
[4]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of shares outstanding.
[5]	On May 16, 2014, the 15,254,890 subordinated units were converted into common units on a one-for-one basis and thereafter participate on terms equal with all other common units in distributions of available cash. Distributions and the Partnership’s net income were allocated to the subordinated units through May 15, 2014.

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$19	[1]	$23	[1]
Receivables, net
Trade	122		9	[1]
Affiliate	69		43	[1]
Other	18		14	[1]
Prepayments and other	7		7	[1]
Total Current Assets	235		96	[1]
NET PROPERTY, PLANT AND EQUIPMENT	3,306		1,398	[1]
INTANGIBLES	973		0	[1]
GOODWILL	164		9	[1]
Investment in unconsolidated affiliates	57		0	[1]
OTHER NONCURRENT ASSETS	79		30	[1]
Total Assets	4,814		1,533	[1]
Accounts payable
Trade	126		22	[1]
Affiliate	53		14	[1]
Accrued interest and financing costs	28		23	[1]
Other current liabilities	79		30	[1]
Total Current Liabilities	286		89	[1]
OTHER NONCURRENT LIABILITIES	45		6	[1]
DEBT	2,593		1,164	[1]
COMMITMENTS AND CONTINGENCIES (Note 11)				[1]
EQUITY
Equity of Predecessors	0		29	[1]
Common unitholders: 80,125,930 units issued and outstanding (39,148,916 in 2013)	1,474		459	[1]
Subordinated unitholders: 0 units issued and outstanding (15,254,890 in 2013)	0		-161	[1]
General partner: 1,631,448 units issued and outstanding (1,110,282 in 2013)	-19		-53	[1]
Noncontrolling interest	435		0	[1]
Total Equity	1,890		274	[1]
Total Liabilities and Equity	$4,814		$1,533	[1]
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Combined_Consolidated_Balance_

Combined Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$19	[1]	$23	[1]
Property, Plant and Equipment, Net
NET PROPERTY, PLANT AND EQUIPMENT	3,306		1,398	[1]
Equity
Common units issued (units)	80,125,930		39,148,916
Subordinated units issued (units)	0		15,254,890
General partner units issued (units)	1,631,448		1,110,282
Common units outstanding (units)	80,125,930		39,148,916
Subordinated units outstanding (units)	0		15,254,890
General partner units outstanding (units)	1,631,448		1,110,282
QEPM
CURRENT ASSETS
Cash and cash equivalents	15		0
Property, Plant and Equipment, Net
NET PROPERTY, PLANT AND EQUIPMENT	$476		$0
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Combined_Consolidated_Statemen1

Combined Consolidated Statements of Partners' Equity (USD $)		Total		Equity of Predecessors		Common	Subordinated	General Partner	Non-controlling Interest
In Millions, unless otherwise specified
Balance at Beginning of Period, Partnership at Dec. 31, 2011		$192				$250	($143)	$2	$0
Balance at Beginning of Period, Equity of Predecessors at Dec. 31, 2011	[1]			83
Partners' Capital
Sponsor contributions of equity to the Predecessors		61		61	[1]	0	0	0	0
Loss attributable to Predecessors		-9	[2]	-9	[1]	0	0	0	0
Net liabilities not assumed by Tesoro Logistics LP		2		2	[1]	0	0	0	0
Allocation of net assets acquired by the unitholders		0		-111	[1]	98	0	13	0
Equity offering, net of issuance costs		171		0	[1]	174	-3	0	0
Quarterly distributions to unitholders and general partner		-53		0	[1]	-26	-25	-2	0
Distributions to unitholders and general partner related to assets acquired	[3]	-419		0	[1]	-376	0	-43	0
Net income attributable to partners		57	[2]	0	[1]	28	26	3	0
Other		6		0	[1]	5	1	0	0
Partner's capital additional information
Cash payments for acquisitions		419
Decrease in equity balance due to acquisitions		-308
Balance at End of Period, Partnership at Dec. 31, 2012		8				153	-144	-27	0
Balance at End of Period, Equity of Predecessors at Dec. 31, 2012	[1]			26
Partners' Capital
Sponsor contributions of equity to the Predecessors		29		29	[1]	0	0	0	0
Sponsor contributions of assets acquired to the Predecessors		702		702	[1]	0	0	0	0
Loss attributable to Predecessors		-45	[2]	-45	[1]	0	0	0	0
Net liabilities not assumed by Tesoro Logistics LP		15		15	[1]	0	0	0	0
Allocation of net assets acquired by the unitholders		0		-698	[1]	655	0	43	0
Equity offering, net of issuance costs		709		0	[1]	710	-9	8	0
Quarterly distributions to unitholders and general partner		-102		0	[1]	-63	-30	-9	0
Distributions to unitholders and general partner related to assets acquired	[3]	-1,129		0	[1]	-1,049	0	-80	0
Net income attributable to partners		80	[2]	0	[1]	46	22	12	0
Other		7		0	[1]	7	0	0	0
Partner's capital additional information
Cash payments for acquisitions		1,100
Decrease in equity balance due to acquisitions		431
Balance at End of Period, Partnership at Dec. 31, 2013		274	[1]			459	-161	-53	0
Balance at End of Period, Equity of Predecessors at Dec. 31, 2013	[1]	29		29
Partners' Capital
Sponsor contributions of equity to the Predecessors		3		3	[1]	0	0	0	0
Loss attributable to Predecessors		-4	[2],[4]	-4	[1]	0	0	0	0
Net liabilities not assumed by Tesoro Logistics LP		1		1	[1]	0	0	0	0
Allocation of net assets acquired by the unitholders		0		-29		28	0	1	0
Equity offerings		1,510		0	[1]	1,480	0	30	0
Equity issuance costs		-32		0	[1]	-31	0	-1	0
Quarterly distributions to unitholders and general partner		-183		0	[1]	-131	-17	-35	0
Subordinated unit conversion		0		0	[1]	-165	165	0	0
Distributions to unitholders and general partner related to assets acquired	[3]	-243		0	[1]	-237	0	-6	0
Contributions		29		0	[1]	27	0	2	0
Net income attributable to partners	[2]	99
Net Income		102		0	[1]	43	13	43	3
Noncontrolling interest acquired		432		0	[1]	0	0	0	432
Other		1		0	[1]	1	0	0	0
Partner's capital additional information
Cash payments for acquisitions		243
Decrease in equity balance due to acquisitions		214
Balance at End of Period, Partnership at Dec. 31, 2014		1,890				1,474	0	-19	435
Balance at End of Period, Equity of Predecessors at Dec. 31, 2014		$0		$0	[1]
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[3]	Distributions to unitholders and general partner include $243 million, $1.1 billion and $419 million in cash payments for acquisitions from Tesoro during 2014, 2013 and 2012, respectively. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesorobs historical book value instead of fair value, andB any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity.B As a result of this accounting treatment, these transactions resulted in net decreases of $214 million, $431 million and $308 million in our equity balance during 2014, 2013 and 2012, respectively.
[4]	Amounts attributable to Predecessors have been reflected in the Parent column.

Combined_Consolidated_Statemen2

Combined Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net Income	$98	[1],[2]	$35	[1],[2]	$48	[1],[2]
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization expenses	77	[1],[2]	45	[2]	15	[2]
Amortization of debt issuance costs	6	[2]	2	[2]	1	[2]
Unit-based compensation expense	2	[2]	2	[2]	1	[2]
Loss (gain) on asset disposals and impairments	-4	[1],[2]	0	[1],[2]	1	[1],[2]
Earnings from unconsolidated affiliates in excess of distributions	-1	[1],[2]	0	[1],[2]	0	[1],[2]
Changes in receivables	8		48		8
Changes in current assets	10		-2		0
Changes in current liabilities	9		47		13
Changes in other noncurrent assets and liabilities	-4	[2]	12	[2]	1	[2]
Net cash from operating activities	185	[2]	93	[2]	72	[2]
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	-199	[2]	-76	[2]	-93	[2]
Acquisitions	-2,479	[2]	-315	[2]	-40	[2]
Capital expenditure reimbursements	0	[2]	0	[2]	5	[2]
Proceeds from sale of assets	10	[2]	0	[2]	0	[2]
Net cash used in investing activities	-2,668	[2]	-391	[2]	-128	[2]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	1,300	[2]	806	[2]	350	[2]
Proceeds from issuance of common units, net of issuance costs	1,449	[2]	701	[2]	171	[2]
Proceeds from Issuance of general partner units, net of issuance costs	29	[2]	8	[2]	0	[2]
Distributions related to acquisitions	-243	[2]	-1,129	[2]	-419	[2]
Quarterly distributions to unitholders	-148	[2]	-93	[2]	-51	[2]
Quarterly distributions to general partner	-35	[2]	-9	[2]	-2	[2]
Repayments under revolving credit agreement	-386	[2]	-794	[2]	-118	[2]
Borrowings under revolving credit agreement	646	[2]	794	[2]	68	[2]
Repayments of debt	-130	[2]	0	[2]	0	[2]
Sponsor contributions of equity to the Predecessors	3		29		61
Financing costs	-32	[2]	-16	[2]	-9	[2]
Capital contributions by affiliate	26	[2]	5	[2]	6	[2]
Net cash from financing activities	2,479	[2]	302	[2]	57	[2]
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-4	[2]	4	[2]	1	[2]
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	23	[2]	19	[2]	18	[2]
CASH AND CASH EQUIVALENTS, END OF YEAR	$19	[2]	$23	[2]	$19	[2]
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Description_of_Business_and_Su

Description of Business and Summary of Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	DESCRIPTION OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Description of Business
	Tesoro Logistics LP (“TLLP” or the “Partnership”) is a fee-based, growth-oriented Delaware limited partnership formed in December 2010 by Tesoro Corporation and its wholly owned subsidiary, Tesoro Logistics GP, LLC (“TLGP”), our general partner in December 2010 to own, operate, develop and acquire logistics assets. Unless the context otherwise requires, references in this report to “we,” “us,” “our,” or “ours” refer to Tesoro Logistics LP, one or more of its consolidated subsidiaries or all of them taken as a whole. The words “we,” “us,” “our,” or “ours” generally include our 57.8% interest in QEP Midstream Partners, LP (“QEPM”), a publicly traded limited partnership, and its subsidiaries as consolidated subsidiaries of TLLP with certain exceptions where there are transactions or obligations between QEPM and TLLP or its other subsidiaries. Unless the context otherwise requires, references in this report to “Tesoro” or our “Sponsor” refer collectively to Tesoro Corporation and any of its subsidiaries, other than TLLP, its subsidiaries and its general partner.
	In April 2011, we completed our initial public offering (the “Initial Offering”) of 14,950,000 common units representing limited partner interests. Our logistics assets are integral to the success of Tesoro’s refining and marketing operations and are used to gather crude oil and to distribute, transport and store crude oil and refined products. We are a full-service logistics company operating primarily in the western and mid-continent regions of the United States. We own and operate a network of crude oil, refined products and natural gas pipelines as well as operate 28 crude oil and refined products truck and marine terminals and provide crude oil and refined product storage capacity. In addition, we own and operate four natural gas processing complexes and one fractionation facility. Our assets are categorized into a Gathering segment, a Processing segment and a Terminalling and Transportation segment.
	We generate revenue by charging fees for gathering crude oil and natural gas, for processing natural gas, for terminalling, transporting and storing crude oil, and refined products. With the exception of a small amount of condensate, we are not exposed to commodity price risk with respect to any of the crude oil, natural gas, NGLs or refined products that we handle. For the NGLs that we handle under keep-whole agreements, the Partnership has a fee-based processing agreement with Tesoro which minimizes the impact of commodity price movement during the annual period subsequent to renegotiation of terms and pricing each year. We do not engage in the trading of crude oil, natural gas, NGLs or refined products; therefore we have minimal direct exposure to risks associated with commodity price fluctuations. However, these risks indirectly influence our activities and results of operations over the long term through their effects on our customers’ operations. In 2014, 83% of our revenue was derived from Tesoro primarily under various long-term, fee-based commercial agreements that generally include minimum volume commitments.
	Our Gathering segment consists of a crude oil gathering system (the “High Plains System”) and natural gas gathering systems in the Uinta basin. Our High Plains System, located in the Bakken Shale/Williston Basin area of North Dakota and Montana (the “Bakken Region”), gathers and transports crude oil from various production locations in this area for transportation to Tesoro’s North Dakota refinery and other destinations in the Bakken Region, including export rail terminals and pipelines. Our natural gas gathering systems in the Uinta basin include the Uinta Basin Gathering System and our equity method investment Uintah Basin Field Services, LLC. In addition, we own approximately 57.8% of QEPM, whose assets include ownership interests in four gathering systems and two Federal Energy Regulatory Commission regulated pipelines through which it provides natural gas and crude oil gathering and transportation services.
	Our Processing segment consists of four gas processing complexes, including a 60% interest in Green River Processing, LLC, which owns one fractionation facility and two gas processing complexes, with the remaining 40% interest owned by QEPM.
	Our Terminalling and Transportation segment consists of:
	•	a regulated common carrier products pipeline running from Salt Lake City, Utah to Spokane, Washington and a jet fuel pipeline to the Salt Lake City International Airport (the “Northwest Products Pipeline”);
	•	a regulated common carrier refined products pipeline system connecting Tesoro’s Kenai refinery to Anchorage, Alaska;
	•	24 crude oil and refined products terminals and storage facilities in the western and midwestern U.S.;
	•	four marine terminals in California;
	•	a rail-car unloading facility in Washington;
	•	a petroleum coke handling and storage facility in Los Angeles; and
	•	other pipelines which transport products and crude oil from Tesoro’s refineries to nearby facilities in Salt Lake City and Los Angeles.
	Principles of Combination and Consolidation and Basis of Presentation
	The accompanying consolidated financial statements include the accounts of TLLP and its subsidiaries. All intercompany accounts and transactions have been eliminated. We have evaluated subsequent events through the filing of this Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. Certain prior year balances have been reclassified to conform to current year presentation.
	In 2014, 2013 and 2012, we entered into various transactions with Tesoro and our general partner, TLGP, pursuant to which TLLP acquired from Tesoro the following:
	•	three truck terminals, ten storage tanks, two rail loading and unloading facilities and a refined products pipeline (the “West Coast Logistics Assets”) effective July 1, 2014 for the terminals, storage tanks and rail facilities and effective September 30, 2014 for the refined products pipeline (the “West Coast Logistics Assets Acquisition”);
	•	two marine terminals, a marine storage terminal, a products terminal, a petroleum coke handling and storage facility, over 100 miles of active crude oil and refined products pipeline and certain assets and properties related thereto located in Southern California (the “Los Angeles Logistics Assets”) effective December 6, 2013 (the “Los Angeles Logistics Assets Acquisition”);
	•	six marketing terminals and storage facilities located in Southern California and certain assets and properties related thereto (the “Los Angeles Terminal Assets”) effective June 1, 2013 (the “Los Angeles Terminal Assets Acquisition”);
	•	the Anacortes rail car unloading facility assets (collectively, the “Anacortes Rail Facility”) effective November 15, 2012 (the “Anacortes Rail Facility Acquisition”);
	•	the Long Beach marine terminal and related short-haul pipelines, including the Los Angeles short-haul pipelines effective September 14, 2012 (the “Long Beach Assets Acquisition”); and
	•	the Martinez crude oil marine terminal assets effective April 1, 2012 (the “Martinez Marine Terminal Acquisition”).
	These transactions are collectively referred to as “Acquisitions from Tesoro” and the related assets, liabilities and results of the operations are collectively referred to as the “Predecessors.”
	The Acquisitions from Tesoro were transfers between entities under common control. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro on our consolidated balance sheet at Tesoro’s historical basis instead of fair value. Transfers of businesses between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior periods are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of TLLP have been retrospectively adjusted to include the historical results of the assets acquired in the Acquisitions from Tesoro prior to the effective date of each acquisition. Also there was no financial statement impact related to the Los Angeles Terminal Assets since they were not operated by Tesoro prior to their acquisition by TLLP. See Note 2 for additional information regarding the 2014 and 2013 acquisitions.
	The accompanying financial statements and related notes present the combined financial position, results of operations, cash flows and equity of our Predecessors at historical cost. The financial statements of our Predecessors have been prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment. Accordingly, the revenues in our Predecessors’ historical combined financial statements relate only to amounts received from third parties for these services and amounts received from affiliates with respect to transportation regulated by the Regulatory Commission of Alaska (“RCA”) for the refined products pipeline included in the West Coast Logistics Assets Acquisition.
	On December 2, 2014, the Partnership acquired all of the limited liability company interests of QEP Field Services, LLC (“QEPFS”) for an aggregate purchase price of approximately $2.5 billion in cash (the “Rockies Natural Gas Business Acquisition”). See Note 2 for additional information regarding the Rockies Natural Gas Business Acquisition.
	Our consolidated financial statements include QEPM, a variable interest entity with the portion not owned by TLLP reflected as a reduction to net income and equity as a noncontrolling interest. QEP Midstream Partners GP, LLC (“QEPM GP”), TLLP’s fully consolidated subsidiary, serves as QEPM’s general partner. As the general partner of QEPM, we have the sole ability to direct the activities of QEPM that most significantly impact its economic performance. We are also considered to be the primary beneficiary for accounting purposes. QEPM provides natural gas gathering and transportation services, primarily under fee-based contracts. Under these arrangements, QEPM receives a fee or fees for one or more of the following services: firm and interruptible gathering or transmission of natural gas, crude oil, condensate, and produced water. In the event QEPM incurs a loss, our operating results will reflect QEPM’s loss, net of intercompany eliminations, to the extent of our ownership interest in QEPM. All intercompany transactions with QEPM are eliminated upon consolidation. We did not elect to apply pushdown accounting to QEPM. As a result, separate financial information of QEPM represents the historical carrying value of the assets as of December 31, 2014.
	As of December 31, 2014, QEPM was a guarantor of our amended revolving credit facility (the “Revolving Credit Facility”). See further discussion regarding guarantors of our senior notes in Note 10 and Note 16.
	Under the unsecured affiliate credit agreement between QEPFS and QEPM (“Affiliate Credit Agreement”), QEPFS has agreed to provide revolving loans and advances to QEPM up to a borrowing capacity of $500 million. The Affiliate Credit Agreement is available for working capital, capital expenditures, permitted acquisitions and general corporate purposes, including distributions. As of December 31, 2014, there was $210 million owed to QEPFS under the Affiliate Credit Agreement, which was eliminated upon consolidation. The maturity date of the Affiliate Credit Agreement is August 14, 2018, and borrowings under the Affiliate Credit Agreement bear interest at a rate of 1.92%.
	QEPM has a 78% interest in Rendezvous Gas Services, L.L.C. (“Rendezvous Gas”), a non-wholly owned subsidiary, which owns a gas gathering system located in Wyoming. Rendezvous Gas is consolidated by QEPM under the voting interest model.
	Use of Estimates
	We prepare our combined consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”), which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and revenues and expenses reported and presented as of and for the periods ended. We review our estimates on an ongoing basis using currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates.
	Reclassifications
	Certain prior year balances have been reclassified in order to conform to the current year presentation including amounts within operating and maintenance expenses to disaggregate reimbursements from Tesoro, which are now included in imbalance settlement gains and reimbursements from Tesoro within the combined consolidated statements of operations.
	Acquisitions
	We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed with acquisitions at their estimated fair values as of the date of acquisition, with the exception of the Acquisitions from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro on our consolidated balance sheet at Tesoro’s historical basis instead of fair value. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. While we use our best estimates and assumptions to measure the fair value of the identifiable assets acquired and liabilities assumed at the acquisition date, our estimates are inherently uncertain and subject to refinement. As a result, during the measurement period, not to exceed one year from the date of acquisition, any changes in the estimated fair values of the net assets recorded for the acquisitions will result in an adjustment to goodwill. Upon the conclusion of the measurement period or final determination of the values of assets acquired or liabilities assumed, whichever comes first, any subsequent adjustments are recorded to our combined consolidated statements of operations.
	Cash and Cash Equivalents
	Cash and cash equivalents include bank deposits and low-risk short-term investments with original maturities of three months or less at the time of purchase. Cash equivalents are stated at cost, which approximates market value. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.
	Receivables
	A portion of the Partnership’s accounts receivable is due from Tesoro. Credit for non-affiliated customers is extended based on an evaluation of each customer’s financial condition and in certain circumstances, collateral, such as letters of credit or guarantees, is required. Our allowance for doubtful accounts is based on various factors including current sales amounts, historical charge-offs and specific accounts identified as high risk. Uncollectible accounts receivable are charged against the allowance for doubtful accounts when all reasonable efforts to collect the amounts due have been exhausted. The Partnership had an immaterial amount of allowance for doubtful accounts at both December 31, 2014 and 2013.
	Financial Instruments
	Financial instruments including cash and cash equivalents, receivables, accounts payable and accrued liabilities are recorded at their carrying value. We believe the carrying value of these financial instruments approximates fair value. Our fair value assessment incorporates a variety of considerations, including:
	•	the short term duration of the instruments (less than one percent of our trade payables and seven percent of our third-party receivables have been outstanding for greater than 90 days); and
	•	the expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk.
	The computation of the percentage of the short-term duration of our third-party receivables excludes amounts that are greater than 90 days related to XTO Energy Inc.’s (“XTO”) legal dispute with QEPFS. See further discussion regarding the XTO litigation in Note 11.
	The fair value of our senior notes is based on prices from recent trade activity and is categorized in level 2 of the fair value hierarchy. The carrying value and fair value of our debt were both approximately $2.6 billion at December 31, 2014 and were both approximately $1.2 billion at December 31, 2013.
	Property, Plant and Equipment
	Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation or fair value, if impaired. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering and other allocated employee costs. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and maintenance projects that do not increase the original efficiency, productivity or capacity of property, plant and equipment are expensed as incurred. We capitalize interest as part of the cost of major projects during the construction period. These costs are recorded as a reduction to interest and financing costs.
	We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of three to 28 years and salvage value of each asset. When assets are placed into service, we make estimates with respect to their useful lives that we believe are reasonable. However, factors such as maintenance levels, economic conditions impacting the demand for these assets and regulatory or environmental requirements could cause us to change our estimates, thus impacting the future calculation of depreciation. We depreciate leasehold improvements and property acquired under capital leases over the lesser of the lease term or the economic life of the asset.
	Impairment of Long-Lived Assets
	We review property, plant and equipment and other long-lived assets, including acquired intangibles with finite lives, for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. If this occurs, an impairment loss is recognized for the difference between the asset fair value and net book value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.
	Acquired Intangibles
	Acquired intangibles are recorded at fair value as of the date acquired, and consist of customer relationships obtained in connection with the Rockies Natural Gas Business Acquisition. The value for the identified customer relationships consists of cash flow expected from existing contracts and future arrangements from the existing customer base. We amortize acquired intangibles with finite lives on a straight-line basis over an estimated weighted average useful life of 35 years, and we include the amortization in depreciation and amortization on our combined consolidated statements of operations. Amortization expense of $2 million was included in our financial statements for the year ended December 31, 2014. Amortization expense is expected to be approximately $28 million per year for the next five years beginning January 1, 2015. We have not yet finalized our valuation estimate and related evaluation of the useful lives; accordingly, future amortization of intangible assets related to customer relationships may be revised.
	Goodwill
	Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. We do not amortize goodwill. We are required, however, to review goodwill for impairment annually or more frequently if events or changes in business circumstances indicate the book value of the goodwill may not be recoverable. In such circumstances, we record the impairment in loss on asset disposals and impairments in our combined consolidated statement of operations. We review the carrying value of goodwill for impairment as of November 1st of each year, or sooner if events or changes in circumstances indicate the carrying amount of a reporting unit may exceed fair value.
	We perform a qualitative analysis to determine whether it is more likely than not that the fair value of goodwill is less than its carrying value. If we determine it is more likely than not that the fair value of goodwill is less than its carrying amount, then a second step is performed to quantify the amount of goodwill impairment. If impairment is indicated, a goodwill impairment charge would be recorded to write the goodwill down to its implied fair value. In 2014, based on the qualitative analysis performed, we determined that no further impairment testing was necessary.
	We recorded $155 million of goodwill in connection with the Rockies Natural Gas Business Acquisition, of which $20 million was included in our Gathering segment, and $135 million included in our Processing segment. The goodwill recorded represents future organic growth opportunities, anticipated synergies and intangible assets that did not qualify for separate recognition. Goodwill of $9 million was recorded in conjunction with the acquisition of the Northwest Products Pipeline and the Boise and Pocatello, Idaho and Pasco, Washington refined products terminals (collectively, the “Northwest Products System”) on June 19, 2013 (the “Northwest Products System Acquisition”) from Chevron Pipe Line Company and Northwest Terminalling Company (collectively, “Chevron”) and is included in our Terminalling and Transportation segment.
	Investment in Unconsolidated Affiliates
	For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in investment in unconsolidated affiliates in our combined consolidated balance sheet and adjusted for our shares of the net earnings and losses of the investee and cash distributions, which are separately stated in our combined consolidated statement of operations and our combined consolidated statement of cash flows. Amounts recognized for earnings in excess of distributions of our equity method investments are included in the operating section of our combined consolidated statement of cash flows. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary.
	The principal unconsolidated affiliates and TLLP’s ownership percentage as of December 31, 2014 were Uintah Basin Field Services, L.L.C., in which we owned a 38% ownership interest, and Three Rivers Gathering, L.L.C., in which QEPM, our consolidated entity, owns a 50% ownership interest. Both are limited liability companies engaged in gathering and compressing natural gas.
	Asset Retirement Obligations
	An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. We record AROs at fair value in the period in which we have a legal obligation to incur this liability and can make a reasonable estimate of the fair value of the liability. Cost projections are based on engineering estimates, expected timing, probability of occurrence, experience gained from similar sites for which comparable projects have been completed and other closure costs using our credit-adjusted risk free rate. These estimates will be re-evaluated and adjusted as necessary as more information becomes available. When the liability is initially recorded, the cost is capitalized by increasing the book value of the related long-lived tangible asset. The liability is accreted through operating expenses to its estimated settlement value and the related capitalized cost is depreciated over the asset’s useful life. Settlement dates are estimated by considering our past practice, industry practice, management’s intent and estimated economic lives.
Estimates of the fair value for certain AROs may not be made as settlement dates (or range of dates) associated with these assets are not estimable because we intend to operate and maintain our assets as long as supply and demand for petroleum products exists. AROs primarily include regulatory or contractual obligations for the expected future demolition or removal of assets and related hazardous materials, if applicable, located at our leased facilities including the demolition or removal of tanks, pipelines or other equipment. AROs included in our consolidated balance sheets at December 31, 2014 were $30 million related to the preliminary purchase price allocation of the Rockies Natural Gas Business Acquisition and at December 31, 2013 they were immaterial.
Other Assets
We defer debt issuance costs related to our credit agreements and senior notes and amortize the costs over the terms of each instrument using the effective interest method. Amortization of deferred issuance costs, which is included in interest and financing costs, was $6 million and $2 million in the years ended December 31, 2014 and 2013, respectively. We reassess the carrying value of debt issuance costs when modifications are made to the related debt instruments.
Environmental Matters
We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and the extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Generally, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value, and environmental expenses are recorded primarily in operating expenses.
As of December 31, 2014, we carry a pollution liability insurance policy, which is subject to a $2 million deductible and a $50 million loss limit. We record insurance recoveries during the year when recovery is probable and can be reasonably estimated.
Legal Liabilities
In the ordinary course of business, we become party to lawsuits, administrative proceedings and governmental investigations. These matters may involve large or unspecified damages or penalties that may be sought from us and may require years to resolve. We record a liability related to a loss contingency attributable to such legal matters in other current liabilities or other noncurrent liabilities on our consolidated balance sheet, depending on the classification as current or noncurrent if we determine the loss to be both probable and estimable. The liability is recorded for an amount that is management’s best estimate of the loss, or when a best estimate cannot be made, the minimum loss amount of a range of possible outcomes.
Revenue Recognition
The Partnership generates revenue by charging fees for gathering crude oil and natural gas, for terminalling, transporting and storing crude oil and refined products and for processing natural gas and natural gas liquids. Revenues are recognized as crude oil, natural gas and refined products are transported through, delivered by, or stored in our pipelines, terminals and storage facility assets and transported by our trucking operations. Processing revenues are generated under long-term contracts with fee-based or keep-whole agreements. Under our fee-based agreements, the amount of fee-based revenue we generate is based on the volumes of natural gas that we process at our processing complexes.
The only historic revenues reflected in the financial statements of our Predecessor are amounts received from third-party use of our pipelines and terminals, and amounts received from Tesoro with respect to transportation regulated by the RCA on the refined products pipeline included in the West Coast Logistics Assets Acquisition. Tesoro was not charged fees for services rendered with respect to any terminalling, storage or pipeline transportation services, except as described above, prior to the Acquisitions from Tesoro, as the respective assets were operated as a component of Tesoro’s petroleum refining and marketing businesses.
The Partnership has several streams of revenue. Revenues are recognized as products are shipped through our pipelines and terminals. Billings to customers for obligations under their quarterly minimum revenue commitments (shortfall payments) are recorded as deferred revenue when they have the right to receive future services for these billings. Some of our fee-based agreements provide for fixed demand charges, which are recognized as revenue pursuant to the contract terms.
Revenue is recognized at the earlier of:
•	the customer receiving the services provided by these billings;
•	the expiration of the period in which the customer is contractually allowed to receive the services; or
•	the determination that future services will not be required.
Reimbursements
Pursuant to the Third Amended and Restated Omnibus Agreement (“Amended Omnibus Agreement”), Tesoro reimburses the Partnership for pressure testing, required repairs and maintenance identified as a result of the first inspection of certain pipeline and tank assets subsequent to the Acquisitions from Tesoro, as well as maintenance projects identified in the Amended Omnibus Agreement for which the costs were not known at the date of the Acquisitions from Tesoro. These amounts are recorded as a reduction to operating expense within the category labeled imbalance settlement gains and reimbursements from Tesoro during the period the costs are incurred and were $26 million, $4 million and $2 million for the years ended December 31, 2014, 2013 and 2012, respectively.
In addition, Tesoro reimburses the Partnership for capital projects identified in the Amended Omnibus Agreement. These amounts are recorded as a capital contribution by affiliate and were $26 million, $5 million and $6 million for the years ended December 31, 2014, 2013 and 2012, respectively.
Imbalances
We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporation and variances in meter readings and in other measurement methods. On our High Plains System, we retain 0.20% of the crude oil shipped on the High Plains Pipeline and we bear any crude oil volume losses in excess of that amount. Under the Second Amended and Restated Master Terminalling Service Agreement with Tesoro, we retain 0.25% of the refined products we handle at certain of our terminals for Tesoro, and bear any refined product volume losses in excess of that amount. The value of any crude oil or refined product imbalance settlements resulting from these tariffs or contractual provisions is determined by using the monthly average market prices for the applicable commodity, less a specified discount. The Partnership measures volume losses annually for the terminals and pipelines in the Northwest Products System. We retain 0.125% of the distillates and 0.25% of the other refined products we handle at our terminals on the Northwest Products System and we bear any refined product volume losses in excess of those amounts. The value of any refined product losses is determined by using the annual average market price for the applicable commodity. Any settlements under tariffs or contractual provisions where we bear any crude oil or refined product volume losses in excess of amounts specified reduce our operating and maintenance expenses in the period in which they are realized, to the extent they are within the loss allowance, and increase our operating and maintenance expenses in such period to the extent they exceed the loss allowance. For all of other terminals, and under our other commercial agreements with Tesoro, we have no obligation to measure volume losses and have no liability for physical losses.
The combined consolidated balance sheets also include offsetting natural gas imbalance receivables or payables resulting from differences in gas volumes received by customers and gas volumes delivered to interstate pipelines. Natural gas volumes owed to or by TLLP that are subject to tariffs are valued at market index prices, as of the balance sheet dates, and are subject to cash settlement procedures. Other natural gas volumes owed to or by TLLP are valued at the our weighted average cost of natural gas as of the balance sheet dates and are settled in-kind.
Unit-based Compensation
Our general partner provides unit-based compensation to officers and non-employee directors for the Partnership, which includes service and performance phantom unit awards. The fair value of our service phantom unit awards on the date of grant is equal to the market price of our common units. We estimate the grant date fair value of performance phantom unit awards using a Monte Carlo simulation at the inception of the award. We amortize the fair value over the vesting period using the straight-line method. The phantom unit awards are settled in TLLP common units. Expenses related to unit-based compensation are included in general and administrative expenses in our combined consolidated statements of operations. Total unit-based compensation expense totaled $2 million for the years ended December 31, 2014 and 2013, and $1 million for 2012. The Partnership had 337,342 units available for future grants under the long term incentive plan at December 31, 2014, assuming a 200% payout of the performance phantom unit awards currently outstanding.
Net Income per Limited Partner Unit
We use the two-class method when calculating the net income per unit applicable to limited partners, because we have more than one participating security. At December 31, 2014, our participating securities consist of common units, general partner units and incentive distribution rights (“IDRs”). Net income attributable to the Partnership is allocated between the limited and general partners in accordance with our partnership agreement. We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period.
Diluted net income per unit includes the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. Basic and diluted net income per unit applicable to subordinated limited partners was historically the same, as there were no potentially dilutive subordinated units outstanding. Distributions less than or greater than earnings are allocated in accordance with our partnership agreement.
Income Taxes
We are a limited partnership and are not subject to federal or state income taxes. Accordingly, our taxable income or loss is included in the federal and state income tax returns of our partners. Taxable income may vary substantially from income or loss reported for financial reporting purposes due to differences in the tax bases and financial reporting bases of assets and liabilities, and due to certain taxable income allocation requirements of the partnership agreement. We are unable to readily determine the net difference in the bases of our assets and liabilities for financial and tax reporting purposes because individual unitholders have different investment bases depending upon the timing and price of acquisition of their partnership units.
U.S. GAAP requires management to evaluate uncertain tax positions taken by the Partnership. The financial statement effects of a tax position are recognized when the position is more likely than not, based on the technical merits, to be sustained upon examination by the Internal Revenue Service. Management has analyzed the tax positions taken by the Partnership and has concluded that there are no uncertain positions taken or expected to be taken. The Partnership is subject to routine audits by taxing jurisdictions; however, there are currently no audits for any tax periods in progress.
Noncontrolling Interests
Noncontrolling interests represent third-party ownership in the net assets of our consolidated subsidiaries and are presented as a component of equity and net income. Changes in TLLP’s ownership interest in subsidiaries that do not result in deconsolidation are recognized in equity. On December 2, 2014, we completed the Rockies Natural Gas Business Acquisition, which included controlling interest in QEPM and Rendezvous Gas. QEPM’s results, which include Rendezvous Gas, are consolidated into TLLP as it is a majority-owned and controlled subsidiary and the portion not owned by TLLP is reflected as noncontrolling interest. Noncontrolling interest was initially valued primarily based on the market value of public common units outstanding at the acquisition date for QEPM as well as the respective third-party ownership of future cash flows for Rendezvous Gas, based on estimated future volumes and estimated earnings.
New Accounting Standards
Revenue Recognition
The Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) in May 2014 providing accounting guidance for all revenue arising from contracts to provide goods or services to customers. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2016, and early adoption is not permitted. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the ASU to determine the method of adoption and the impact this ASU may have on our financial statements and related disclosures.
Pushdown Accounting
The Securities and Exchange Commission released a Staff Accounting Bulletin (“SAB”) in November 2014, overturning portions of the interpretive guidance regarding pushdown accounting. Effective November 18, 2014, the new bulletin aligns the existing guidance to the ASU issued by the FASB in October 2014. Under the new guidance, pushdown accounting can be applied in the separate financial statements of the acquired entity upon completion of the acquisition or in a subsequent period. This impacts the stand-alone financial statements of the subsidiary, but does not alter the existing reporting requirements for the parent company to record the acquired assets, liabilities, and non-controlling interests in consolidated financial statements. If pushdown accounting is not applied in the reporting period in which the change-in-control event occurs, an acquired entity will have the option to elect to apply pushdown accounting in a subsequent reporting period. If pushdown accounting is applied, that election is irrevocable. The SEC responded by rescinding its guidance on pushdown accounting, which had required registrants to apply pushdown accounting in certain circumstances. With regard to the Rockies Natural Gas Business Acquisition, we did not elect to apply pushdown accounting to certain acquired entities.
Consolidation
The FASB issued an ASU in February 2015 amending current consolidation guidance including changes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. We are evaluating the new ASU to determine whether any of our current conclusions with respect to consolidation of variable interest or other entities will change under the new guidance. At this time, we cannot estimate the impact of this ASU on our financial statements and related disclosures.

Acquisitions_Notes

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Acquisitions	ACQUISITIONS
	Rockies Natural Gas Business Acquisition
	On October 19, 2014, the Partnership entered into a Membership Interest Purchase Agreement (the “MIPA”) with QEP Field Services Company (“QEPFSC”), a wholly-owned subsidiary of QEP Resources, Inc. (“QEP Resources”). Pursuant to the MIPA, the Partnership agreed to purchase from QEPFSC all of the limited liability company interests of QEPFS, a wholly-owned subsidiary of QEPFSC, including environmental obligations and existing legal obligations. QEPFS is the direct or indirect owner of assets related to, and entities engaged in, natural gas gathering, transportation and processing in or around the Green River Basin located in Wyoming and Colorado, the Uinta Basin located in eastern Utah (collectively, the “Rockies Region”), and the portion of the Williston Basin located in North Dakota. QEPFS also holds an approximate 55.8% limited partner interest in QEPM and 100% of the limited liability company interests of QEP Midstream Partners GP, LLC (“QEPM GP”), which itself holds a 2% general partner interest and all of the IDRs in QEPM.
	On December 2, 2014, the Partnership and QEPFS closed the acquisition as contemplated by the MIPA for an aggregate purchase price of approximately $2.5 billion in cash, which includes approximately $230 million to refinance QEPM’s debt. The purchase price includes adjustments for working capital and remains subject to post-closing adjustments. The acquired assets include natural gas and crude oil gathering and transmission pipelines within the Rockies Region and North Dakota, which are reported in our Gathering segment. Additionally, the acquired assets include four natural gas processing complexes and one fractionation facility, the operations of which are reported in our Processing segment (collectively, the “QEPFS Assets”).
	On October 24, 2014, in connection with the Rockies Natural Gas Business Acquisition, we closed a registered public offering of 23 million common units, representing limited partner interests in TLLP (the “October 2014 Equity Offering”) to raise $1.3 billion. Additionally, on October 29, 2014, we completed a private offering of $1.3 billion aggregate principal amount of senior notes (the “Senior Notes Offering”) pursuant to a private placement transaction conducted under Rule 144A and Regulation S of the Securities Act of 1933, as amended. We used the proceeds from the October 2014 Equity Offering and Senior Notes Offering to repay amounts outstanding under our existing revolving credit facility with the remainder, including amounts borrowed under the amended revolving credit facility (the “Revolving Credit Facility”), to fund the Rockies Natural Gas Business Acquisition and payment of related fees and expenses. Also we paid $16 million of fees for an alternative financing arrangement which would have been used to fund borrowings in the event we were not able to finance the Rockies Natural Gas Business Acquisition with equity or debt offerings. Refer to Note 10 for further information on the Senior Notes Offering and expansion of our Revolving Credit Facility, and Note 12 for further information on the October 2014 Equity Offering.
	The acquisition aligns with TLLP’s strategies to focus on stable fee-based business, optimize existing assets, pursue organic growth and grow through acquisitions. The combined system provides a platform for growth across the crude oil and natural gas basin near existing TLLP assets. The Rockies Natural Gas Business Acquisition makes TLLP a full-service, integrated logistics company. Natural gas gathering and processing is an extension of our existing business allowing us to offer integrated crude oil and natural gas services to producers, particularly in the Bakken region.
	Commercial Agreements
	All third-party agreements and any contracts between QEP Resources and other QEP Resources affiliates were assigned to TLLP for the QEPFS Assets.
	Financial Information
	We accounted for the Rockies Natural Gas Business Acquisition using the acquisition method of accounting, which requires, among other things, that assets acquired at their fair values and liabilities assumed be recognized on the balance sheet as of the acquisition date. The purchase price allocation for the Rockies Natural Gas Business Acquisition is preliminary and has been allocated based on estimated fair values of the assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent valuation and the assessment of asset retirement obligations and other information as it becomes available to us. Additionally, certain working capital amounts will be updated upon receipt of the final closing statement. The purchase price allocation adjustments can be made through the end of TLLP’s measurement period, which is not to exceed one year from the acquisition date.
	Included in our preliminary purchase price allocation are values for all of the assets acquired in the Rockies Natural Gas Business Acquisition, including $57 million specifically identified for our interest in QEPFS’ joint ventures and $1.3 billion specifically identified for QEPM, of which approximately $432 million represents noncontrolling interest. Also included in the preliminary purchase price allocation is $30 million related to AROs. Certain valuations and other studies have yet to commence or progress to a state where there is sufficient information for a definitive measurement, including estimates for property, plant and equipment values, AROs and values for intangible assets.
	The table below presents the preliminary acquisition date purchase price allocation (in millions):
	Cash	$	31
	Accounts receivable	117
	Prepayments and other	7
	Property, plant and equipment	1,735
	Intangibles	976
	Goodwill	155
	Investment in unconsolidated affiliates	57
	Other noncurrent assets	22
	Accounts payable	(81		)
	Other current liabilities	(47		)
	Other noncurrent liabilities	(30		)
	Noncontrolling interest	(432		)
	Total purchase price	$	2,510
	The following unaudited pro forma condensed combined consolidated results of operations for the years ended December 31, 2014 and 2013 are presented as if the Rockies Natural Gas Business Acquisition had been completed on January 1, 2013. The amounts presented below have not been adjusted to include the pro forma results of the Northwest Products System for the year ended December 31, 2013. The unaudited pro forma financial information below reflects adjustments to exclude $8 million of nonrecurring accelerated amortization of certain QEPFS deferred issuance costs and $33 million of transaction costs as a result of the Rockies Natural Gas Business Acquisition for the year ended December 31, 2014.
		Year Ended December 31,
		2014				2013
		(Dollars in millions, except per unit amounts)
	Revenues	$	936			$	689
	Net income	126				72
	Net income attributable to partners	106				105
	Net income per limited partner unit:
	Common - basic and diluted	$	0.77			$	1.23
	Subordinated - basic and diluted	$	1.13			$	1.39
	2014 Acquisition from Tesoro
	On June 23, 2014, we entered into an agreement with Tesoro to acquire certain terminalling and pipeline assets owned by Tesoro and two of its subsidiaries, Tesoro Refining & Marketing Company LLC (“TRMC”) and Tesoro Alaska Company LLC. Under the terms of the agreement, TLLP acquired the West Coast Logistics Assets for total consideration of $270 million. The operations of the West Coast Logistics Assets are included in our Terminalling and Transportation segment.
	On July 1, 2014, we closed on the purchase of the first portion of the West Coast Logistics Assets in exchange for consideration of $241 million, comprised of approximately $214 million in cash, financed with borrowings on our Revolving Credit Facility, the issuance of equity to Tesoro with a fair value of $27 million. The equity was comprised of 370,843 common units and 8,856 general partner units.
	TLLP completed the second portion of this acquisition on September 30, 2014, upon receiving the required regulatory approval from the RCA, for cash consideration of $29 million, which was financed with borrowings on our Revolving Credit Facility. The assets consist of all of Tesoro’s membership interests in Tesoro Alaska Pipeline Company LLC, a wholly-owned subsidiary of Tesoro, which owns a refined products pipeline connecting Tesoro’s Kenai refinery to Anchorage, Alaska.
	The following are the results of the West Coast Logistics Assets operations, prior to the West Coast Logistics Assets respective acquisitions’ dates on July 1, 2014 and September 30, 2014, for the years ended December 31, 2014, 2013 and 2012. The results of the West Coast Logistics Assets, subsequent to each respective acquisition date, have been included in TLLP’s consolidated results.
			Year Ended December 31,
			2014				2013			2012
			(in millions)
	Revenues		$	6			$	8		$	7
	Total costs and expenses		(10		)		(15		)	(15		)
	Net loss		$	(4	)		$	(7	)	$	(8	)
	Tesoro retained any current assets and current liabilities related to the West Coast Logistics Assets as of the dates of acquisition. The only historical balance sheet item that transferred to the Partnership in the acquisition was property, plant and equipment, which was recorded by TLLP at historical cost of $29 million.
	We entered into throughput, use and storage agreements with Tesoro for the marketing and storage terminal facilities in connection with the closing of this transaction. The terminalling agreements include a minimum throughput commitment and the storage agreement requires Tesoro to pay a monthly storage services fee. In addition, Tesoro committed to a minimum volume throughput on the refined products pipeline. See Note 3 for additional information regarding commercial agreements and amendments to other agreements with related parties in connection with the acquisition.
	Northwest Products System Acquisition
	On June 19, 2013, we purchased the Northwest Products System for a total purchase price of $355 million from Chevron. The amount paid at closing was reduced by an advance deposit of $40 million that was paid at the time the asset purchase and sale agreements were executed in December 2012. The Partnership financed the acquisition with proceeds from its registered public offering of common units on January 14, 2013 (the “January 2013 Equity Offering”). The Northwest Products System consists of a products pipeline system running from Salt Lake City, Utah to Spokane, Washington (the “Northwest Products Pipeline”) and three refined products terminals in Boise and Pocatello, Idaho and Pasco, Washington. During the second quarter of 2014, we finalized the assessments of fair values related to the acquisition. The purchase price allocation for the Northwest Products System acquisition is final and is based on estimated fair values of the assets acquired and liabilities assumed at the acquisition date. There were no material purchase price allocation adjustments during 2014.
	Pursuant to the regulatory review process associated with the Northwest Products System acquisition, we agreed to divest our legacy refined products terminal in Boise, Idaho (“Boise Terminal”). We completed the sale of the Boise Terminal on March 18, 2014. Net proceeds from the sale were $10 million, which resulted in a gain of $5 million recorded for the year ended December 31, 2014. The carrying value of the Boise Terminal is reflected in other current assets in our consolidated balance sheet as of December 31, 2013.
	The following unaudited pro forma condensed combined consolidated results of operations for the years ended December 31, 2013 and 2012 are presented as if the Northwest Products System acquisition had been completed on January 1, 2012. The amounts presented below have not been adjusted to include the pro forma results of the Rockies Natural Gas Business Acquisition for the year ended December 31, 2013.
			Year Ended December 31,
			2013				2012
			(Dollars in millions, except per unit amounts)
	Revenues		$	327			$	207
	Net income		46				67
	Net income attributable to partners		84				68
	Net income per limited partner unit:
	Common - basic		$	1.56			$	1.59
	Common - diluted		$	1.56			$	1.58
	Subordinated - basic and diluted		$	1.46			$	1.49
	Post-Acquisition Financial Information
	The following amounts associated with the West Coast Logistics Asset Acquisition and the Rockies Natural Gas Business Acquisition, subsequent to each respective acquisition date, are included in the combined consolidated statements of operations of TLLP (in millions):
	Year Ended
	31-Dec-14
West Coast Logistics Acquisition:
Total revenues	$	19
Net income attributable to partners	13
Costs associated with the acquisition (a)	2
Rockies Natural Gas Business Acquisition:
Total revenues	$	36
Net income attributable to partners	7
Costs associated with the acquisition (a)	33
____________
(a)	Costs associated with the acquisitions are included in the general and administrative expenses and interest and financing costs in our combined consolidated statements of operations.

RelatedParty_Transactions_Note

Related-Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related-Party Transactions	RELATED-PARTY TRANSACTIONS
	Commercial Agreements
	The Partnership has various long-term, fee-based commercial agreements with Tesoro under which we provide pipeline transportation, trucking, terminal distribution and storage services to Tesoro, and Tesoro commits to provide us with minimum monthly throughput volumes of crude oil and refined products.
	If, in any calendar month, Tesoro fails to meet its minimum volume commitments under these agreements, it will be required to pay us a shortfall payment. These shortfall payments may be applied as a credit against any amounts due above their minimum volume commitments for up to three months after the shortfall occurs.
	We believe the terms and conditions under these agreements, as well as our other agreements with Tesoro described below, are generally no less favorable to either party than those that could have been negotiated with unaffiliated parties with respect to similar services. Each of these agreements has fees that are indexed annually for inflation, with the exception of the Second Amended and Restated Trucking Transportation Services Agreement (High Plains System), which allows for a quarterly rate adjustment based on a comparison of competitive rates. These commercial agreements with Tesoro include:
		Initiation Date		Term	Renewals		Termination Provisions
							Refinery Shutdown Notice Period (a)	Force Majeure
	Transportation Services Agreement (High Plains System)	Apr-11		10 years	2 x 5 years		12 months	TLLP can declare (unilateral)
	Second Amended and Restated Trucking Transportation Services Agreement (High Plains System)	Apr-11		5 years	1 x 5 years
	Second Amended and Restated Master Terminalling Services Agreement	Apr-11		10 years	2 x 5 years
	Amended Salt Lake City Storage and Transportation Services Agreement	Apr-11		10 years	2 x 5 years
	Amorco Terminal Use and Throughput Agreement (Martinez Marine)	Apr-12		10 years	2 x 5 years
	Amended Anacortes Track Use and Throughput Agreement	Nov-12		10 years	2 x 5 years		N/A
	Carson Storage Services Agreement	Jun-13		10 years	2 x 5 years
	Amended and Restated Master Terminalling Services Agreement - Southern California	Jun-13		10 years	2 x 5 years
	Long Beach Storage Services Agreement	Dec-13		10 years	2 x 5 years
	Transportation Services Agreement (SoCal Pipelines)	Dec-13		10 years	2 x 5 years
	Carson Coke Handling Services Agreement	Dec-13		10 years	2 x 5 years
	Amended and Restated Long Beach Berth Access Use and Throughput Agreement (b)	Dec-13		10 years	2 x 5 years
	Long Beach Berth Throughput Agreement (b)	Dec-13		10 years	2 x 5 years
	Long Beach Pipeline Throughput Agreement	Dec-13		10 years	2 x 5 years
	Terminalling Services Agreement - Nikiski	Jul-14		10 years	2 x 5 years
	Terminalling Services Agreement - Anacortes	Jul-14		10 years	2 x 5 years
	Terminalling Services Agreement - Martinez	Jul-14		10 years	2 x 5 years
	Storage Services Agreement - Anacortes	Jul-14		10 years	2 x 5 years
	Martinez Dedicated LPG Storage Agreement	Jul-14		10 years	2 x 5 years
	Tesoro Alaska Pipeline Throughput Agreement	Sep-14		10 years	2 x 5 years
	____________
	(a)	Fixed minimum volumes remain in effect during routine turnarounds.
	(b)	Agreement gives Tesoro the option to renew for two five-year terms, or Tesoro may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement.
	We charge fixed fees based on the total storage capacity of our tanks under several of our agreements with Tesoro. We recognized approximately $83 million, $28 million and $1 million of revenue under these agreements where TLLP was considered to be the lessor during the years ended December 31, 2014, 2013 and 2012, respectively. Committed minimum payments for each of the five years following December 31, 2014 are expected to be approximately $99 million.
	Third Amended and Restated Omnibus Agreement
	The Partnership entered into an omnibus agreement with Tesoro at the closing of the Initial Offering. The agreement has been amended for each of the Acquisitions from Tesoro and was most recently amended on July 1, 2014 in connection with the West Coast Logistics Assets Acquisition. The amendment increased the annual administrative fee payable by the Partnership to Tesoro under the Amended Omnibus Agreement to approximately $6 million as of December 31, 2014 for the provision of various general and administrative services, including executive management, legal, accounting, treasury, human resources, health, safety and environmental, information technology, certain insurance coverage, administration and other corporate services. In addition, the Partnership reimburses Tesoro for all other direct or allocated costs and expenses incurred by Tesoro or its affiliates on its behalf.
	Under the Amended Omnibus Agreement, Tesoro indemnifies us for certain matters, including environmental, title and tax matters associated with the ownership of our assets at or before the closing of the Initial Offering and the subsequent Acquisitions from Tesoro, with the exception of the Los Angeles Terminal Assets Acquisition and Los Angeles Logistics Assets Acquisition, which are covered by the Carson Assets Indemnity Agreement. With respect to assets that we acquired from Tesoro, excluding the Los Angeles Terminal Assets and the Los Angeles Logistics Assets, indemnification for unknown environmental and title liabilities is limited to pre-closing conditions identified prior to the earlier of the date that Tesoro no longer controls our general partner or five years after the date of closing. Under the Amended Omnibus Agreement, the aggregate annual deductible for each type of liability (unknown environmental liabilities or title matters) is approximately $1 million, as of December 31, 2014, before we are entitled to indemnification in any calendar year in consideration of the Initial Assets and all subsequent Acquisitions from Tesoro, with the exception of the Los Angeles Terminal Assets Acquisition and the Los Angeles Logistics Assets Acquisition. In addition, with respect to the assets that we acquired from Tesoro, we have agreed to indemnify Tesoro for events and conditions associated with the ownership or operation of our assets that occur after the closing of the Initial Offering, and the subsequent Acquisitions from Tesoro, and for environmental liabilities related to our assets to the extent Tesoro is not required to indemnify us for such liabilities. See Note 11 for additional information regarding the Amended Omnibus Agreement.
	Anacortes Truck Rack Construction Agreement
	The Partnership entered into a construction service agreement (the “Construction Agreement”) with Tesoro, effective July 1, 2014. Under the Construction Agreement, the Partnership will pay Tesoro a fixed fee of $23 million for the construction of a new refined products truck rack at the site of Partnership’s Anacortes terminal, which was acquired as part of the West Coast Logistics Assets Acquisition.
	First Amended and Restated Omnibus Agreement of QEPM
	QEPM amended and restated its omnibus agreement upon closing of the Rockies Natural Gas Business Acquisition on December 2, 2014 (“QEPM Omnibus Agreement”) to transfer all previous rights and obligations to TLLP and TLGP, as outlined in the QEPM Omnibus Agreement. Under the QEPM Omnibus Agreement, TLLP indemnifies QEPM for certain matters, including legal, environmental, title and tax matters associated with the ownership of the acquired assets at or before the closing of QEPM’s initial offering on August 14, 2013. Under the MIPA, QEP Resources retained responsibility for the title and tax matters prior to December 2, 2014.
	Carson Assets Indemnity Agreement
	The Partnership entered into the Carson Assets Indemnity Agreement with Tesoro at the closing of the Los Angeles Logistics Assets Acquisition effective December 6, 2013, establishing indemnification for certain matters including known and unknown environmental liabilities arising out of the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the respective acquisition dates.
	Under the Carson Assets Indemnity Agreement, Tesoro retained responsibility for remediation of known environmental liabilities due to the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the respective acquisition dates, and has indemnified the Partnership for any losses incurred by the Partnership arising out of those remediation obligations. The indemnification for unknown pre-Closing remediation liabilities is limited to five years. However, with respect to Terminal 2 at the Long Beach marine terminal, which was included in the Los Angeles Logistics Assets Acquisition, the indemnification for unknown pre-closing remediation liabilities is limited to ten years. Indemnification of the Los Angeles Terminal Assets’ and the Los Angeles Logistics Assets’ environmental liabilities is not subject to a deductible. See Note 11 for additional information regarding the Carson Assets Indemnity Agreement.
	Keep-Whole Commodity Fee Agreement
	Effective December 2, 2014, following the completion of the Rockies Natural Gas Business Acquisition, we began processing gas for certain producers under “keep-whole” processing agreements. Under a keep-whole agreement, a producer transfers title to the NGLs produced during gas processing, and the processor, in exchange, delivers to the producer natural gas with a BTU content equivalent to the NGLs removed. The operating margin for these contracts is determined by the spread between NGL sales prices and the price paid to purchase the replacement natural gas (“Shrink Gas”). TLLP entered into a five-year agreement with Tesoro, which transfers the commodity risk exposure associated with these keep-whole processing agreements from TLLP to Tesoro (the “Keep-Whole Commodity Agreement”). Under the Keep-Whole Commodity Agreement with Tesoro, Tesoro pays TLLP a processing fee for NGLs related to keep-whole agreements and delivers Shrink Gas to the producers on behalf of TLLP. TLLP pays Tesoro a marketing fee in exchange for assuming the commodity risk.
	Terms and pricing under this agreement are revised each year. The Keep-Whole Commodity Agreement minimizes the impact of commodity price movement during the annual period subsequent to renegotiation of terms and pricing each year. However, the annual fee we charge Tesoro could be impacted as a result of any changes in the spread between NGL sales prices and the price of natural gas.
	Secondment and Logistics Services Agreement
	In connection with the acquisition of the West Coast Logistics Assets on July 1, 2014, we terminated our Operational Services Agreement and entered into the Secondment and Logistics Services Agreement (the “Secondment Agreement”) with Tesoro to govern the provision of seconded employees to or from Tesoro, the Partnership, and its subsidiaries, as applicable. The Secondment Agreement also governs the use of certain facilities of the parties by the various entities. The services to be provided by such seconded employees, along with the fees for such services, will be provided on the service schedules attached to the Secondment Agreement. Specialized services and the use of various facilities, along with the fees for such services, will be provided for in service orders to be executed by parties requesting and receiving the service. All fees to be paid pursuant to the Secondment Agreement are indexed for inflation. The total annual fee to the Partnership under the Secondment Agreement is approximately $5 million as of December 31, 2014.
	On December 2, 2014, the General Partner and certain of its indirect subsidiaries entered into Amendment No. 1 to the Secondment Agreement (the “Secondment Agreement Amendment”) with Tesoro and including QEPFS, QEPM GP, QEPM and certain of its subsidiaries, pursuant to which these entities joined as parties to the Secondment Agreement dated July 1, 2014, to provide for the secondment of employees to or from those entities and Tesoro.
	Predecessors’ Affiliate Transactions
	Related-party transactions of our Predecessors were settled through equity.
	Summary of Transactions
	A summary of revenue and expense transactions with Tesoro, including expenses directly charged and allocated to our Predecessors, are as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Revenues	$	497		$	273		$	150
	Operating and maintenance expenses	77			71			28
	Imbalance settlement gains and reimbursements from Tesoro (a)	(43		)	(12		)	(12		)
	General and administrative expenses	39			20			13
	____________
	(a) Includes imbalance settlement gains of $17 million, $8 million and $10 million in the years ended December 31, 2014, 2013 and 2012, respectively. Also includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement of $26 million, $4 million and $2 million in the years ended December 31, 2014, 2013 and 2012, respectively.
	In accordance with our partnership agreement, our limited and general partner interests are entitled to receive quarterly distributions of available cash. We paid quarterly cash distributions to Tesoro, including IDRs, totaling $87 million, $44 million and $27 million in 2014, 2013 and 2012, respectively. On January 22, 2015, we declared a quarterly cash distribution of $0.6675 per unit based on the results of the fourth quarter of 2014, of which $35 million was paid to Tesoro on February 13, 2015.

Net_Income_Per_Unit_Notes

Net Income Per Unit (Notes)	12 Months Ended
	Dec. 31, 2014
Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax [Abstract]
Net Income Per Unit	NET INCOME PER UNIT
	The calculation of net income per unit is as follows (in millions, except unit and per unit amounts):
		Year Ended December 31,
		2014			2013			2012
	Net income attributable to partners	$	99		$	80		$	57
	Special allocation of net income (“Special Allocation”) (a)	7			—			—
	Net income attributable to partners, excluding Special Allocation	106			80			57
	General partner’s distributions (including IDRs) (b)	(46		)	(13		)	(3		)
	Limited partners’ distributions on common units	(157		)	(71		)	(36		)
	Limited partner’s distributions on subordinated units (c)	(14		)	(32		)	(26		)
	Distributions greater than earnings	$	(111	)	$	(36	)	$	(8	)
	General partner’s earnings:
	Distributions (including IDRs) (b)	$	46		$	13		$	3
	Allocation of distributions greater than earnings	(3		)	(1		)	—
	Total general partner’s earnings	$	43		$	12		$	3
	Limited partners’ earnings on common units:
	Distributions	$	157		$	71		$	36
	Special Allocation (a)	(7		)	—			—
	Allocation of distributions greater than earnings	(98		)	(23		)	(4		)
	Total limited partners’ earnings on common units	$	52		$	48		$	32
	Limited partner’s earnings on subordinated units (c):
	Distributions	$	14		$	32		$	26
	Allocation of distributions greater than earnings	(10		)	(12		)	(4		)
	Total limited partner’s earnings on subordinated units	$	4		$	20		$	22
	Weighted average limited partner units outstanding:
	Common units - basic	54,203,508			31,545,935			16,614,668
	Common unit equivalents	45,908			72,499			94,282
	Common units - diluted	54,249,416			31,618,434			16,708,950
	Subordinated units - basic and diluted (c)	5,642,220			15,254,890			15,254,890
	Net income per limited partner unit:
	Common - basic	$	0.96		$	1.48		$	1.9
	Common - diluted	$	0.96		$	1.47		$	1.89
	Subordinated - basic and diluted	$	0.62		$	1.35		$	1.47
	____________
	(a)	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to TLGP common unitholders for the premium paid in connection with the redemption of the senior notes due 2020.
	(b)	General partner’s distributions (including IDRs) consist of the 2% general partner interest and IDRs, which entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. See Note 12 for further discussion related to IDRs.
	(c)	On May 16, 2014, the 15,254,890 subordinated units were converted into common units on a one-for-one basis and thereafter participate on terms equal with all other common units in distributions of available cash. Distributions and the Partnership’s net income were allocated to the subordinated units through May 15, 2014.
	See Note 1 for the method and policies related to the calculation of net income per unit. Following payment of the cash distribution for the first quarter of 2014 and the attainment of necessary approvals, the requirements for the conversion of all subordinated units were satisfied under the partnership agreement. The Partnership’s net income was allocated to the general partner and the limited partners, including the holders of the subordinated units through May 15, 2014, in accordance with our partnership agreement. The conversion did not impact the amount of the cash distribution paid or the total number of the Partnership’s outstanding units representing limited partner interests.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment, at cost, is as follows (in millions):
		December 31,			December 31,
		2014			2013
	Gathering	$	1,507		$	172
	Processing	539			—
	Terminalling and Transportation	1,478			1,397
	Other	27			—
	Property, Plant and Equipment	3,551			1,569
	Accumulated depreciation	(245		)	(171		)
	Net Property, Plant and Equipment	$	3,306		$	1,398
	Capitalized interest totaled $6 million, $2 million and $1 million for the years ended December 31, 2014, 2013, and 2012, respectively. Depreciation expense totaled $75 million, $45 million and $15 million for the years ended December 31, 2014, 2013 and 2012, respectively.

Investment_in_Unconsolidated_A

Investment in Unconsolidated Affiliates Investment in Unconsolidated Affiliates (Notes)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Affiliates	INVESTMENT IN UNCONSOLIDATED AFFILIATES
	We do not consolidate any part of the assets or liabilities of our equity investees. Our share of net income or loss will increase or decrease, as applicable, the carrying value of our investments in unconsolidated affiliates.
	For the Uintah Basin Field Services, L.L.C. (“UBFS”) and Three Rivers Gathering, L.L.C. (“TRG”) joint ventures, we determined that these entities do not represent variable interest entities and consolidation was not required. We have the ability to exercise influence over each of these joint ventures through our participation in the management committees, which make all significant decisions. However, since all significant decisions require the consent of the other investor(s) without regard to economic interest, we have determined that we have joint control and have applied the equity method of accounting.
	Uintah Basin Field Services, L.L.C.
	UBFS, in which we acquired a 38% interest in connection with the Rockies Natural Gas Business Acquisition, is a joint venture between us, Discovery Natural Resources LLC (“Discovery”), and Ute Energy Midstream Holdings, LLC (“Ute Energy”) that was originally formed to allow the partners to jointly develop the natural gas gathering infrastructure within a defined area of mutual interest located in the southeastern Uinta Basin. The gathering system is supported by long-term, fee-based gas gathering agreements that contain firm throughput commitments, which generate fees whether or not the capacity is used, and is operated by us. Our investment in UBFS totaled $18 million at December 31, 2014. The carrying amount of our investment in UBFS exceeded the underlying equity in net assets by $7 million at December 31, 2014.The basis difference is being amortized over the useful life of the underlying fixed assets.
	Three Rivers Gathering, L.L.C.
	We own a 50% interest in TRG located in the southeastern Uinta Basin. TRG was formed with Ute Energy to transport natural gas gathered by UBFS and other third-party volumes to gas processing facilities. The Three Rivers Gathering system is primarily supported by long-term, fee-based gas gathering agreements with minimum volume commitments. Our investment in TRG totaled $39 million at December 31, 2014. The carrying amount of our investment in TRG exceeded the underlying equity in net assets by $15 million at December 31, 2014. The basis difference is being amortized over the useful life of the underlying fixed assets.

Other_Current_Liabilities_Note

Other Current Liabilities (Notes)	12 Months Ended
	Dec. 31, 2014
Other Liabilities, Current [Abstract]
Other Current Liabilities	OTHER CURRENT LIABILITIES
	Other current liabilities are as follows (in millions):
		December 31,		December 31,
		2014		2013
	Legal	$	21	$	—
	Accrued environmental liabilities	13		20
	Other	45		10
	Total Other Current Liabilities	$	79	$	30

Benefit_Plans_Notes

Benefit Plans (Notes)	12 Months Ended
	Dec. 31, 2014
Benefit Plans [Abstract]
Benefit Plans	BENEFIT PLANS
	Employees supporting our operations participate in the benefit plans and the employee thrift plan of Tesoro. Tesoro allocates expense to the Partnership for costs associated with the benefit plans based on the salaries of Tesoro’s employees that provide services to the Partnership as a percentage of total Tesoro salaries. The Predecessors were allocated expenses for costs associated with the benefit plans primarily based on the percentage of the Predecessors’ allocated salaries compared to Tesoro’s total salaries. Our portion of our Sponsor’s employee benefit plan expenses was $13 million, $9 million and $4 million for the years ended December 31, 2014, 2013 and 2012, respectively. These employee benefit plan expenses and the related payroll costs are included in operating and maintenance expenses and general and administrative expenses in our combined consolidated statements of operations and include amounts allocated to the Predecessors.

Major_Customer_and_Concentrati

Major Customer and Concentrations of Credit Risk (Notes)	12 Months Ended
	Dec. 31, 2014
Major Customer and Concentrations of Credit Risk [Abstract]
Major Customer and Concentrations of Credit Risk	MAJOR CUSTOMER AND CONCENTRATIONS OF CREDIT RISK
	Tesoro accounted for 83%, 87% and 91% of our total revenues in the years ended December 31, 2014, 2013 and 2012, respectively. No revenue was recorded for the Predecessors for transactions with Tesoro in the Terminalling and Transportation segment, except for the RCA tariffs charged to Tesoro on the refined products pipeline included in the acquisition of the West Coast Logistics Assets.

Debt_Notes

Debt (Notes)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	DEBT
	Our total debt at December 31, 2014 and 2013 was comprised of the following (in millions):
	Debt, including current maturities:	December 31,				December 31,
		2014				2013
	Revolving Credit Facility	$	260			$	—
	5.500% Senior Notes due 2019	500				—
	5.875% Senior Notes due 2020 (a)	475				606
	6.125% Senior Notes due 2021	550				550
	6.250% Senior Notes due 2022	800				—
	Capital lease obligations	8				8
	Total Debt	2,593				1,164
	Current maturities	—				—
	Debt, less current maturities	$	2,593			$	1,164
	____________
	(a)	Includes an unamortized premium of $5 million and $6 million as of December 31, 2014 and 2013, respectively.
	The aggregate maturities of our debt, including the principal payments of our capital lease obligations, for each of the five years following December 31, 2014 are: immaterial in 2015 and 2016, $1 million in 2017, $1 million in 2018 and $761 million in 2019.
	Revolving Credit Facility
	We amended our Revolving Credit Facility on December 2, 2014, in connection with the Rockies Natural Gas Business Acquisition. As of December 31, 2014, our Revolving Credit Facility provided for total loan availability of $900 million, and we are allowed to request that the loan availability be increased up to an aggregate of $1.5 billion, subject to receiving increased commitments from the lenders. Our Revolving Credit Facility is non-recourse to Tesoro, except for TLGP, and is guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas, and secured by substantially all of our assets. Borrowings are available under the Revolving Credit Facility up to the total loan availability of the facility. We had $260 million borrowings outstanding under the Revolving Credit Facility, resulting in a total unused loan availability of $640 million or 71% of the borrowing capacity as of December 31, 2014. The weighted average interest rate for borrowings under our Revolving Credit Facility was 2.92% at December 31, 2014. The Revolving Credit Facility is scheduled to mature on December 2, 2019.
	As of December 31, 2014, our Revolving Credit Facility was subject to the following:
	Credit Facility		30 day Eurodollar (LIBOR) Rate		Eurodollar Margin		Base Rate	Base Rate Margin	Commitment Fee
									(unused portion)
	Revolving Credit Facility (b)		0.17%		2.75%		3.25%	1.75%	0.50%
	____________
	(b) We have the option to elect if the borrowings will bear interest at either, a base rate plus the base rate margin or a Eurodollar rate, for the applicable period, plus the Eurodollar margin at the time of the borrowing. The applicable margin varies based upon a certain leverage ratio, as defined by the Revolving Credit Facility. We also incur commitment fees for the unused portion of the Revolving Credit Facility at an annual rate. Letters of credit outstanding under the Revolving Credit Facility incur fees at the Eurodollar margin rate.
	Senior Notes due 2019 and 2022
	Effective October 29, 2014, we completed a private offering of $1.3 billion aggregate principal amount of senior notes pursuant to a private placement transaction conducted under Rule 144A and Regulation S of the Securities Act of 1933, as amended. Offering costs related to the Senior Notes Offering were $19 million. The Senior Notes Offering consisted of $500 million of 5.50% senior notes due in 2019 (the “2019 Senior Notes”) and $800 million of 6.25% senior notes due in 2022 (the “2022 Senior Notes”). The proceeds from the 2019 Senior Notes were used to repay amounts outstanding under our Revolving Credit Facility related to the West Coast Logistics Assets Acquisition. The remaining net proceeds from the 2019 Senior Notes and all of the net proceeds from the 2022 Senior Notes were used to fund the Rockies Natural Gas Business Acquisition.
	We agreed to complete a registered exchange offer to exchange the 2019 Senior Notes and the 2022 Senior Notes for debt securities with substantially identical terms within 18 months of the closing date of the Senior Notes Offering. As the 2019 Senior Notes and the 2022 Senior Notes had not been registered with the SEC as of December 31, 2014, the condensed consolidating financial information included in Note 16 to the combined consolidated financial statements is not applicable to the 2019 Senior Notes and the 2022 Senior Notes as of December 31, 2014.
	The 2019 Senior Notes have no sinking fund requirements. We may redeem some or all of the 2019 Senior Notes prior to September 15, 2019, at a make-whole price, and at par thereafter, plus any accrued and unpaid interest. The 2019 Senior Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas and Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.
	The 2022 Senior Notes have no sinking fund requirements. We may redeem some or all of the 2022 Senior Notes prior to October 15, 2018, at a make-whole price, plus any accrued and unpaid interest. On or after October 15, 2018, the 2022 Senior Notes may be redeemed at premiums equal to 3.125% through October 15, 2019; 1.563% from October 15, 2019 through October 15, 2020; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 106.25% of face value with proceeds from certain equity issuances through October 15, 2017. The 2022 Senior Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas and Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.
	Senior Notes due 2020
	Effective December 17, 2013, we completed a private offering of $250 million aggregate principal amount of the 5.875% Senior Notes due 2020 (the “December 2013 Debt Offering”) pursuant to a private placement transaction conducted under Rule 144A and Regulation S of the Securities Act of 1933, as amended. The December 2013 Debt Offering was issued under the Indenture governing the $350 million of our 5.875% Senior Notes due 2020 issued on September 14, 2012 (the “September 2012 Debt Offering”) and has the same terms as the September 2012 Debt Offering (together with the December 2013 Debt Offering, the “2020 Senior Notes”). The December 2013 Debt Offering was issued at 102.25% of face value for an effective rate of 5.334%. The proceeds of the December 2013 Debt Offering were used to repay the amounts outstanding under our Revolving Credit Facility, which were used to fund a portion of the Los Angeles Logistics Assets Acquisition, to pay for the fees and expenses related to the December 2013 Debt Offering and for general partnership purposes.
	The 2020 Senior Notes have no sinking fund requirements. We may redeem some or all of the 2020 Senior Notes, prior to October 1, 2016, at a make-whole price plus accrued and unpaid interest. On or after October 1, 2016, the Senior Notes may be redeemed at premiums equal to 2.938% through October 1, 2017; 1.469% from October 1, 2017 through October 1, 2018; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 105.875% of face value with proceeds from certain equity issuances through October 1, 2015. The 2020 Senior Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and any subsidiaries acquired with the Rockies Natural Gas Business Acquisition, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.
	On August 22, 2014, we closed an offering of 2.1 million common units representing limited partner interests, at a price of $67.47 per unit (the “August 2014 Equity Offering”). We used the net proceeds of $142 million from the August 2014 Equity Offering for the redemption of $130 million of the Senior Notes due 2020, and to pay accrued interest and premiums of $4 million and $7 million, respectively. TLGP reimbursed the payment of premiums, which was reflected as a contribution by TLGP as it relates to its ownership of our common units. The premium and $3 million of expenses of unamortized debt issuance costs were included in interest and financing costs, net.
	Senior Notes due 2021
	Effective August 1, 2013, we completed a private offering of $550 million aggregate principal amount of the 6.125% Senior Notes due 2021 (“2021 Senior Notes”). The proceeds of this offering were used to repay the amounts outstanding under our Revolving Credit Facility, which were used to fund a significant portion of the Los Angeles Terminal Assets Acquisition, and to pay a portion of the fees and expenses related to the offering of the 2021 Senior Notes.
	The 2021 Senior Notes have no sinking fund requirements. We may redeem some or all of the 2021 Senior Notes, prior to October 15, 2016, at a make-whole price plus accrued and unpaid interest, if any. On or after October 15, 2016, the Senior Notes due 2021 may be redeemed at premiums equal to 4.594% through October 15, 2017; 3.063% from October 15, 2017 through October 15, 2018; 1.531% from October 15, 2018 through October 15, 2019; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 106.125% of face value with proceeds from certain equity issuances through October 15, 2016. The 2021 Senior Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer and any subsidiaries acquired with the Rockies Natural Gas Business Acquisition, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.
	Registration Rights Agreement and Exchange Offer
	On September 12, 2013, we completed an offer to exchange $350 million of our unregistered Senior Notes due 2020 from the September 2012 Debt Offering and our Senior Notes due 2021 (the “Unregistered Notes”) for an equal principal amount of 5.875% Senior Notes due 2020 and 6.125% Senior Notes due 2021 (the “Exchange Notes”), respectively, that were registered under the Securities Act of 1933, as amended. The terms of the Exchange Notes are identical in all material respects (including principal amount, interest rate, maturity and redemption rights) to the Unregistered Notes for which they were exchanged, except that the Exchange Notes generally are not subject to transfer restrictions. The exchange offer fulfills all of the requirements of the registration rights agreements for such Unregistered Notes.
	On July 25, 2014, we completed an offer to exchange $250 million of our unregistered Senior Notes due 2020 from the December 2013 Debt Offering for an equal principal amount of 5.875% Senior Notes due 2020 that were registered under the Securities Act of 1933, as amended. The terms of the Exchange Notes are identical in all material respects (including principal amount, interest rate, maturity and redemption rights) to the unregistered notes for which they were exchanged, except that the exchange notes generally are not subject to transfer restrictions. The exchange offer fulfills all of the requirements of the Registration Rights Agreement for these unregistered notes.
	Capital Lease Obligations
	Our capital lease obligations relate to two leases of facilities used for trucking operations in North Dakota with initial terms of 15 years, with five-year renewal options and a right of way with an initial term of 31 years. The total cost of assets under capital leases was $9 million with accumulated amortization of $1 million at both December 31, 2014 and 2013. We include amortization of the cost of assets under capital leases in depreciation and amortization expenses in our combined consolidated statements of operations.
	Future minimum annual lease payments, including interest, as of December 31, 2014 for the capital lease were (in millions):
	2015	$	1
	2016	1
	2017	1
	2018	1
	2019	1
	Thereafter	7
	Total minimum lease payments	12
	Less amount representing interest	(4		)
	Capital lease obligations	$	8

Commitments_and_Contingencies_

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES
	Commitments
	Future minimum annual payments applicable to all non-cancellable operating leases and purchase obligations as of December 31, 2014 are as follows (in millions):
		Payments Due by Period
		2015				2016				2017				2018				2019		Thereafter		Total
	Operating leases	$	10			$	8			$	7			$	6			$	6	$	65	$	102
	Purchase obligations	84				85				84				84				84		136		557
	Total	$	94			$	93			$	91			$	90			$	90	$	201	$	659
	Operating Leases
	We have various cancellable and non-cancellable operating leases related to land, trucks, terminals, right-of-way permits and other operating facilities. In general, these leases have remaining primary terms up to 20 years and typically contain multiple renewal options. Total lease expense for all operating leases, including leases with a term of one month or less, was $8 million, $6 million and $4 million for the years ended December 31, 2014, 2013 and 2012, respectively. See Note 10 for information related to our capital leases. See Note 3 for a discussion of revenue recognized under agreements where TLLP is considered the lessor.
	Purchase Obligations
	Our purchase obligations include enforceable and legally binding service agreement commitments that meet any of the following criteria: (1) they are non-cancellable, (2) we would incur a penalty if the agreement was canceled, or (3) we must make specified minimum payments even if we do not take delivery of the contracted products or services. If we can unilaterally terminate the agreement simply by providing a certain number of days’ notice or by paying a termination fee, we have included the termination fee or the amount that would be paid over the notice period. Contracts that can be unilaterally terminated without a penalty are not included. Future purchase obligations primarily include NGL transportation costs, fractionation fees, and fixed charges under the Amended Omnibus Agreement, the QEPM Omnibus Agreement and the Secondment Agreement Amendment. Our Amended Omnibus Agreement and QEPM Omnibus Agreement remain in effect between the applicable parties until a change in control of the Partnership. As we are unable to estimate the termination of these omnibus agreements, we have included the fees for each of the five years following December 31, 2014 for the Amended Omnibus Agreement and the QEPM Omnibus Agreement for disclosure purposes in the table above.
	Total expense under these service agreements was $117 million, $56 million and $28 million for the years ended December 31, 2014, 2013 and 2012, respectively. In addition to these purchase commitments, we also have minimum contractual capital spending commitments for approximately $94 million in 2015.
	Indemnification
	Under the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement, Tesoro indemnifies us for certain matters, including environmental, title and tax matters associated with the ownership of our assets at or before the closing of the Initial Offering and the subsequent Acquisitions from Tesoro.
	Under the Amended Omnibus Agreement, with respect to assets that we acquired from Tesoro, excluding the Los Angeles Terminal Assets and the Los Angeles Logistics Assets, indemnification for unknown environmental and title liabilities is limited to pre-closing conditions identified prior to the earlier of the date that Tesoro no longer controls our general partner or five years after the date of closing. Under the Amended Omnibus Agreement, the aggregate annual deductible for each type of liability (unknown environmental liabilities or title matters) is approximately $1 million, as of December 31, 2014, before we are entitled to indemnification in any calendar year in consideration of the Initial Assets and all subsequent Acquisitions from Tesoro, with the exception of the Los Angeles Terminal Assets Acquisition and the Los Angeles Logistics Assets Acquisition. In addition, with respect to the assets that we acquired from Tesoro, we have agreed to indemnify Tesoro for events and conditions associated with the ownership or operation of our assets that occur after the closing of the Initial Offering, and the subsequent Acquisitions from Tesoro, and for environmental liabilities related to our assets to the extent Tesoro is not required to indemnify us for such liabilities.
	Under the Carson Assets Indemnity Agreement, Tesoro retained responsibility for remediation of known environmental liabilities due to the use or operation of the Los Angeles Terminal Assets and the Los Angeles Logistics Assets prior to the acquisition dates, and has indemnified the Partnership for any losses incurred by the Partnership arising out of those remediation obligations. The indemnification for unknown pre-closing remediation liabilities is limited to five years. However, with respect to Terminal 2 at the Long Beach marine terminal, which was included in the Los Angeles Logistics Assets Acquisition, the indemnification for unknown pre-closing remediation liabilities is limited to ten years. Indemnification of the Los Angeles Terminal Assets’ and the Los Angeles Logistics Assets’ environmental liabilities are not subject to a deductible.
	Contingencies
	In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. The outcome of these matters cannot always be predicted accurately, but TLLP will accrue liabilities for these matters if the amount is probable and can be reasonably estimated. Contingencies arising after the closing of the Initial Offering from conditions existing before the Initial Offering, and the subsequent Acquisitions from Tesoro that have been identified after the closing of each transaction, will be recorded in accordance with the indemnification terms set forth in the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement. Any contingencies arising from events after the Initial Offering, and the subsequent Acquisitions from Tesoro, will be the responsibility of TLLP.
	Environmental Liabilities
	We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remedy the effect of the disposal or release of specified substances at current and former operating sites.
	Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible these estimates will change as additional information becomes available. Changes in our environmental liabilities for the years ended December 31, 2014 and 2013 were as follows (in millions):
			Tioga Crude Oil Pipeline Release				Chevron Corrective Action Order				Other Liabilities				Total
	Balance at December 31, 2013		$	11			$	8			$	5			$	24
	Additions		28				—				2				30
	Expenditures		(14		)		(6		)		(2		)		(22		)
	Balance at December 31, 2014		$	25			$	2			$	5			$	32
	Tioga, North Dakota Crude Oil Pipeline Release
	In September 2013, the Partnership responded to the release of crude oil in a rural field northeast of Tioga, North Dakota (the “Crude Oil Pipeline Release”). The environmental liabilities related to the Crude Oil Pipeline Release include amounts estimated for remediation activities that will be conducted during the next few years to restore the site for agricultural use. We accrued an additional $28 million during the year ended December 31, 2014 to reflect improved scope definition and estimates which resulted in an increase in the total estimated cost associated with the project. We had insurance recovery receivables of $18 million and $14 million related to the Crude Oil Pipeline Release at December 31, 2014 and 2013, respectively. These receivables are pursuant to a pollution liability insurance policy, which is subject to a $1 million deductible and a $25 million loss limit. The estimated remediation costs exceeded our policy loss limit by $17 million as of December 31, 2014. Through December 31, 2014, we have received insurance proceeds of $7 million in reimbursement of costs incurred.
	Costs to comply with a safety order related to the Crude Oil Pipeline Release issued by the Pipeline and Hazardous Materials Safety Administration of the U.S. Department of Transportation (“PHMSA”) are not expected to have a material adverse effect on our liquidity, financial position, or results of operations.
	Chevron Diesel Pipeline Release
	On March 18, 2013, Chevron detected and responded to the release of diesel fuel (the “Diesel Pipeline Release”) that occurred near Willard, Utah on the Northwest Products System. As a result of this release, a Corrective Action Order (the “CAO”) was issued on March 22, 2013 by PHMSA. In addition, on April 11, 2013, the Department of Environmental Quality, Division of Water Quality, of the state of Utah issued a notice of violation and compliance order. In accordance with the sale and purchase agreements related to the Northwest Products System acquisition, as amended, Chevron retains financial and operational responsibility to remediate the site of the Diesel Pipeline Release through mid-2015, in addition to paying any monetary fines and penalties assessed by any government authority arising from this incident.
	The Partnership assumed responsibility for performing additional testing and associated pipeline repairs on the pipeline pursuant to the CAO upon closing the Northwest Products System acquisition. In connection with the Northwest Products System acquisition, our combined consolidated balance sheet included $2 million and $8 million in accrued environmental liabilities related to the CAO at December 31, 2014 and 2013, respectively, and $4 million and $5 million in accruals unrelated to the CAO at December 31, 2014 and 2013, respectively.
	Legal
	Questar Gas Company v. QEP Field Services Company. QEPFS’ former affiliate, Questar Gas Company (“QGC”) and its affiliate Wexpro, filed a complaint on May 1, 2012, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, and an accounting and declaratory judgment related to a 1993 gathering agreement (the “1993 Agreement”) executed when the parties were affiliates. Tesoro Logistics has agreed to indemnify QEPFSC for this claim under the acquisition agreement for QEPFS. Under the 1993 Agreement, certain of QEPFS’ systems provide gathering services to QGC charging an annual gathering rate which is based on the cost of service calculation. QGC is disputing the annual calculation of the gathering rate, which has been calculated in the same manner since 1998, without objection by QGC. At the closing of the QEPM initial public offering (“QEPM IPO”), the assets and agreement discussed above was assigned to QEPM. QGC amended its complaint to add QEPM as a defendant in the litigation. QEPM was indemnified by the Partnership upon closing of the Rockies Natural Gas Business Acquisition for costs, expenses and other losses incurred by QEPM in connection with the QGC dispute, subject to certain limitations, as set forth in the QEPM Omnibus Agreement. QGC has netted $14 million of disputed amounts from its monthly payments of the gathering fees to QEPFS and has continued to net such amounts from its monthly payment to QEPM. In December 2014, the trial court granted a partial summary judgment in favor of QGC on the issues of the appropriate methodology for certain of the cost of service calculations. As a result of the summary judgment, the Partnership assumed a $21 million liability for estimated damages in excess of the amount QGC has netted for disputed amounts. Issues regarding other calculations, the amount of damages and certain counterclaims in the litigation remain open pending a trial on the merits. We believe the outcome of this matter will not have a material impact on our liquidity, financial position, or results of operations.
	XTO Energy Inc. v. QEP Field Services Company. XTO filed a complaint on January 30, 2014, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, unjust enrichment and an accounting related to a 2010 gas processing agreement (the “XTO Agreement”). QEPFS processes XTO’s natural gas on a firm basis under the XTO Agreement. The XTO Agreement requires QEPFS to transport, fractionate and market XTO’s natural gas liquids derived from XTO’s processed gas. XTO is seeking monetary damages related to QEPFS allocation of charges related to XTO’s share of natural gas liquid transportation, fractionation and marketing costs associated with shortfalls in contractual firm processing volumes. We believe the outcome of this matter will not have a material impact on our liquidity, financial position, or results of operations.
	Other than described above, we did not have any other material outstanding lawsuits, administrative proceedings or governmental investigations as of December 31, 2014.

Equity_Notes

Equity (Notes)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Equity	EQUITY
	We had 51,944,182 common public units outstanding as of December 31, 2014. Additionally, Tesoro owned 28,181,748 of our common units, and 1,631,448 of our general partner units (the 2% general partner interest) as of December 31, 2014, which together constitutes a 36.5% ownership interest in us.
	Subordinated Unit Conversion
	Following payment of the cash distribution for the first quarter of 2014 and the attainment of necessary approvals, the requirements for the conversion of all subordinated units were satisfied under the partnership agreement. As a result, effective May 16, 2014, 15,254,890 subordinated units were converted into common units on a one-for-one basis and thereafter participate on terms equal with all other common units in distributions of available cash. The conversion of the subordinated units did not impact the amount of cash distributions paid by the Partnership or the total number of its outstanding units.
	ATM Program
	On June 25, 2014, we filed a prospectus supplement to our shelf registration statement filed with the SEC in 2012, authorizing the continuous issuance of up to an aggregate of $200 million of common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of our offerings (such continuous offering program, or at-the-market program, referred to as our “ATM Program”). During the year ended December 31, 2014, we issued an aggregate of 199,400 common units under our ATM Program, generating net proceeds of approximately $14 million.
	Issuance of Additional Securities
	Our partnership agreement authorizes us to issue an unlimited number of additional partnership securities for the consideration and on the terms and conditions determined by our general partner without the approval of the unitholders. Costs associated with the issuance of securities are allocated to all unitholders’ capital accounts based on their ownership interest at the time of issuance.
	Allocations of Net Income
	Our partnership agreement contains provisions for the allocation of net income and loss to the unitholders and the general partner. For purposes of maintaining partner capital accounts, the partnership agreement specifies that items of income and loss will be allocated among the partners in accordance with their respective percentage interest. Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations.
	The following table presents the allocation of the general partner’s interest in net income (in millions, except percentage of ownership interest):
		Year Ended December 31,
		2014				2013				2012
	Net income attributable to partners	$	99			$	80			$	57
	General partner’s IDRs	(41		)		(11		)		(2		)
	Special Allocation	7				—				—
	Net income available to partners	$	65			$	69			$	55
	General partner’s ownership interest	2		%		2		%		2		%
	General partner’s allocated interest in net income	$	2			$	1			$	1
	General partner’s IDRs	41				11				2
	Total general partner’s interest in net income	$	43			$	12			$	3
	The table below summarizes the changes in the number of units outstanding through December 31, 2014 (in units).
		Common			Subordinated			General Partner			Total
	Balance at December 31, 2011	15,254,890			15,254,890			622,649			31,132,429
	Units issued in the Martinez Marine Terminal Acquisition	206,362			—			4,212			210,574
	Units issued in the Long Beach Assets Acquisition	462,825			—			9,446			472,271
	Units issued in the Anacortes Rail Facility Acquisition	309,838			—			93,289			403,127
	Issuance of units in October 2012 equity offering (a)	4,255,000			—			—			4,255,000
	Unit-based compensation awards (b)	6,339			—			—			6,339
	Balance at December 31, 2012	20,495,254			15,254,890			729,596			36,479,740
	Issuance of units in January 2013 equity offering (c)	9,775,000			—			199,490			9,974,490
	Units issued for the LA Terminal Assets Acquisition	1,445,561			—			29,501			1,475,062
	Issuance of units in November 2013 equity offering (d)	6,300,000			—			—			6,300,000
	Units issued for the LA Logistics Assets Acquisition	1,126,348			—			151,695			1,278,043
	Unit-based compensation awards (b)	6,753			—			—			6,753
	Balance at December 31, 2013	39,148,916			15,254,890			1,110,282			55,514,088
	Issuance of units under ATM Program	199,400			—			—			199,400
	Issuance of units in the West Coast Logistics Assets Acquisition (e)	370,843			—			8,856			379,699
	Issuance of units in August 2014 equity offering (f)	2,100,000			—			44,000			2,144,000
	Issuance of units in October 2014 equity offering (g)	23,000,000			—			468,310			23,468,310
	Unit-based compensation awards (b)	51,881			—			—			51,881
	Subordinated unit conversion	15,254,890			(15,254,890	)		—			—
	Balance at December 31, 2014	80,125,930			—			1,631,448			81,757,378
	____________
	(a) On October 5, 2012, we closed a registered public offering of 4,255,000 common units representing limited partner interests, at a public offering price of $41.80 per unit. We used a significant portion of the net proceeds of $171 million, including the proceeds from the exercise of the underwriters’ over-allotment option, for the Anacortes Rail Facility Acquisition.
	(b) Unit-based compensation awards are presented net of 22,933, 1,306 and 654 units withheld for taxes as of December 31, 2014, 2013 and 2012, respectively.
	(c) On January 14, 2013, we closed the January 2013 Equity Offering of 9,775,000 common units representing limited partner interests, at a public offering price of $41.70 per unit. We initially used the net proceeds of $391 million, including the proceeds from the exercise of the underwriters’ over-allotment option, to make short-term liquid investments and then applied a significant portion of the proceeds to fund the Northwest Products System Acquisition. In addition, as a result of the January 2013 Equity Offering, TLGP contributed $8 million to maintain its 2% general partnership interest.
	(d) On November 22, 2013, we closed the November 2013 Equity Offering of 6,300,000 common units representing limited partner interests, at a public offering price of $51.05 per unit. We initially used the net proceeds of $310 million to make short-term liquid investments and then used the net proceeds to fund a portion of the Los Angeles Logistics Assets Acquisition.
	(e)	On July 1, 2014, we closed on the first portion of the West Coast Logistics Assets Acquisition and issued equity to Tesoro with a fair value of $27 million comprised of 370,843 common units and 8,856 general partner units.
	(f)	On August 22, 2014, we closed the August 2014 Equity Offering. We used a significant portion of the net proceeds of $142 million to redeem a portion of the 5.875% Senior Notes due 2020. TLGP contributed $3 million to maintain its 2% general partnership interest.
	(g)	On October 24, 2014, we closed a registered public offering of 23 million common units representing limited partner interests, at a public offering price of $57.47 per unit. The net proceeds of $1.3 billion include the purchase of 8,700,191 common units by Tesoro equal to $500 million and an over-allotment option exercised by the underwriters to purchase an additional 3 million common units. Concurrent with the October 2014 Equity Offering, TLGP contributed $27 million to maintain its 2% general partner interest in TLLP.
	Incentive Distribution Rights
	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under marginal percentage interest in distributions are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute, up to and including the corresponding amount in the column total quarterly distribution per unit target amount. The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. For illustrative purposes, the percentage interests set forth below for our general partner assume that there are no arrearages on common units, our general partner has contributed any additional capital necessary to maintain its 2% general partner interest and our general partner owns all of the IDRs.
		Total quarterly distribution per unit target amount			Marginal percentage interest in distributions
					Unitholders		General Partner		Incentive Distribution Rights
	Minimum Quarterly Distribution	$0.34			98%		2%		—
	First Target Distribution	Above $0.337500 up to $0.388125			98%		2%		—
	Second Target Distribution	Above $0.388125 up to $0.421875			85%		2%		13%
	Third Target Distribution	Above $0.421875 up to $0.506250			75%		2%		23%
	Thereafter	Above $0.506250			50%		2%		48%
	Cash distributions
	Our partnership agreement, as amended, sets forth the calculation to be used to determine the amount and priority of cash distributions that the limited partner unitholders and general partner will receive. In accordance with our partnership agreement, on January 22, 2015, we declared a quarterly cash distribution, based on the results of the fourth quarter of 2014, totaling $70 million, or $0.6675 per limited partner unit. This distribution was paid on February 13, 2015 to unitholders of record on February 2, 2015.
	In connection with the Rockies Natural Gas Business Acquisition, our general partner will waive its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). TLGP will begin to waive general partner distributions with the first quarter 2015 quarterly distribution.
	The allocation of total quarterly cash distributions to general and limited partners is as follows for the years ended December 31, 2014, 2013 and 2012 (in millions). Our distributions are declared subsequent to quarter end; therefore, the following table represents total cash distributions applicable to the period in which the distributions are earned.
	Year Ended December 31,
	2014				2013				2012
General partner’s distributions:
General partner’s distributions	$	5			$	2			$	1
General partner’s IDRs	41				11				2
Total general partner’s distributions	$	46			$	13			$	3
Limited partners’ distributions:
Common	$	157			$	71			$	36
Subordinated	14				32				26
Total limited partners’ distributions	171				103				62
Total Cash Distributions	$	217			$	116			$	65

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION
	Supplemental disclosure of cash activities include interest paid, net of capitalized interest, of $73 million, $23 million and $2 million for the years ended December 31, 2014, 2013 and 2012, respectively. Supplemental disclosure of non-cash activities is as follows (in millions):
		Year Ended December 31,
		2014		2013		2012
	Sponsor contributions of assets acquired to the Predecessors	$	—	$	702	$	—
	Assets received for deposit paid in prior period	—		40		—
	Capital expenditures included in accounts payable at period end	62		12		5
	Capital leases and other	4		5		4
	Predecessors’ net liabilities not assumed by Tesoro Logistics LP	1		15		2
	Receivable from affiliate for capital expenditures	3		1		—

Segment_Disclosures_Notes

Segment Disclosures (Notes)	12 Months Ended
	Dec. 31, 2014
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Segment Disclosures	SEGMENT DISCLOSURES
	Our revenues are derived from three operating segments: Gathering, Processing, and Terminalling and Transportation. We introduced a new reporting segment (Processing) for the processing assets acquired in the Rockies Natural Gas Business Acquisition. In addition we modified our previous Crude Oil Gathering segment to encompass all gathering operations, including the natural gas transmission assets acquired in the Rockies Natural Gas Business Acquisition. Our Gathering segment consists of crude oil and natural gas gathering systems in the Bakken and Rockies Regions. Our Processing segment consists of four gas processing complexes, including a 60% interest in Green River Processing, LLC, which owns one fractionation facility and two gas processing complexes, with the remaining 40% interest owned by QEPM. Our Terminalling and Transportation segment consists of:
	•	the Northwest Products Pipeline, which includes a regulated common carrier products pipeline running from Salt Lake City, Utah to Spokane, Washington and a jet fuel pipeline to the Salt Lake City International Airport;
	•	a regulated common carrier refined products pipeline system connecting Tesoro’s Kenai refinery to Anchorage, Alaska;
	•	24 crude oil and refined products terminals and storage facilities in the western and midwestern U.S.;
	•	four marine terminals in California;
	•	a rail-car unloading facility in Washington;
	•	a petroleum coke handling and storage facility in Los Angeles; and
	•	other pipelines which transport products and crude oil from Tesoro’s refineries to nearby facilities in Salt Lake City and Los Angeles.
	Our revenues are generated from existing third-party contracts and from commercial agreements we have entered into with Tesoro under which Tesoro pays us fees for gathering crude oil and natural gas, processing natural gas and distributing, transporting and storing crude oil, refined products, natural gas and NGLs. The commercial agreements with Tesoro are described in Note 3. We do not have any foreign operations.
	The operating segments adhere to the accounting polices used for our combined consolidated financial statements, as described in Note 1. Our operating segments are strategic business units that offer different services in different geographical locations. We evaluate the performance of each segment based on its respective operating income. Certain general and administrative expenses and interest and financing costs are excluded from segment operating income as they are not directly attributable to a specific operating segment. Identifiable assets are those used by the segment, whereas other assets are principally cash, deposits and other assets that are not associated with a specific operating segment.
	Segment information is as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	REVENUES
	Gathering:
	Affiliate (a)	$	107		$	88		$	72
	Third-party	30			2			—
	Total Gathering	137			90			72
	Processing:
	Affiliate	7			—			—
	Third-party	16			—			—
	Total Processing	23			—			—
	Terminalling and Transportation:
	Affiliate (b)	385			185			78
	Third-party	57			38			14
	Total Terminalling and Transportation	442			223			92
	Intersegment Revenues (a)	(2		)	—			—
	Total Segment Revenues	$	600		$	313		$	164
	OPERATING INCOME
	Gathering	$	49		$	34		$	26
	Processing	4			—			—
	Terminalling and Transportation	192			57			40
	Total Segment Operating Income	245			91			66
	Unallocated general and administrative expenses	(39		)	(17		)	(9		)
	Interest and financing costs, net	(109		)	(40		)	(9		)
	Equity in earnings of unconsolidated affiliates	1			—			—
	Interest income	—			1			—
	NET INCOME	$	98		$	35		$	48
	____________
	(a)	Affiliate gathering revenues includes $2 million of intersegment revenues related to transactions between our Gathering and Processing segments for the year ended December 31, 2014, which is eliminated upon consolidation.
	(b) Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment for assets acquired in the Acquisitions from Tesoro prior to the effective date of each acquisition, except for the RCA tariffs charged to Tesoro on the refined products pipeline included in the acquisition of the West Coast Logistics Assets.
	Capital expenditures by operating segment were as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Capital Expenditures
	Gathering	$	156		$	52		$	17
	Processing	4			—			—
	Terminalling and Transportation	84			31			77
	Total Capital Expenditures	$	244		$	83		$	94
	Total identifiable assets by operating segment were as follows (in millions):
		December 31,
		2014			2013			2012
	Identifiable Assets
	Gathering	$	1,694		$	155		$	87
	Processing	1,612			—			—
	Terminalling and Transportation	1,352			1,330			233
	Other	156			48			71
	Total Identifiable Assets	$	4,814		$	1,533		$	391

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	QUARTERLY FINANCIAL DATA (UNAUDITED)
		Quarters
		First		Second		Third		Fourth			Total Year
	2014	(Dollars in millions, except per unit amounts)
	Total Revenues	$	127	$	133	$	150	$	190		$	600
	Operating and Maintenance Expenses	53		63		72		102			290
	Operating Income	60		48		61		37			206
	Net Income (Loss)	42		31		33		(8		)	98
	Limited partners’ interest in net income (loss)	36		26		19		(25		)	56
	Net Income (Loss) per limited partner unit (a):
	Common - basic	$	0.64	$	0.45	$	0.33	$	(0.34	)	$	0.96
	Common - diluted	$	0.64	$	0.45	$	0.33	$	(0.34	)	$	0.96
	Subordinated - basic and diluted	$	0.64	$	0.45	$	—	$	—		$	0.62
	2013
	Total Revenues	$	53	$	62	$	97	$	101		$	313
	Operating and Maintenance Expenses	23		32		60		59			174
	Operating Income	22		18		13		21			74
	Net Income	17		11		1		6			35
	Limited partners’ interest in net income	17		17		18		16			68
	Net Income per limited partner unit (a):
	Common - basic	$	0.4	$	0.38	$	0.37	$	0.33		$	1.48
	Common - diluted	$	0.4	$	0.38	$	0.37	$	0.33		$	1.47
	Subordinated - basic and diluted	$	0.37	$	0.36	$	0.37	$	0.26		$	1.35
	____________
	(a) The sum of four quarters may not equal annual results due to rounding or the quarterly number of shares outstanding.

Condensed_Consolidating_Financ

Condensed Consolidating Financial Information (Notes)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
CONDENSED CONSOLIDATING FINANCIAL INFORMATION	CONDENSED CONSOLIDATING FINANCIAL INFORMATION
	Separate condensed consolidating financial information of Tesoro Logistics LP (the “Parent”), subsidiary guarantors and non-guarantors are presented below. At December 31, 2014, TLLP and certain subsidiary guarantors have fully and unconditionally guaranteed our registered 2020 Senior Notes and 2021 Senior Notes. QEPFS and its subsidiaries, including QEPM, did not guarantee these obligations as of December 31, 2014. As a result of these guarantee arrangements, we are required to present the following condensed consolidating financial information, which should be read in conjunction with the accompanying consolidated financial statements and notes thereto. This information is provided as an alternative to providing separate financial statements for guarantor subsidiaries. Separate financial statements of the Partnership’s subsidiary guarantors are not included because the guarantees are full and unconditional and these subsidiary guarantors are 100% owned and are jointly and severally liable for TLLP’s outstanding senior notes. The information is presented using the equity method of accounting for investments in subsidiaries. Intercompany transactions between subsidiaries are presented gross and eliminated in the eliminations column. QEPFS and certain of its subsidiaries were elected guarantors of these obligations in January 2015.
	The parent company of the Partnership has no independent assets or operations and, prior to the Rockies Natural Gas Business Acquisition, the Partnership’s operations were only conducted by wholly-owned guarantor subsidiaries, other than Tesoro Logistics Finance Corp., an indirect wholly-owned subsidiary of the Partnership whose sole purpose is to act as co-issuer of any debt securities. The guarantees are full and unconditional and joint and several, subject to certain automatic customary releases, including sale, disposition, or transfer of the capital stock or substantially all of the assets of a subsidiary guarantor, exercise of legal defeasance option or covenant defeasance option, and designation of a subsidiary guarantor as unrestricted in accordance with the applicable indenture. There were no significant restrictions on the ability of the Partnership or any guarantor to obtain funds from its subsidiaries by dividend or loan. None of the assets of the Partnership or a guarantor represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act. As a result, we have not provided condensed consolidating financial information for prior periods.
	Condensed Consolidating Statement of Operations
	for the Year Ended December 31, 2014
	(In millions)
		Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
	REVENUES
	Affiliate	$	6		$	484		$	7		$	—		$	497
	Third-party	—			74			29			—			103
	Total Revenues	6			558			36			—			600
	COSTS AND EXPENSES
	Operating and maintenance expenses	9			266			15			—			290
	Imbalance settlement gains and reimbursements from Tesoro	—			(43		)	—			—			(43		)
	General and administrative expenses	37			34			3			—			74
	Depreciation and amortization expenses	1			68			8			—			77
	Gain on asset disposals and impairments	—			(4		)	—			—			(4		)
	Total Costs and Expenses	47			321			26			—			394
	OPERATING INCOME (LOSS)	(41		)	237			10			—			206
	Interest and financing costs, net	(115		)	6			—			—			(109		)
	Equity in earnings of unconsolidated affiliates	—			—			1			—			1
	Equity in earnings of subsidiaries	251			—			—			(251		)	—
	NET INCOME	$	95		$	243		$	11		$	(251	)	$	98
	Loss attributable to Predecessors (a)	4			—			—			—			4
	Net income attributable to noncontrolling interest	—			—			(3		)	—			(3		)
	Net income attributable to partners	$	99		$	243		$	8		$	(251	)	$	99
	____________
	(a)	Amounts attributable to Predecessors have been reflected in the Parent column.
	Condensed Consolidating Balance Sheet as of December 31, 2014
	(In millions)
		Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
	ASSETS
	Current Assets
	Cash and cash equivalents	$	—		$	—		$	19		$	—		$	19
	Receivables, net
	Trade	—			13			109			—			122
	Affiliate	3			52			14			—			69
	Other	—			18			—			—			18
	Prepayments and other	3			2			2			—			7
	Total Current Assets	6			85			144			—			235
	Net property, plant and equipment	1			1,569			1,736			—			3,306
	Intangibles	—			—			973			—			973
	Goodwill	—			9			155			—			164
	Investment in unconsolidated affiliates	—			—			57			—			57
	Investments in subsidiaries	4,348			—			—			(4,348		)	—
	Long-term intercompany receivable	—			307			—			(307		)	—
	Other noncurrent assets	49			7			23			—			79
	Total Assets	$	4,404		$	1,977		$	3,088		$	(4,655	)	$	4,814
	LIABILITIES AND EQUITY
	Current Liabilities
	Accounts payable
	Trade	$	6		$	57		$	63		$	—		$	126
	Affiliate	2			40			11			—			53
	Accrued interest and financing costs	28			—			—			—			28
	Other current liabilities	21			33			25			—			79
	Total Current Liabilities	57			130			99			—			286
	Long-term intercompany payable	307			—			—			(307		)	—
	Other noncurrent liabilities	—			14			31			—			45
	Debt	2,585			8			—			—			2,593
	Equity - TLLP	1,455			1,825			2,523			(4,348		)	1,455
	Equity - Noncontrolling interest	—			—			435			—			435
	Total Liabilities and Equity	$	4,404		$	1,977		$	3,088		$	(4,655	)	$	4,814
	Condensed Consolidating Statement of Cash Flows
	for the Year Ended December 31, 2014
(In millions)
	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	$	(138	)	$	317		$	6		$	—		$	185
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	(1		)	(195		)	(3		)	—			(199		)
Acquisitions	—			—			(2,479		)	—			(2,479		)
Investments in subsidiaries	(2,510		)	—			—			2,510			—
Distributions to parent	15			—			(15		)	—			—
Proceeds from sale of assets	—			10			—			—			10
Net cash used in investing activities	(2,496		)	(185		)	(2,497		)	2,510			(2,668		)
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	1,300			—			—			—			1,300
Proceeds from issuance of common units, net of issuance costs	1,449			—			—			—			1,449
Proceeds from issuance of general partner units, net of issuance costs	29			—			—			—			29
Distributions related to acquisitions	(243		)	—			—			—			(243		)
Quarterly distributions to unitholders	(148		)	—			—			—			(148		)
Quarterly distributions to general partner	(35		)										(35		)
Repayments under revolving credit agreement	(386		)	—			—			—			(386		)
Borrowings under revolving credit agreement	646			—			—			—			646
Repayments of debt	(130		)	—			—			—			(130		)
Contributions by parent	—			—			2,510			(2,510		)	—
Intercompany borrowings (payments)	132			(132		)	—			—			—
Sponsor contributions of equity to the Predecessors	3			—			—			—			3
Financing costs	(32		)	—			—			—			(32		)
Capital contributions by affiliate	26			—			—			—			26
Net cash from (used in) financing activities	2,611			(132		)	2,510			(2,510		)	2,479
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(23		)	—			19			—			(4		)
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	23			—			—			—			23
CASH AND CASH EQUIVALENTS, END OF YEAR	$	—		$	—		$	19		$	—		$	19

Description_of_Business_and_Su1

Description of Business and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting, Policy	The accompanying consolidated financial statements include the accounts of TLLP and its subsidiaries. All intercompany accounts and transactions have been eliminated. We have evaluated subsequent events through the filing of this Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. Certain prior year balances have been reclassified to conform to current year presentation.
Consolidation, Policy	Our consolidated financial statements include QEPM, a variable interest entity with the portion not owned by TLLP reflected as a reduction to net income and equity as a noncontrolling interest. QEP Midstream Partners GP, LLC (“QEPM GP”), TLLP’s fully consolidated subsidiary, serves as QEPM’s general partner. As the general partner of QEPM, we have the sole ability to direct the activities of QEPM that most significantly impact its economic performance. We are also considered to be the primary beneficiary for accounting purposes. QEPM provides natural gas gathering and transportation services, primarily under fee-based contracts. Under these arrangements, QEPM receives a fee or fees for one or more of the following services: firm and interruptible gathering or transmission of natural gas, crude oil, condensate, and produced water. In the event QEPM incurs a loss, our operating results will reflect QEPM’s loss, net of intercompany eliminations, to the extent of our ownership interest in QEPM. All intercompany transactions with QEPM are eliminated upon consolidation.
Use of Estimates, Policy	Use of Estimates
	We prepare our combined consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”), which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and revenues and expenses reported and presented as of and for the periods ended. We review our estimates on an ongoing basis using currently available information. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates.
Reclassifications, Policy	Reclassifications
	Certain prior year balances have been reclassified in order to conform to the current year presentation including amounts within operating and maintenance expenses to disaggregate reimbursements from Tesoro, which are now included in imbalance settlement gains and reimbursements from Tesoro within the combined consolidated statements of operations.
Acquisitions, Policy	Acquisitions
	We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed with acquisitions at their estimated fair values as of the date of acquisition, with the exception of the Acquisitions from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro on our consolidated balance sheet at Tesoro’s historical basis instead of fair value. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. While we use our best estimates and assumptions to measure the fair value of the identifiable assets acquired and liabilities assumed at the acquisition date, our estimates are inherently uncertain and subject to refinement. As a result, during the measurement period, not to exceed one year from the date of acquisition, any changes in the estimated fair values of the net assets recorded for the acquisitions will result in an adjustment to goodwill. Upon the conclusion of the measurement period or final determination of the values of assets acquired or liabilities assumed, whichever comes first, any subsequent adjustments are recorded to our combined consolidated statements of operations.
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents
	Cash and cash equivalents include bank deposits and low-risk short-term investments with original maturities of three months or less at the time of purchase. Cash equivalents are stated at cost, which approximates market value. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.
Receivables, Policy	Receivables
	A portion of the Partnership’s accounts receivable is due from Tesoro. Credit for non-affiliated customers is extended based on an evaluation of each customer’s financial condition and in certain circumstances, collateral, such as letters of credit or guarantees, is required. Our allowance for doubtful accounts is based on various factors including current sales amounts, historical charge-offs and specific accounts identified as high risk. Uncollectible accounts receivable are charged against the allowance for doubtful accounts when all reasonable efforts to collect the amounts due have been exhausted. The Partnership had an immaterial amount of allowance for doubtful accounts at both December 31, 2014 and 2013.
Financial Instruments, Policy	Financial Instruments
	Financial instruments including cash and cash equivalents, receivables, accounts payable and accrued liabilities are recorded at their carrying value. We believe the carrying value of these financial instruments approximates fair value. Our fair value assessment incorporates a variety of considerations, including:
	•	the short term duration of the instruments (less than one percent of our trade payables and seven percent of our third-party receivables have been outstanding for greater than 90 days); and
	•	the expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk.
	The computation of the percentage of the short-term duration of our third-party receivables excludes amounts that are greater than 90 days related to XTO Energy Inc.’s (“XTO”) legal dispute with QEPFS. See further discussion regarding the XTO litigation in Note 11.
	The fair value of our senior notes is based on prices from recent trade activity and is categorized in level 2 of the fair value hierarchy. The carrying value and fair value of our debt were both approximately $2.6 billion at December 31, 2014 and were both approximately $1.2 billion at December 31, 2013.
Property, Plant and Equipment, Policy	Property, Plant and Equipment
	Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation or fair value, if impaired. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering and other allocated employee costs. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and maintenance projects that do not increase the original efficiency, productivity or capacity of property, plant and equipment are expensed as incurred. We capitalize interest as part of the cost of major projects during the construction period. These costs are recorded as a reduction to interest and financing costs.
	We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of three to 28 years and salvage value of each asset. When assets are placed into service, we make estimates with respect to their useful lives that we believe are reasonable. However, factors such as maintenance levels, economic conditions impacting the demand for these assets and regulatory or environmental requirements could cause us to change our estimates, thus impacting the future calculation of depreciation. We depreciate leasehold improvements and property acquired under capital leases over the lesser of the lease term or the economic life of the asset.
Impairment of Long-Lived Assets, Policy	Impairment of Long-Lived Assets
	We review property, plant and equipment and other long-lived assets, including acquired intangibles with finite lives, for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. If this occurs, an impairment loss is recognized for the difference between the asset fair value and net book value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.
Acquired Intangibles, Policy	Acquired Intangibles
	Acquired intangibles are recorded at fair value as of the date acquired, and consist of customer relationships obtained in connection with the Rockies Natural Gas Business Acquisition. The value for the identified customer relationships consists of cash flow expected from existing contracts and future arrangements from the existing customer base. We amortize acquired intangibles with finite lives on a straight-line basis over an estimated weighted average useful life of 35 years, and we include the amortization in depreciation and amortization on our combined consolidated statements of operations. Amortization expense of $2 million was included in our financial statements for the year ended December 31, 2014. Amortization expense is expected to be approximately $28 million per year for the next five years beginning January 1, 2015. We have not yet finalized our valuation estimate and related evaluation of the useful lives; accordingly, future amortization of intangible assets related to customer relationships may be revised.
Goodwill, Policy	Goodwill
	Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. We do not amortize goodwill. We are required, however, to review goodwill for impairment annually or more frequently if events or changes in business circumstances indicate the book value of the goodwill may not be recoverable. In such circumstances, we record the impairment in loss on asset disposals and impairments in our combined consolidated statement of operations. We review the carrying value of goodwill for impairment as of November 1st of each year, or sooner if events or changes in circumstances indicate the carrying amount of a reporting unit may exceed fair value.
	We perform a qualitative analysis to determine whether it is more likely than not that the fair value of goodwill is less than its carrying value. If we determine it is more likely than not that the fair value of goodwill is less than its carrying amount, then a second step is performed to quantify the amount of goodwill impairment. If impairment is indicated, a goodwill impairment charge would be recorded to write the goodwill down to its implied fair value. In 2014, based on the qualitative analysis performed, we determined that no further impairment testing was necessary.
	We recorded $155 million of goodwill in connection with the Rockies Natural Gas Business Acquisition, of which $20 million was included in our Gathering segment, and $135 million included in our Processing segment. The goodwill recorded represents future organic growth opportunities, anticipated synergies and intangible assets that did not qualify for separate recognition. Goodwill of $9 million was recorded in conjunction with the acquisition of the Northwest Products Pipeline and the Boise and Pocatello, Idaho and Pasco, Washington refined products terminals (collectively, the “Northwest Products System”) on June 19, 2013 (the “Northwest Products System Acquisition”) from Chevron Pipe Line Company and Northwest Terminalling Company (collectively, “Chevron”) and is included in our Terminalling and Transportation segment.
Investment in Unconsolidated Affiliates, Policy	Investment in Unconsolidated Affiliates
	For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in investment in unconsolidated affiliates in our combined consolidated balance sheet and adjusted for our shares of the net earnings and losses of the investee and cash distributions, which are separately stated in our combined consolidated statement of operations and our combined consolidated statement of cash flows. Amounts recognized for earnings in excess of distributions of our equity method investments are included in the operating section of our combined consolidated statement of cash flows. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary.
	The principal unconsolidated affiliates and TLLP’s ownership percentage as of December 31, 2014 were Uintah Basin Field Services, L.L.C., in which we owned a 38% ownership interest, and Three Rivers Gathering, L.L.C., in which QEPM, our consolidated entity, owns a 50% ownership interest. Both are limited liability companies engaged in gathering and compressing natural gas.
Asset Retirement Obligations, Policy	Asset Retirement Obligations
	An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. We record AROs at fair value in the period in which we have a legal obligation to incur this liability and can make a reasonable estimate of the fair value of the liability. Cost projections are based on engineering estimates, expected timing, probability of occurrence, experience gained from similar sites for which comparable projects have been completed and other closure costs using our credit-adjusted risk free rate. These estimates will be re-evaluated and adjusted as necessary as more information becomes available. When the liability is initially recorded, the cost is capitalized by increasing the book value of the related long-lived tangible asset. The liability is accreted through operating expenses to its estimated settlement value and the related capitalized cost is depreciated over the asset’s useful life. Settlement dates are estimated by considering our past practice, industry practice, management’s intent and estimated economic lives.
	Estimates of the fair value for certain AROs may not be made as settlement dates (or range of dates) associated with these assets are not estimable because we intend to operate and maintain our assets as long as supply and demand for petroleum products exists. AROs primarily include regulatory or contractual obligations for the expected future demolition or removal of assets and related hazardous materials, if applicable, located at our leased facilities including the demolition or removal of tanks, pipelines or other equipment. AROs included in our consolidated balance sheets at December 31, 2014 were $30 million related to the preliminary purchase price allocation of the Rockies Natural Gas Business Acquisition and at December 31, 2013 they were immaterial.
Other Assets, Policy	Other Assets
	We defer debt issuance costs related to our credit agreements and senior notes and amortize the costs over the terms of each instrument using the effective interest method. Amortization of deferred issuance costs, which is included in interest and financing costs, was $6 million and $2 million in the years ended December 31, 2014 and 2013, respectively. We reassess the carrying value of debt issuance costs when modifications are made to the related debt instruments.
Environmental Matters, Policy	Environmental Matters
	We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and the extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Generally, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value, and environmental expenses are recorded primarily in operating expenses.
	As of December 31, 2014, we carry a pollution liability insurance policy, which is subject to a $2 million deductible and a $50 million loss limit. We record insurance recoveries during the year when recovery is probable and can be reasonably estimated.
Legal Liabilities, Policy	Legal Liabilities
	In the ordinary course of business, we become party to lawsuits, administrative proceedings and governmental investigations. These matters may involve large or unspecified damages or penalties that may be sought from us and may require years to resolve. We record a liability related to a loss contingency attributable to such legal matters in other current liabilities or other noncurrent liabilities on our consolidated balance sheet, depending on the classification as current or noncurrent if we determine the loss to be both probable and estimable. The liability is recorded for an amount that is management’s best estimate of the loss, or when a best estimate cannot be made, the minimum loss amount of a range of possible outcomes.
Revenue Recognition, Policy	Revenue Recognition
	The Partnership generates revenue by charging fees for gathering crude oil and natural gas, for terminalling, transporting and storing crude oil and refined products and for processing natural gas and natural gas liquids. Revenues are recognized as crude oil, natural gas and refined products are transported through, delivered by, or stored in our pipelines, terminals and storage facility assets and transported by our trucking operations. Processing revenues are generated under long-term contracts with fee-based or keep-whole agreements. Under our fee-based agreements, the amount of fee-based revenue we generate is based on the volumes of natural gas that we process at our processing complexes.
	The only historic revenues reflected in the financial statements of our Predecessor are amounts received from third-party use of our pipelines and terminals, and amounts received from Tesoro with respect to transportation regulated by the RCA on the refined products pipeline included in the West Coast Logistics Assets Acquisition. Tesoro was not charged fees for services rendered with respect to any terminalling, storage or pipeline transportation services, except as described above, prior to the Acquisitions from Tesoro, as the respective assets were operated as a component of Tesoro’s petroleum refining and marketing businesses.
	The Partnership has several streams of revenue. Revenues are recognized as products are shipped through our pipelines and terminals. Billings to customers for obligations under their quarterly minimum revenue commitments (shortfall payments) are recorded as deferred revenue when they have the right to receive future services for these billings. Some of our fee-based agreements provide for fixed demand charges, which are recognized as revenue pursuant to the contract terms.
	Revenue is recognized at the earlier of:
	•	the customer receiving the services provided by these billings;
	•	the expiration of the period in which the customer is contractually allowed to receive the services; or
	•	the determination that future services will not be required.
Reimbursements, Policy	Reimbursements
	Pursuant to the Third Amended and Restated Omnibus Agreement (“Amended Omnibus Agreement”), Tesoro reimburses the Partnership for pressure testing, required repairs and maintenance identified as a result of the first inspection of certain pipeline and tank assets subsequent to the Acquisitions from Tesoro, as well as maintenance projects identified in the Amended Omnibus Agreement for which the costs were not known at the date of the Acquisitions from Tesoro. These amounts are recorded as a reduction to operating expense within the category labeled imbalance settlement gains and reimbursements from Tesoro during the period the costs are incurred and were $26 million, $4 million and $2 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	In addition, Tesoro reimburses the Partnership for capital projects identified in the Amended Omnibus Agreement. These amounts are recorded as a capital contribution by affiliate and were $26 million, $5 million and $6 million for the years ended December 31, 2014, 2013 and 2012, respectively.
Imbalances, Policy	Imbalances
	We experience volume gains and losses, which we sometimes refer to as imbalances, within our pipelines, terminals and storage facilities due to pressure and temperature changes, evaporation and variances in meter readings and in other measurement methods. On our High Plains System, we retain 0.20% of the crude oil shipped on the High Plains Pipeline and we bear any crude oil volume losses in excess of that amount. Under the Second Amended and Restated Master Terminalling Service Agreement with Tesoro, we retain 0.25% of the refined products we handle at certain of our terminals for Tesoro, and bear any refined product volume losses in excess of that amount. The value of any crude oil or refined product imbalance settlements resulting from these tariffs or contractual provisions is determined by using the monthly average market prices for the applicable commodity, less a specified discount. The Partnership measures volume losses annually for the terminals and pipelines in the Northwest Products System. We retain 0.125% of the distillates and 0.25% of the other refined products we handle at our terminals on the Northwest Products System and we bear any refined product volume losses in excess of those amounts. The value of any refined product losses is determined by using the annual average market price for the applicable commodity. Any settlements under tariffs or contractual provisions where we bear any crude oil or refined product volume losses in excess of amounts specified reduce our operating and maintenance expenses in the period in which they are realized, to the extent they are within the loss allowance, and increase our operating and maintenance expenses in such period to the extent they exceed the loss allowance. For all of other terminals, and under our other commercial agreements with Tesoro, we have no obligation to measure volume losses and have no liability for physical losses.
	The combined consolidated balance sheets also include offsetting natural gas imbalance receivables or payables resulting from differences in gas volumes received by customers and gas volumes delivered to interstate pipelines. Natural gas volumes owed to or by TLLP that are subject to tariffs are valued at market index prices, as of the balance sheet dates, and are subject to cash settlement procedures. Other natural gas volumes owed to or by TLLP are valued at the our weighted average cost of natural gas as of the balance sheet dates and are settled in-kind.
Unit-based Compensation, Policy	Unit-based Compensation
	Our general partner provides unit-based compensation to officers and non-employee directors for the Partnership, which includes service and performance phantom unit awards. The fair value of our service phantom unit awards on the date of grant is equal to the market price of our common units. We estimate the grant date fair value of performance phantom unit awards using a Monte Carlo simulation at the inception of the award. We amortize the fair value over the vesting period using the straight-line method. The phantom unit awards are settled in TLLP common units. Expenses related to unit-based compensation are included in general and administrative expenses in our combined consolidated statements of operations.
Net Income per Limited Partner Unit, Policy	Net Income per Limited Partner Unit
	We use the two-class method when calculating the net income per unit applicable to limited partners, because we have more than one participating security. At December 31, 2014, our participating securities consist of common units, general partner units and incentive distribution rights (“IDRs”). Net income attributable to the Partnership is allocated between the limited and general partners in accordance with our partnership agreement. We base our calculation of net income per unit on the weighted-average number of common and subordinated limited partner units outstanding during the period.
	Diluted net income per unit includes the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. Basic and diluted net income per unit applicable to subordinated limited partners was historically the same, as there were no potentially dilutive subordinated units outstanding. Distributions less than or greater than earnings are allocated in accordance with our partnership agreement.
Income Taxes, Policy	Income Taxes
	We are a limited partnership and are not subject to federal or state income taxes. Accordingly, our taxable income or loss is included in the federal and state income tax returns of our partners. Taxable income may vary substantially from income or loss reported for financial reporting purposes due to differences in the tax bases and financial reporting bases of assets and liabilities, and due to certain taxable income allocation requirements of the partnership agreement. We are unable to readily determine the net difference in the bases of our assets and liabilities for financial and tax reporting purposes because individual unitholders have different investment bases depending upon the timing and price of acquisition of their partnership units.
	U.S. GAAP requires management to evaluate uncertain tax positions taken by the Partnership. The financial statement effects of a tax position are recognized when the position is more likely than not, based on the technical merits, to be sustained upon examination by the Internal Revenue Service. Management has analyzed the tax positions taken by the Partnership and has concluded that there are no uncertain positions taken or expected to be taken. The Partnership is subject to routine audits by taxing jurisdictions; however, there are currently no audits for any tax periods in progress.
Noncontrolling Interests, Policy	Noncontrolling Interests
	Noncontrolling interests represent third-party ownership in the net assets of our consolidated subsidiaries and are presented as a component of equity and net income. Changes in TLLP’s ownership interest in subsidiaries that do not result in deconsolidation are recognized in equity. On December 2, 2014, we completed the Rockies Natural Gas Business Acquisition, which included controlling interest in QEPM and Rendezvous Gas. QEPM’s results, which include Rendezvous Gas, are consolidated into TLLP as it is a majority-owned and controlled subsidiary and the portion not owned by TLLP is reflected as noncontrolling interest. Noncontrolling interest was initially valued primarily based on the market value of public common units outstanding at the acquisition date for QEPM as well as the respective third-party ownership of future cash flows for Rendezvous Gas, based on estimated future volumes and estimated earnings.
New Accounting Standards, Policy	New Accounting Standards
	Revenue Recognition
	The Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) in May 2014 providing accounting guidance for all revenue arising from contracts to provide goods or services to customers. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2016, and early adoption is not permitted. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the ASU to determine the method of adoption and the impact this ASU may have on our financial statements and related disclosures.
	Pushdown Accounting
	The Securities and Exchange Commission released a Staff Accounting Bulletin (“SAB”) in November 2014, overturning portions of the interpretive guidance regarding pushdown accounting. Effective November 18, 2014, the new bulletin aligns the existing guidance to the ASU issued by the FASB in October 2014. Under the new guidance, pushdown accounting can be applied in the separate financial statements of the acquired entity upon completion of the acquisition or in a subsequent period. This impacts the stand-alone financial statements of the subsidiary, but does not alter the existing reporting requirements for the parent company to record the acquired assets, liabilities, and non-controlling interests in consolidated financial statements. If pushdown accounting is not applied in the reporting period in which the change-in-control event occurs, an acquired entity will have the option to elect to apply pushdown accounting in a subsequent reporting period. If pushdown accounting is applied, that election is irrevocable. The SEC responded by rescinding its guidance on pushdown accounting, which had required registrants to apply pushdown accounting in certain circumstances. With regard to the Rockies Natural Gas Business Acquisition, we did not elect to apply pushdown accounting to certain acquired entities.
	Consolidation
	The FASB issued an ASU in February 2015 amending current consolidation guidance including changes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. We are evaluating the new ASU to determine whether any of our current conclusions with respect to consolidation of variable interest or other entities will change under the new guidance. At this time, we cannot estimate the impact of this ASU on our financial statements and related disclosures.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The table below presents the preliminary acquisition date purchase price allocation (in millions):
	Cash	$	31
	Accounts receivable	117
	Prepayments and other	7
	Property, plant and equipment	1,735
	Intangibles	976
	Goodwill	155
	Investment in unconsolidated affiliates	57
	Other noncurrent assets	22
	Accounts payable	(81		)
	Other current liabilities	(47		)
	Other noncurrent liabilities	(30		)
	Noncontrolling interest	(432		)
	Total purchase price	$	2,510
Acquisition
Business Acquisition, Financial Information	The following are the results of the West Coast Logistics Assets operations, prior to the West Coast Logistics Assets respective acquisitions’ dates on July 1, 2014 and September 30, 2014, for the years ended December 31, 2014, 2013 and 2012. The results of the West Coast Logistics Assets, subsequent to each respective acquisition date, have been included in TLLP’s consolidated results.
			Year Ended December 31,
			2014				2013			2012
			(in millions)
	Revenues		$	6			$	8		$	7
	Total costs and expenses		(10		)		(15		)	(15		)
	Net loss		$	(4	)		$	(7	)	$	(8	)
Schedule of Business Acquisitions, by Acquisition	The following amounts associated with the West Coast Logistics Asset Acquisition and the Rockies Natural Gas Business Acquisition, subsequent to each respective acquisition date, are included in the combined consolidated statements of operations of TLLP (in millions):
		Year Ended
		31-Dec-14
	West Coast Logistics Acquisition:
	Total revenues	$	19
	Net income attributable to partners	13
	Costs associated with the acquisition (a)	2
	Rockies Natural Gas Business Acquisition:
	Total revenues	$	36
	Net income attributable to partners	7
	Costs associated with the acquisition (a)	33
	____________
	(a)	Costs associated with the acquisitions are included in the general and administrative expenses and interest and financing costs in our combined consolidated statements of operations.
Northwest Products System
Acquisition
Business Acquisition, Pro Forma Information	The following unaudited pro forma condensed combined consolidated results of operations for the years ended December 31, 2013 and 2012 are presented as if the Northwest Products System acquisition had been completed on January 1, 2012. The amounts presented below have not been adjusted to include the pro forma results of the Rockies Natural Gas Business Acquisition for the year ended December 31, 2013.
			Year Ended December 31,
			2013				2012
			(Dollars in millions, except per unit amounts)
	Revenues		$	327			$	207
	Net income		46				67
	Net income attributable to partners		84				68
	Net income per limited partner unit:
	Common - basic		$	1.56			$	1.59
	Common - diluted		$	1.56			$	1.58
	Subordinated - basic and diluted		$	1.46			$	1.49
Rockies Natural Gas Business Acquisition
Acquisition
Business Acquisition, Pro Forma Information	The unaudited pro forma financial information below reflects adjustments to exclude $8 million of nonrecurring accelerated amortization of certain QEPFS deferred issuance costs and $33 million of transaction costs as a result of the Rockies Natural Gas Business Acquisition for the year ended December 31, 2014.
		Year Ended December 31,
		2014				2013
		(Dollars in millions, except per unit amounts)
	Revenues	$	936			$	689
	Net income	126				72
	Net income attributable to partners	106				105
	Net income per limited partner unit:
	Common - basic and diluted	$	0.77			$	1.23
	Subordinated - basic and diluted	$	1.13			$	1.39

RelatedParty_Transactions_Tabl

Related-Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Commercial arrangements	These commercial agreements with Tesoro include:
		Initiation Date		Term	Renewals		Termination Provisions
							Refinery Shutdown Notice Period (a)	Force Majeure
	Transportation Services Agreement (High Plains System)	Apr-11		10 years	2 x 5 years		12 months	TLLP can declare (unilateral)
	Second Amended and Restated Trucking Transportation Services Agreement (High Plains System)	Apr-11		5 years	1 x 5 years
	Second Amended and Restated Master Terminalling Services Agreement	Apr-11		10 years	2 x 5 years
	Amended Salt Lake City Storage and Transportation Services Agreement	Apr-11		10 years	2 x 5 years
	Amorco Terminal Use and Throughput Agreement (Martinez Marine)	Apr-12		10 years	2 x 5 years
	Amended Anacortes Track Use and Throughput Agreement	Nov-12		10 years	2 x 5 years		N/A
	Carson Storage Services Agreement	Jun-13		10 years	2 x 5 years
	Amended and Restated Master Terminalling Services Agreement - Southern California	Jun-13		10 years	2 x 5 years
	Long Beach Storage Services Agreement	Dec-13		10 years	2 x 5 years
	Transportation Services Agreement (SoCal Pipelines)	Dec-13		10 years	2 x 5 years
	Carson Coke Handling Services Agreement	Dec-13		10 years	2 x 5 years
	Amended and Restated Long Beach Berth Access Use and Throughput Agreement (b)	Dec-13		10 years	2 x 5 years
	Long Beach Berth Throughput Agreement (b)	Dec-13		10 years	2 x 5 years
	Long Beach Pipeline Throughput Agreement	Dec-13		10 years	2 x 5 years
	Terminalling Services Agreement - Nikiski	Jul-14		10 years	2 x 5 years
	Terminalling Services Agreement - Anacortes	Jul-14		10 years	2 x 5 years
	Terminalling Services Agreement - Martinez	Jul-14		10 years	2 x 5 years
	Storage Services Agreement - Anacortes	Jul-14		10 years	2 x 5 years
	Martinez Dedicated LPG Storage Agreement	Jul-14		10 years	2 x 5 years
	Tesoro Alaska Pipeline Throughput Agreement	Sep-14		10 years	2 x 5 years
	____________
	(a)	Fixed minimum volumes remain in effect during routine turnarounds.
	(b)	Agreement gives Tesoro the option to renew for two five-year terms, or Tesoro may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement.
Schedule of Related Party Transactions	A summary of revenue and expense transactions with Tesoro, including expenses directly charged and allocated to our Predecessors, are as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Revenues	$	497		$	273		$	150
	Operating and maintenance expenses	77			71			28
	Imbalance settlement gains and reimbursements from Tesoro (a)	(43		)	(12		)	(12		)
	General and administrative expenses	39			20			13
	____________
	(a) Includes imbalance settlement gains of $17 million, $8 million and $10 million in the years ended December 31, 2014, 2013 and 2012, respectively. Also includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement of $26 million, $4 million and $2 million in the years ended December 31, 2014, 2013 and 2012, respectively.

Net_Income_Per_Unit_Tables

Net Income Per Unit (Tables)	12 Months Ended
	Dec. 31, 2014
Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The calculation of net income per unit is as follows (in millions, except unit and per unit amounts):
		Year Ended December 31,
		2014			2013			2012
	Net income attributable to partners	$	99		$	80		$	57
	Special allocation of net income (“Special Allocation”) (a)	7			—			—
	Net income attributable to partners, excluding Special Allocation	106			80			57
	General partner’s distributions (including IDRs) (b)	(46		)	(13		)	(3		)
	Limited partners’ distributions on common units	(157		)	(71		)	(36		)
	Limited partner’s distributions on subordinated units (c)	(14		)	(32		)	(26		)
	Distributions greater than earnings	$	(111	)	$	(36	)	$	(8	)
	General partner’s earnings:
	Distributions (including IDRs) (b)	$	46		$	13		$	3
	Allocation of distributions greater than earnings	(3		)	(1		)	—
	Total general partner’s earnings	$	43		$	12		$	3
	Limited partners’ earnings on common units:
	Distributions	$	157		$	71		$	36
	Special Allocation (a)	(7		)	—			—
	Allocation of distributions greater than earnings	(98		)	(23		)	(4		)
	Total limited partners’ earnings on common units	$	52		$	48		$	32
	Limited partner’s earnings on subordinated units (c):
	Distributions	$	14		$	32		$	26
	Allocation of distributions greater than earnings	(10		)	(12		)	(4		)
	Total limited partner’s earnings on subordinated units	$	4		$	20		$	22
	Weighted average limited partner units outstanding:
	Common units - basic	54,203,508			31,545,935			16,614,668
	Common unit equivalents	45,908			72,499			94,282
	Common units - diluted	54,249,416			31,618,434			16,708,950
	Subordinated units - basic and diluted (c)	5,642,220			15,254,890			15,254,890
	Net income per limited partner unit:
	Common - basic	$	0.96		$	1.48		$	1.9
	Common - diluted	$	0.96		$	1.47		$	1.89
	Subordinated - basic and diluted	$	0.62		$	1.35		$	1.47
	____________
	(a)	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to TLGP common unitholders for the premium paid in connection with the redemption of the senior notes due 2020.
	(b)	General partner’s distributions (including IDRs) consist of the 2% general partner interest and IDRs, which entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. See Note 12 for further discussion related to IDRs.
	(c)	On May 16, 2014, the 15,254,890 subordinated units were converted into common units on a one-for-one basis and thereafter participate on terms equal with all other common units in distributions of available cash. Distributions and the Partnership’s net income were allocated to the subordinated units through May 15, 2014.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment, at cost, is as follows (in millions):
		December 31,			December 31,
		2014			2013
	Gathering	$	1,507		$	172
	Processing	539			—
	Terminalling and Transportation	1,478			1,397
	Other	27			—
	Property, Plant and Equipment	3,551			1,569
	Accumulated depreciation	(245		)	(171		)
	Net Property, Plant and Equipment	$	3,306		$	1,398

Other_Current_Liabilities_Tabl

Other Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Other Liabilities, Current [Abstract]
Schedule of Other Current Liabilities	Other current liabilities are as follows (in millions):
		December 31,		December 31,
		2014		2013
	Legal	$	21	$	—
	Accrued environmental liabilities	13		20
	Other	45		10
	Total Other Current Liabilities	$	79	$	30

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Debt	Our total debt at December 31, 2014 and 2013 was comprised of the following (in millions):
	Debt, including current maturities:	December 31,				December 31,
		2014				2013
	Revolving Credit Facility	$	260			$	—
	5.500% Senior Notes due 2019	500				—
	5.875% Senior Notes due 2020 (a)	475				606
	6.125% Senior Notes due 2021	550				550
	6.250% Senior Notes due 2022	800				—
	Capital lease obligations	8				8
	Total Debt	2,593				1,164
	Current maturities	—				—
	Debt, less current maturities	$	2,593			$	1,164
	____________
	(a)	Includes an unamortized premium of $5 million and $6 million as of December 31, 2014 and 2013, respectively.
Schedule of Line of Credit Facilities	As of December 31, 2014, our Revolving Credit Facility was subject to the following:
	Credit Facility		30 day Eurodollar (LIBOR) Rate		Eurodollar Margin		Base Rate	Base Rate Margin	Commitment Fee
									(unused portion)
	Revolving Credit Facility (b)		0.17%		2.75%		3.25%	1.75%	0.50%
	____________
	(b) We have the option to elect if the borrowings will bear interest at either, a base rate plus the base rate margin or a Eurodollar rate, for the applicable period, plus the Eurodollar margin at the time of the borrowing. The applicable margin varies based upon a certain leverage ratio, as defined by the Revolving Credit Facility. We also incur commitment fees for the unused portion of the Revolving Credit Facility at an annual rate. Letters of credit outstanding under the Revolving Credit Facility incur fees at the Eurodollar margin rate.
Schedule of Future Minimum Lease Payments for Capital Leases	Future minimum annual lease payments, including interest, as of December 31, 2014 for the capital lease were (in millions):
	2015	$	1
	2016	1
	2017	1
	2018	1
	2019	1
	Thereafter	7
	Total minimum lease payments	12
	Less amount representing interest	(4		)
	Capital lease obligations	$	8

Commitments_and_Contingencies_1

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule of Commitments	Future minimum annual payments applicable to all non-cancellable operating leases and purchase obligations as of December 31, 2014 are as follows (in millions):
		Payments Due by Period
		2015				2016				2017				2018				2019		Thereafter		Total
	Operating leases	$	10			$	8			$	7			$	6			$	6	$	65	$	102
	Purchase obligations	84				85				84				84				84		136		557
	Total	$	94			$	93			$	91			$	90			$	90	$	201	$	659
Environmental Liabilities	Changes in our environmental liabilities for the years ended December 31, 2014 and 2013 were as follows (in millions):
			Tioga Crude Oil Pipeline Release				Chevron Corrective Action Order				Other Liabilities				Total
	Balance at December 31, 2013		$	11			$	8			$	5			$	24
	Additions		28				—				2				30
	Expenditures		(14		)		(6		)		(2		)		(22		)
	Balance at December 31, 2014		$	25			$	2			$	5			$	32

Equity_Tables

Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Schedule Of Calculation Of Net Income Applicable To General Partners	The following table presents the allocation of the general partner’s interest in net income (in millions, except percentage of ownership interest):
		Year Ended December 31,
		2014				2013				2012
	Net income attributable to partners	$	99			$	80			$	57
	General partner’s IDRs	(41		)		(11		)		(2		)
	Special Allocation	7				—				—
	Net income available to partners	$	65			$	69			$	55
	General partner’s ownership interest	2		%		2		%		2		%
	General partner’s allocated interest in net income	$	2			$	1			$	1
	General partner’s IDRs	41				11				2
	Total general partner’s interest in net income	$	43			$	12			$	3
Schedule of Partners' Capital	The table below summarizes the changes in the number of units outstanding through December 31, 2014 (in units).
		Common			Subordinated			General Partner			Total
	Balance at December 31, 2011	15,254,890			15,254,890			622,649			31,132,429
	Units issued in the Martinez Marine Terminal Acquisition	206,362			—			4,212			210,574
	Units issued in the Long Beach Assets Acquisition	462,825			—			9,446			472,271
	Units issued in the Anacortes Rail Facility Acquisition	309,838			—			93,289			403,127
	Issuance of units in October 2012 equity offering (a)	4,255,000			—			—			4,255,000
	Unit-based compensation awards (b)	6,339			—			—			6,339
	Balance at December 31, 2012	20,495,254			15,254,890			729,596			36,479,740
	Issuance of units in January 2013 equity offering (c)	9,775,000			—			199,490			9,974,490
	Units issued for the LA Terminal Assets Acquisition	1,445,561			—			29,501			1,475,062
	Issuance of units in November 2013 equity offering (d)	6,300,000			—			—			6,300,000
	Units issued for the LA Logistics Assets Acquisition	1,126,348			—			151,695			1,278,043
	Unit-based compensation awards (b)	6,753			—			—			6,753
	Balance at December 31, 2013	39,148,916			15,254,890			1,110,282			55,514,088
	Issuance of units under ATM Program	199,400			—			—			199,400
	Issuance of units in the West Coast Logistics Assets Acquisition (e)	370,843			—			8,856			379,699
	Issuance of units in August 2014 equity offering (f)	2,100,000			—			44,000			2,144,000
	Issuance of units in October 2014 equity offering (g)	23,000,000			—			468,310			23,468,310
	Unit-based compensation awards (b)	51,881			—			—			51,881
	Subordinated unit conversion	15,254,890			(15,254,890	)		—			—
	Balance at December 31, 2014	80,125,930			—			1,631,448			81,757,378
	____________
	(a) On October 5, 2012, we closed a registered public offering of 4,255,000 common units representing limited partner interests, at a public offering price of $41.80 per unit. We used a significant portion of the net proceeds of $171 million, including the proceeds from the exercise of the underwriters’ over-allotment option, for the Anacortes Rail Facility Acquisition.
	(b) Unit-based compensation awards are presented net of 22,933, 1,306 and 654 units withheld for taxes as of December 31, 2014, 2013 and 2012, respectively.
	(c) On January 14, 2013, we closed the January 2013 Equity Offering of 9,775,000 common units representing limited partner interests, at a public offering price of $41.70 per unit. We initially used the net proceeds of $391 million, including the proceeds from the exercise of the underwriters’ over-allotment option, to make short-term liquid investments and then applied a significant portion of the proceeds to fund the Northwest Products System Acquisition. In addition, as a result of the January 2013 Equity Offering, TLGP contributed $8 million to maintain its 2% general partnership interest.
	(d) On November 22, 2013, we closed the November 2013 Equity Offering of 6,300,000 common units representing limited partner interests, at a public offering price of $51.05 per unit. We initially used the net proceeds of $310 million to make short-term liquid investments and then used the net proceeds to fund a portion of the Los Angeles Logistics Assets Acquisition.
	(e)	On July 1, 2014, we closed on the first portion of the West Coast Logistics Assets Acquisition and issued equity to Tesoro with a fair value of $27 million comprised of 370,843 common units and 8,856 general partner units.
	(f)	On August 22, 2014, we closed the August 2014 Equity Offering. We used a significant portion of the net proceeds of $142 million to redeem a portion of the 5.875% Senior Notes due 2020. TLGP contributed $3 million to maintain its 2% general partnership interest.
	(g)	On October 24, 2014, we closed a registered public offering of 23 million common units representing limited partner interests, at a public offering price of $57.47 per unit. The net proceeds of $1.3 billion include the purchase of 8,700,191 common units by Tesoro equal to $500 million and an over-allotment option exercised by the underwriters to purchase an additional 3 million common units. Concurrent with the October 2014 Equity Offering, TLGP contributed $27 million to maintain its 2% general partner interest in TLLP.
Schedule of Incentive Distributions Made to General Partners by Distribution	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under marginal percentage interest in distributions are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute, up to and including the corresponding amount in the column total quarterly distribution per unit target amount. The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. For illustrative purposes, the percentage interests set forth below for our general partner assume that there are no arrearages on common units, our general partner has contributed any additional capital necessary to maintain its 2% general partner interest and our general partner owns all of the IDRs.
		Total quarterly distribution per unit target amount			Marginal percentage interest in distributions
					Unitholders		General Partner		Incentive Distribution Rights
	Minimum Quarterly Distribution	$0.34			98%		2%		—
	First Target Distribution	Above $0.337500 up to $0.388125			98%		2%		—
	Second Target Distribution	Above $0.388125 up to $0.421875			85%		2%		13%
	Third Target Distribution	Above $0.421875 up to $0.506250			75%		2%		23%
	Thereafter	Above $0.506250			50%		2%		48%
Schedule of Distributions Made to Members or Limited Partners, by Distribution	The allocation of total quarterly cash distributions to general and limited partners is as follows for the years ended December 31, 2014, 2013 and 2012 (in millions). Our distributions are declared subsequent to quarter end; therefore, the following table represents total cash distributions applicable to the period in which the distributions are earned.
		Year Ended December 31,
		2014				2013				2012
	General partner’s distributions:
	General partner’s distributions	$	5			$	2			$	1
	General partner’s IDRs	41				11				2
	Total general partner’s distributions	$	46			$	13			$	3
	Limited partners’ distributions:
	Common	$	157			$	71			$	36
	Subordinated	14				32				26
	Total limited partners’ distributions	171				103				62
	Total Cash Distributions	$	217			$	116			$	65

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	Supplemental disclosure of non-cash activities is as follows (in millions):
		Year Ended December 31,
		2014		2013		2012
	Sponsor contributions of assets acquired to the Predecessors	$	—	$	702	$	—
	Assets received for deposit paid in prior period	—		40		—
	Capital expenditures included in accounts payable at period end	62		12		5
	Capital leases and other	4		5		4
	Predecessors’ net liabilities not assumed by Tesoro Logistics LP	1		15		2
	Receivable from affiliate for capital expenditures	3		1		—

Segment_Disclosures_Tables

Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Schedule of Segment Reporting Information, by Segment	Segment information is as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	REVENUES
	Gathering:
	Affiliate (a)	$	107		$	88		$	72
	Third-party	30			2			—
	Total Gathering	137			90			72
	Processing:
	Affiliate	7			—			—
	Third-party	16			—			—
	Total Processing	23			—			—
	Terminalling and Transportation:
	Affiliate (b)	385			185			78
	Third-party	57			38			14
	Total Terminalling and Transportation	442			223			92
	Intersegment Revenues (a)	(2		)	—			—
	Total Segment Revenues	$	600		$	313		$	164
	OPERATING INCOME
	Gathering	$	49		$	34		$	26
	Processing	4			—			—
	Terminalling and Transportation	192			57			40
	Total Segment Operating Income	245			91			66
	Unallocated general and administrative expenses	(39		)	(17		)	(9		)
	Interest and financing costs, net	(109		)	(40		)	(9		)
	Equity in earnings of unconsolidated affiliates	1			—			—
	Interest income	—			1			—
	NET INCOME	$	98		$	35		$	48
	____________
	(a)	Affiliate gathering revenues includes $2 million of intersegment revenues related to transactions between our Gathering and Processing segments for the year ended December 31, 2014, which is eliminated upon consolidation.
	(b) Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment for assets acquired in the Acquisitions from Tesoro prior to the effective date of each acquisition, except for the RCA tariffs charged to Tesoro on the refined products pipeline included in the acquisition of the West Coast Logistics Assets.
	Capital expenditures by operating segment were as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Capital Expenditures
	Gathering	$	156		$	52		$	17
	Processing	4			—			—
	Terminalling and Transportation	84			31			77
	Total Capital Expenditures	$	244		$	83		$	94
	Total identifiable assets by operating segment were as follows (in millions):
		December 31,
		2014			2013			2012
	Identifiable Assets
	Gathering	$	1,694		$	155		$	87
	Processing	1,612			—			—
	Terminalling and Transportation	1,352			1,330			233
	Other	156			48			71
	Total Identifiable Assets	$	4,814		$	1,533		$	391

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Data (Unaudited)
		Quarters
		First		Second		Third		Fourth			Total Year
	2014	(Dollars in millions, except per unit amounts)
	Total Revenues	$	127	$	133	$	150	$	190		$	600
	Operating and Maintenance Expenses	53		63		72		102			290
	Operating Income	60		48		61		37			206
	Net Income (Loss)	42		31		33		(8		)	98
	Limited partners’ interest in net income (loss)	36		26		19		(25		)	56
	Net Income (Loss) per limited partner unit (a):
	Common - basic	$	0.64	$	0.45	$	0.33	$	(0.34	)	$	0.96
	Common - diluted	$	0.64	$	0.45	$	0.33	$	(0.34	)	$	0.96
	Subordinated - basic and diluted	$	0.64	$	0.45	$	—	$	—		$	0.62
	2013
	Total Revenues	$	53	$	62	$	97	$	101		$	313
	Operating and Maintenance Expenses	23		32		60		59			174
	Operating Income	22		18		13		21			74
	Net Income	17		11		1		6			35
	Limited partners’ interest in net income	17		17		18		16			68
	Net Income per limited partner unit (a):
	Common - basic	$	0.4	$	0.38	$	0.37	$	0.33		$	1.48
	Common - diluted	$	0.4	$	0.38	$	0.37	$	0.33		$	1.47
	Subordinated - basic and diluted	$	0.37	$	0.36	$	0.37	$	0.26		$	1.35
	____________
	(a) The sum of four quarters may not equal annual results due to rounding or the quarterly number of shares outstanding.

Condensed_Consolidating_Financ1

Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Statement of Operations	Condensed Consolidating Statement of Operations
	for the Year Ended December 31, 2014
	(In millions)
		Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
	REVENUES
	Affiliate	$	6		$	484		$	7		$	—		$	497
	Third-party	—			74			29			—			103
	Total Revenues	6			558			36			—			600
	COSTS AND EXPENSES
	Operating and maintenance expenses	9			266			15			—			290
	Imbalance settlement gains and reimbursements from Tesoro	—			(43		)	—			—			(43		)
	General and administrative expenses	37			34			3			—			74
	Depreciation and amortization expenses	1			68			8			—			77
	Gain on asset disposals and impairments	—			(4		)	—			—			(4		)
	Total Costs and Expenses	47			321			26			—			394
	OPERATING INCOME (LOSS)	(41		)	237			10			—			206
	Interest and financing costs, net	(115		)	6			—			—			(109		)
	Equity in earnings of unconsolidated affiliates	—			—			1			—			1
	Equity in earnings of subsidiaries	251			—			—			(251		)	—
	NET INCOME	$	95		$	243		$	11		$	(251	)	$	98
	Loss attributable to Predecessors (a)	4			—			—			—			4
	Net income attributable to noncontrolling interest	—			—			(3		)	—			(3		)
	Net income attributable to partners	$	99		$	243		$	8		$	(251	)	$	99
Condensed Consolidating Balance Sheet	Condensed Consolidating Balance Sheet as of December 31, 2014
	(In millions)
		Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
	ASSETS
	Current Assets
	Cash and cash equivalents	$	—		$	—		$	19		$	—		$	19
	Receivables, net
	Trade	—			13			109			—			122
	Affiliate	3			52			14			—			69
	Other	—			18			—			—			18
	Prepayments and other	3			2			2			—			7
	Total Current Assets	6			85			144			—			235
	Net property, plant and equipment	1			1,569			1,736			—			3,306
	Intangibles	—			—			973			—			973
	Goodwill	—			9			155			—			164
	Investment in unconsolidated affiliates	—			—			57			—			57
	Investments in subsidiaries	4,348			—			—			(4,348		)	—
	Long-term intercompany receivable	—			307			—			(307		)	—
	Other noncurrent assets	49			7			23			—			79
	Total Assets	$	4,404		$	1,977		$	3,088		$	(4,655	)	$	4,814
	LIABILITIES AND EQUITY
	Current Liabilities
	Accounts payable
	Trade	$	6		$	57		$	63		$	—		$	126
	Affiliate	2			40			11			—			53
	Accrued interest and financing costs	28			—			—			—			28
	Other current liabilities	21			33			25			—			79
	Total Current Liabilities	57			130			99			—			286
	Long-term intercompany payable	307			—			—			(307		)	—
	Other noncurrent liabilities	—			14			31			—			45
	Debt	2,585			8			—			—			2,593
	Equity - TLLP	1,455			1,825			2,523			(4,348		)	1,455
	Equity - Noncontrolling interest	—			—			435			—			435
	Total Liabilities and Equity	$	4,404		$	1,977		$	3,088		$	(4,655	)	$	4,814
Condensed Consolidating Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows
	for the Year Ended December 31, 2014
	(In millions)
		Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
	CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
	Net cash from (used in) operating activities	$	(138	)	$	317		$	6		$	—		$	185
	CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
	Capital expenditures	(1		)	(195		)	(3		)	—			(199		)
	Acquisitions	—			—			(2,479		)	—			(2,479		)
	Investments in subsidiaries	(2,510		)	—			—			2,510			—
	Distributions to parent	15			—			(15		)	—			—
	Proceeds from sale of assets	—			10			—			—			10
	Net cash used in investing activities	(2,496		)	(185		)	(2,497		)	2,510			(2,668		)
	CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
	Proceeds from debt offering	1,300			—			—			—			1,300
	Proceeds from issuance of common units, net of issuance costs	1,449			—			—			—			1,449
	Proceeds from issuance of general partner units, net of issuance costs	29			—			—			—			29
	Distributions related to acquisitions	(243		)	—			—			—			(243		)
	Quarterly distributions to unitholders	(148		)	—			—			—			(148		)
	Quarterly distributions to general partner	(35		)										(35		)
	Repayments under revolving credit agreement	(386		)	—			—			—			(386		)
	Borrowings under revolving credit agreement	646			—			—			—			646
	Repayments of debt	(130		)	—			—			—			(130		)
	Contributions by parent	—			—			2,510			(2,510		)	—
	Intercompany borrowings (payments)	132			(132		)	—			—			—
	Sponsor contributions of equity to the Predecessors	3			—			—			—			3
	Financing costs	(32		)	—			—			—			(32		)
	Capital contributions by affiliate	26			—			—			—			26
	Net cash from (used in) financing activities	2,611			(132		)	2,510			(2,510		)	2,479
	INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(23		)	—			19			—			(4		)
	CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	23			—			—			—			23
	CASH AND CASH EQUIVALENTS, END OF YEAR	$	—		$	—		$	19		$	—		$	19

Description_of_Business_Narrat

Description of Business Narrative (Details) (USD $)

12 Months Ended

0 Months Ended

1 Months Ended

9 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Oct. 24, 2014

Nov. 22, 2013

Jan. 14, 2013

Oct. 05, 2012

Apr. 30, 2011

Sep. 30, 2014

Dec. 06, 2013

Jun. 01, 2013

Nov. 15, 2012

Apr. 02, 2012

Sep. 14, 2012

Dec. 02, 2014

Jun. 19, 2013

Oct. 19, 2014

Jul. 01, 2014

terminals

terminals

Acquisition

Number of assets (assets)

28

Percentage of revenue from Tesoro

83.00%

87.00%

91.00%

Borrowings under revolving credit agreement

$646

[1]

$794

[1]

$68

[1]

Common

Acquisition

Common units sold to the public (units)

23,000,000

6,300,000

9,775,000

4,255,000

14,950,000

Regulated Common Carrier Pipeline

Acquisition

Number of assets (assets)

1

Jet Fuel Pipeline

Acquisition

Number of assets (assets)

1

Regulated Common Carrier Refined Products Pipeline System

Acquisition

Number of assets (assets)

1

Crude Oil And Refined Products Terminals And Storage Facilities

Acquisition

Number of assets (assets)

24

Marine Terminals

Acquisition

Number of assets (assets)

4

Rail Car Unloading Facility

Acquisition

Number of assets (assets)

1

Petroleum Coke Handling And Storage Facility

Acquisition

Number of assets (assets)

1

West Coast Logistics Assets Acquisition

Acquisition

Purchase price

270

West Coast Logistics Assets Acquisition | Truck terminals

Acquisition

Number of assets (assets)

3

West Coast Logistics Assets Acquisition | Storage tanks

Acquisition

Number of assets (assets)

10

West Coast Logistics Assets Acquisition | Rail loading and unloading facilities

Acquisition

Number of assets (assets)

2

West Coast Logistics Assets Acquisition | Refined products pipeline

Acquisition

Number of assets (assets)

1

Los Angeles Logistics Assets Acquisition

Acquisition

Effective date of acquisition

6-Dec-13

Los Angeles Logistics Assets Acquisition | Marine storage terminals

Acquisition

Number of assets (assets)

1

Los Angeles Logistics Assets Acquisition | Marine Terminals

Acquisition

Number of assets (assets)

2

Los Angeles Logistics Assets Acquisition | Products terminal

Acquisition

Number of assets (assets)

1

Los Angeles Logistics Assets Acquisition | Petroleum Coke Handling And Storage Facility

Acquisition

Number of assets (assets)

1

Los Angeles Logistics Assets Acquisition | Minimum | Crude oil and refined products pipeline

Acquisition

Number of Miles

100

Los Angeles Terminal Assets Acquisition

Acquisition

Effective date of acquisition

1-Jun-13

Los Angeles Terminal Assets Acquisition | Marketing terminals

Acquisition

Number of assets (assets)

6

Anacortes Rail Facility Acquisition

Acquisition

Effective date of acquisition

15-Nov-12

Martinez Marine Terminal Acquisition

Acquisition

Effective date of acquisition

1-Apr-12

Long Beach Assets Acquisition

Acquisition

Effective date of acquisition

14-Sep-12

Rockies Natural Gas Business Acquisition

Acquisition

Effective date of acquisition

2-Dec-14

Purchase price

2,500

Northwest Products System

Acquisition

Effective date of acquisition

19-Jun-13

Purchase price

355

QEPM

Acquisition

Ownership Interest

57.80%

Limited partnership, Ownership Interest

40.00%

55.80%

Green River Processing, LLC

Acquisition

Ownership Interest

60.00%

Rendezvous Gas Services

Acquisition

Ownership Interest

78.00%

Affiliate Credit Agreement | QEPM

Acquisition

Available borrowing capacity

500

Borrowings under revolving credit agreement

$210

Maturity date

14-Aug-18

Interest rate

1.92%

[1]

Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Summary_of_Significant_Account

Summary of Significant Accounting Policies, Narrative (Details) (USD $)	12 Months Ended						0 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 02, 2014	Jun. 19, 2013
Property, Plant and Equipment
Goodwill	$164,000,000		$9,000,000	[1]
Goodwill description	The goodwill recorded represents future organic growth opportunities, anticipated synergies and intangible assets that did not qualify for separate recognition.
Pollution liability insurance deductible	2,000,000
Pollution liabilities insurance coverage loss limit	50,000,000
Debt, fair Value	2,600,000,000		1,200,000,000
Debt, carrying value	2,600,000,000		1,200,000,000
Finite-Lived intangible asset, useful life (years)	35 years
Amortization expense	2,000,000
Amortization expense, 2015	28,000,000
Amortization expense, 2016	28,000,000
Amortization expense, 2017	28,000,000
Amortization expense, 2018	28,000,000
Amortization expense, 2019	28,000,000
Asset retirement obligations	30,000,000
Amortization of deferred issuance costs	6,000,000		2,000,000
Reimbursements from Tesoro	26,000,000		4,000,000		2,000,000
Capital contributions by affiliate	26,000,000	[1]	5,000,000	[1]	6,000,000	[1]
Unit-based compensation expense	2,000,000	[1]	2,000,000	[1]	1,000,000	[1]
Units available for future grants (units)	337,342
Payout percentage for performance phantom unit awards	200.00%
Minimum
Property, Plant and Equipment
Financial instruments, outstanding term	90 days
Property, plant and equipment, estimated useful life (years)	3 years
Maximum
Property, Plant and Equipment
Cash equivalents maturity period (months)	3 months
Percent of trade payables outstanding	1.00%
Percent of trade receivables outstanding	7.00%
Property, plant and equipment, estimated useful life (years)	28 years
Rockies Natural Gas Business Acquisition
Property, Plant and Equipment
Goodwill	155,000,000
Effective date of acquisition							2-Dec-14
Asset retirement obligations	30,000,000
Northwest Products System
Property, Plant and Equipment
Goodwill			9,000,000
Effective date of acquisition								19-Jun-13
UBFS
Property, Plant and Equipment
Ownership Interest	38.00%
TRG
Property, Plant and Equipment
Ownership Interest	50.00%
Gathering | Rockies Natural Gas Business Acquisition
Property, Plant and Equipment
Goodwill	20,000,000
Processing | Rockies Natural Gas Business Acquisition
Property, Plant and Equipment
Goodwill	$135,000,000
Refined products
Property, Plant and Equipment
Percent retained for volume losses	0.25%
Refined products | Northwest Products System
Property, Plant and Equipment
Percent retained for volume losses	0.25%
Distillates | Northwest Products System
Property, Plant and Equipment
Percent retained for volume losses	0.13%
Crude oil
Property, Plant and Equipment
Percent retained for volume losses	0.20%
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Acquisitions_Rockies_Natural_G

Acquisitions Rockies Natural Gas Business Acquisition (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

In Millions, except Share data, unless otherwise specified

Oct. 24, 2014

Oct. 19, 2014

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 02, 2014

Jul. 01, 2014

Nov. 22, 2013

Jan. 14, 2013

Oct. 05, 2012

Apr. 30, 2011

Oct. 29, 2014

terminals

Acquisition

Business Acquisition, Date of Acquisition Agreement

19-Oct-14

General partnerbs ownership interest

2.00%

2.00%

2.00%

Number of assets (assets)

28

Proceeds from issuance of common units, net of issuance costs

$1,300

$1,449

[1]

$701

[1]

$171

[1]

Aggregate principal amount

1,300

Asset retirement obligations

30

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

Goodwill

164

9

[1]

Investment in unconsolidated affiliates

57

0

[1]

Fractionation Facility

Acquisition

Number of assets (assets)

1

1

Natural Gas Processing Complexes

Acquisition

Number of assets (assets)

4

Rockies Natural Gas Business Acquisition

Acquisition

Effective date of acquisition

2-Dec-14

Purchase price

2,500

Fees for alternative financing arrangement

16

Asset retirement obligations

30

Adjustments related to deferred issuance costs

8

Transaction costs

33

[2]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

Cash

31

Account receivable

117

Prepayments and other

7

Property, plant and equipment

1,735

Intangibles

976

Goodwill

155

Investment in unconsolidated affiliates

57

Other noncurrent assets

22

Accounts payable

-81

Other current liabilities

-47

Other noncurrent liabilities

-30

Noncontrolling Interest

-432

Total purchase price

2,510

Business Acquisition, Pro Forma Information

Revenues

936

689

Net Income

126

72

Net Income Attributable To Partners

106

105

Common - basic

$0.77

$1.23

Subordinated - basic and diluted

$1.13

$1.39

Business Combination, Reason for Business Combination

The acquisition aligns with TLLPbs strategies to focus on stable fee-based business, optimize existing assets, pursue organic growth and grow through acquisitions. The combined system provides a platform for growth across the crude oil and natural gas basin near existing TLLP assets. The Rockies Natural Gas Business Acquisition makes TLLP a full-service, integrated logistics company. Natural gas gathering and processing is an extension of our existing business allowing us to offer integrated crude oil and natural gas services to producers, particularly in the Bakken region.

QEPM GP

Acquisition

Limited partnership, Ownership Interest

100.00%

QEPM

Acquisition

Limited partnership, Ownership Interest

55.80%

40.00%

General partnerbs ownership interest

2.00%

Business Combination, Contingent Consideration, Liability

230

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

Investment in unconsolidated affiliates

$1,300

Common

Acquisition

Equity consideration, number of units (units)

370,843

Common units sold to the public (units)

23,000,000

6,300,000

9,775,000

4,255,000

14,950,000

[1]

Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

[2]

Costs associated with the acquisitions are included in the general and administrative expenses and interest and financing costs in our combined consolidated statements of operations.

Acquisitions_2014_Acquisitions

Acquisitions 2014 Acquisitions (Details) (USD $)	0 Months Ended	3 Months Ended								12 Months Ended						9 Months Ended	0 Months Ended
In Millions, except Share data, unless otherwise specified	Oct. 19, 2014	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Sep. 30, 2014	Jul. 01, 2014	Sep. 30, 2014
Acquisition
Business Acquisition, Date of Acquisition Agreement	19-Oct-14
Cash consideration										$243		$1,100		$419
Equity consideration, fair value																	27
Items included in Consolidated Results
Revenues		190	150	133	127	101	97	62	53	600	[1]	313	[1]	164	[1]
Total Costs and Expenses										-394	[1]	-239	[1]	-107	[1]
NET INCOME (LOSS)		-8	33	31	42	6	1	11	17	98	[1],[2]	35	[1],[2]	48	[1],[2]
Allocation of net assets acquired by the unitholders										0		0		0
West Coast Logistics Assets Acquisition
Acquisition
Business Acquisition, Date of Acquisition Agreement																23-Jun-14
Purchase price																270
Items included in Consolidated Results
Revenues										6		8		7
Total Costs and Expenses										-10		-15		-15
NET INCOME (LOSS)										-4		-7		-8
Phase One | West Coast Logistics Assets Acquisition
Acquisition
Purchase price																	241.4
Effective date of acquisition																	1-Jul-14
Cash consideration																	214.4
Equity consideration, fair value																	27
Phase Two | West Coast Logistics Assets Acquisition
Acquisition
Effective date of acquisition																		30-Sep-14
Cash consideration																		28.6
Common
Acquisition
Equity consideration, number of units (units)																	370,843
Items included in Consolidated Results
Allocation of net assets acquired by the unitholders										28		655		98
Common | Phase One | West Coast Logistics Assets Acquisition
Acquisition
Equity consideration, number of units (units)																	370,843
General Partner
Acquisition
Equity consideration, number of units (units)																	8,856
Items included in Consolidated Results
Allocation of net assets acquired by the unitholders										1		43		13
General Partner | Phase One | West Coast Logistics Assets Acquisition
Acquisition
Equity consideration, number of units (units)																	8,856
Equity of Predecessors
Items included in Consolidated Results
Allocation of net assets acquired by the unitholders										($29)		($698)	[2]	($111)	[2]
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Acquisitions_Northwest_Product

Acquisitions Northwest Products System Acquisitions (Details) (USD $)	12 Months Ended						0 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Jun. 19, 2013	Jan. 14, 2013	Mar. 18, 2014
	terminals
Acquisition
Number of assets (assets)	28
Discontinued Operations
Proceeds from sale of assets	$10	[1]	$0	[1]	$0	[1]
Gain (Loss) on Disposition of Property Plant Equipment	4	[1],[2]	0	[1],[2]	-1	[1],[2]
Northwest Products System
Acquisition
Effective date of acquisition							19-Jun-13
Purchase price							355
Advance deposit							40
Equity Instruments, Offering Date								14-Jan-13
Business Acquisition, Pro Forma Information
Revenues			327		207
Net Income			46		67
Net Income Attributable To Partners			84		68
Common - basic			$1.56		$1.59
Common - diluted			$1.56		$1.58
Subordinated - basic and diluted			$1.46		$1.49
Northwest Products System | Refined Products Terminals
Acquisition
Number of assets (assets)							3
Boise Terminal
Discontinued Operations
Disposal date									18-Mar-14
Proceeds from sale of assets									10
Gain (Loss) on Disposition of Property Plant Equipment									$5
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Acquisitions_Post_Acquisition_

Acquisitions, Post Acquisition Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Rockies Natural Gas Business Acquisition
Acquisition
Total revenues	$36
Net income attributable to partners	7
Transaction costs	33	[1]
West Coast Logistics Assets Acquisition
Acquisition
Total revenues	19
Net income attributable to partners	13
Transaction costs	$2	[1]
[1]	Costs associated with the acquisitions are included in the general and administrative expenses and interest and financing costs in our combined consolidated statements of operations.

RelatedParty_Transactions_Agre

Related-Party Transactions, Agreements (Details) (USD $)	12 Months Ended				0 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012	Jul. 01, 2014	Dec. 02, 2014	Jun. 01, 2013	Dec. 06, 2013
Related Party Transaction
Receivables from affiliate related to third-party revenues	$83		$28	$1
Other Commitments
2015, Commitment	99
2016, Commitment	99
2017, Commitment	99
2018, Commitment	99
2019, Commitment	99
Indemnification deductible	1
Commercial Agreements
Related Party Transaction
Length of time to apply shortfall payments (months)	3 months
Transportation Services Agreement (High Plains Pipeline System)
Related Party Transaction
Initiation Date	Apr-11
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Refinery Shutdown Notice Period (a) (months)	12 months	[1]
Second Amended and Restated Trucking Transportation Services Agreement (High Plains System)
Related Party Transaction
Initiation Date	Apr-11
Term (years)	5 years
Renewals, number (options)	1
Renewals, term (years)	5 years
Refinery Shutdown Notice Period (a) (months)	12 months	[1]
Second Amended and Restated Master Terminalling Services Agreement
Related Party Transaction
Initiation Date	Apr-11
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Refinery Shutdown Notice Period (a) (months)	12 months	[1]
Amended Salt Lake City Storage and Transportation Services Agreement
Related Party Transaction
Initiation Date	Apr-11
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Refinery Shutdown Notice Period (a) (months)	12 months	[1]
Amorco Terminal Use and Throughput Agreement (Martinez Marine)
Related Party Transaction
Initiation Date	Apr-12
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Refinery Shutdown Notice Period (a) (months)	12 months	[1]
Amended Anacortes Track Use and Throughput Agreement
Related Party Transaction
Initiation Date	Nov-12
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Carson Storage Services Agreement
Related Party Transaction
Initiation Date	Jun-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Amended and Restated Master Terminalling Services Agreement - Southern California
Related Party Transaction
Initiation Date	Jun-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Long Beach Storage Services Agreement
Related Party Transaction
Initiation Date	Dec-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Transportation Services Agreement (SoCal Pipelines)
Related Party Transaction
Initiation Date	Dec-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Carson Coke Handling Services Agreement
Related Party Transaction
Initiation Date	Dec-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Amended and Restated Long Beach Berth Access Use and Throughput Agreement
Related Party Transaction
Initiation Date	Dec-13	[2]
Term (years)	10 years	[2]
Renewals, number (options)	2	[2]
Renewals, term (years)	5 years	[2]
Term of modification option (years)	20 years	[2]
Long Beach Berth Throughput Agreement
Related Party Transaction
Initiation Date	Dec-13	[2]
Term (years)	10 years	[2]
Renewals, number (options)	2	[2]
Renewals, term (years)	5 years	[2]
Term of modification option (years)	20 years	[2]
Long Beach Pipeline Throughput Agreement
Related Party Transaction
Initiation Date	Dec-13
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Terminalling Services Agreement - Nikiski
Related Party Transaction
Initiation Date	Jul-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Terminalling Services Agreement - Anacortes
Related Party Transaction
Initiation Date	Jul-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Terminalling Services Agreement - Martinez
Related Party Transaction
Initiation Date	Jul-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Storage Services Agreement - Anacortes
Related Party Transaction
Initiation Date	Jul-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Martinez Dedicated LPG Storage Agreement
Related Party Transaction
Initiation Date	Jul-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Tesoro Alaska Pipeline Throughput Agreement
Related Party Transaction
Initiation Date	Sep-14
Term (years)	10 years
Renewals, number (options)	2
Renewals, term (years)	5 years
Third Amended and Restated Omnibus Agreement
Other Commitments
Amendment date	1-Jul-14
Omnibus agreement annual fee	6
Indemnification deductible	1
Construction Agreement
Other Commitments
Operational services fee					23
Effective date of acquisition					1-Jul-14
Keep-Whole Commodity Agreement
Related Party Transaction
Term (years)						5 years
Secondment and Logistics Services Agreement
Other Commitments
Operational services fee	$5
Los Angeles Terminal Assets Acquisition
Other Commitments
Years to identify conditions after the date of purchase (years)	5 years
Effective date of acquisition							1-Jun-13
Rockies Natural Gas Business Acquisition
Other Commitments
Effective date of acquisition						2-Dec-14
Los Angeles Logistics Assets Acquisition
Other Commitments
Years to identify conditions after the date of purchase (years)	10 years
Effective date of acquisition								6-Dec-13
Phase One | West Coast Logistics Assets Acquisition
Other Commitments
Effective date of acquisition					1-Jul-14
[1]	Fixed minimum volumes remain in effect during routine turnarounds.
[2]	Agreement gives Tesoro the option to renew for two five-year terms, or Tesoro may modify the term of the agreements to a twenty-year term by providing notice in accordance with each agreement.

RelatedParty_Transactions_Summ

Related-Party Transactions, Summary of Transactions (Details) (USD $)	12 Months Ended						0 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Jan. 22, 2015
Subsequent Event
Imbalance settlement gains	($17)		($8)		($10)
Cash distribution paid to Tesoro	171		103		62
Revenues	497	[1]	273	[1]	150	[1]
Operating and maintenance expenses	77	[2]	71	[2]	28	[2]
Imbalance settlement gains and reimbursement from Tesoro	-43	[1]	-12	[1]	-12	[1]
General and administrative expenses	39		20		13
Reimbursements from Tesoro	26		4		2
Quarterly cash distributions paid to Tesoro	87		44		27
Quarterly cash distribution
Subsequent Event
Declaration date							22-Jan-15
Cash distributions paid per unit							$0.67
Cash distribution paid to Tesoro							$35
Date of distribution							13-Feb-15
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Includes imbalance settlement gains of $17 million, $8 million and $10 million in the years ended DecemberB 31, 2014, 2013 and 2012, respectively. Also includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement of $26 million, $4 million and $2 million in the years ended DecemberB 31, 2014, 2013 and 2012, respectively.

Net_Income_Per_Unit_Details

Net Income Per Unit (Details) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Earnings Per Share, Basic, by Common Class, Including Two Class Method
Net income attributable to partners																	$99	[1]	$80	[1]	$57	[1]
Special allocation of net income																	7	[2]	0	[2]	0	[2]
Net income attributable to partners, excluding Special Allocation																	106		80		57
General partnerbs distributions (including IDRs)																	-46	[3]	-13	[3]	-3	[3]
Distributions (including IDRs)																	46	[3]	13	[3]	3	[3]
Special allocation																	-7	[2]	0	[2]	0	[2]
Allocation of distributions greater than earnings																	-111		-36		-8
Weighted average limited partner units outstanding:
Common units - basic (units)																	54,203,508		31,545,935		16,614,668
Common unit equivalents																	45,908		72,499		94,282
Common units - diluted (units)																	54,249,416		31,618,434		16,708,950
Subordinated units - basic and diluted (units)																	5,642,220	[4]	15,254,890	[4]	15,254,890	[4]
Net income per limited partner unit:
Common - basic																	$0.96		$1.48		$1.90
Common - diluted																	$0.96		$1.47		$1.89
Subordinated - basic and diluted (dollars per unit)	$0	[5]	$0	[5]	$0.45	[5]	$0.64	[5]	$0.26	[5]	$0.37	[5]	$0.36	[5]	$0.37	[5]	$0.62	[5]	$1.35	[5]	$1.47
Footnote
General partnerbs ownership interest																	2.00%		2.00%		2.00%
Maximum percentage distribution to general partner																	50.00%
Minimum distribution level for IDRs																	0.388125
Subordinated units effective conversion date																	16-May-14
Subordinated units converted in common units																	0
General Partner
Earnings Per Share, Basic, by Common Class, Including Two Class Method
Net income attributable to partners																			12		3
General partnerbs distributions (including IDRs)																	-46	[3]	-13	[3]	-3	[3]
Distributions (including IDRs)																	46	[3]	13	[3]	3	[3]
Allocation of distributions greater than earnings																	-3		-1		0
Total partnerbs earnings																	43		12		3
Footnote
Subordinated units converted in common units																	0
Limited Partner, Common Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method
Net income attributable to partners																			46		28
Special allocation of net income																	7	[2]	0	[2]	0	[2]
Limited partnersb distributions																	157		71		36
Special allocation																	-7	[2]	0	[2]	0	[2]
Allocation of distributions greater than earnings																	-98		-23		-4
Total partnerbs earnings																	52		48		32
Footnote
Subordinated units converted in common units																	15,254,890
Limited Partner, Subordinated units
Earnings Per Share, Basic, by Common Class, Including Two Class Method
Net income attributable to partners																			22		26
Limited partnersb distributions																	14	[4]	32	[4]	26	[4]
Allocation of distributions greater than earnings																	-10	[4]	-12	[4]	-4	[4]
Total partnerbs earnings																	$4	[4]	$20	[4]	$22	[4]
Footnote
Subordinated units converted in common units																	-15,254,890
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to TLGP common unitholders for the premium paid in connection with the redemption of the senior notes due 2020.
[3]	General partnerbs distributions (including IDRs) consist of the 2% general partner interest and IDRs, which entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. See Note 12 for further discussion related to IDRs.
[4]	On MayB 16, 2014, the 15,254,890 subordinated units were converted into common units on a one-for-one basis and thereafter participate on terms equal with all other common units in distributions of available cash. Distributions and the Partnershipbs net income were allocated to the subordinated units through MayB 15, 2014.
[5]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of shares outstanding.

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Property, Plant and Equipment
Property, Plant and Equipment	$3,551	$1,569
Accumulated depreciation	-245	-171
Net Property, Plant and Equipment	3,306	1,398	[1]
Capitalized interest	6	2		1
Depreciation expense	75	45		15
Gathering
Property, Plant and Equipment
Property, Plant and Equipment	1,507	172
Processing
Property, Plant and Equipment
Property, Plant and Equipment	539	0
Terminalling and Transportation
Property, Plant and Equipment
Property, Plant and Equipment	1,478	1,397
Other
Property, Plant and Equipment
Property, Plant and Equipment	$27	$0
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Investment_in_Unconsolidated_A1

Investment in Unconsolidated Affiliates Uintah Basin Field Services, LLC (bUBFSb) and Three Rivers Gathering (bTRGb), LLC Joint Ventures Narrative (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Equity Method Investments
Investment in unconsolidated affiliates	$57	$0	[1]
UBFS
Equity Method Investments
Ownership Interest	38.00%
Investment in unconsolidated affiliates	18
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	7
TRG
Equity Method Investments
Ownership Interest	50.00%
Investment in unconsolidated affiliates	39
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	$15
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Other_Current_Liabilities_Deta

Other Current Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Other Liabilities, Current [Abstract]
Legal	$21	$0
Accrued environmental liabilities	13	20
Other	45	10
Total Other Current Liabilities	$79	$30	[1]
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Benefit_Plans_Details

Benefit Plans (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Benefit Plans [Abstract]
Employee benefit plan expenses	$13	$9	$4

Major_Customer_and_Concentrati1

Major Customer and Concentrations of Credit Risk (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Major Customer and Concentrations of Credit Risk [Abstract]
Percentage of revenue from Tesoro	83.00%	87.00%	91.00%

Debt_Total_Details

Debt, Total (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument
Revolving Credit Facility	$260		$0
Capital lease obligations	8		8
Total Debt	2,593		1,164
Current maturities	0		0
Debt, less current maturities	2,593		1,164	[1]
Aggregate maturities of debt due in 2017	1
Aggregate maturities of debt due in 2018	1
Aggregate maturities of debt due in 2019	761
5.500% Senior Notes Due 2019
Debt Instrument
Senior Notes	500		0
5.875% Senior Notes due 2020
Debt Instrument
Senior Notes	475	[2]	606	[2]
Unamortized Premium	5		6
6.125% Senior Notes due 2021
Debt Instrument
Senior Notes	550		550
6.250% Senior Notes Due 2022
Debt Instrument
Senior Notes	$800		$0
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Includes an unamortized premium of $5 million and $6 million as of December 31, 2014 and 2013, respectively.

Debt_Revolver_and_Senior_Notes

Debt, Revolver and Senior Notes (Details) (USD $)

0 Months Ended

12 Months Ended

Aug. 22, 2014

Nov. 22, 2013

Jan. 14, 2013

Oct. 05, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2014

Oct. 29, 2014

Dec. 17, 2013

Sep. 12, 2013

Aug. 01, 2013

Line of Credit Facility

Amount outstanding

$0

$260,000,000

Senior Notes

Aggregate principal amount

1,300,000,000

Net proceeds from issuance of units (dollars)

142,000,000

310,000,000

391,000,000

171,000,000

709,000,000

171,000,000

Revolving Credit Facility

Line of Credit Facility

Available borrowing capacity

900,000,000

Maximum borrowing capacity

1,500,000,000

Amount outstanding

260,000,000

Unused credit availability

640,000,000

Remaining percentage of eligible borrowing base

71.00%

credit facility, weighted average interest rate

2.92%

Maturity date

2-Dec-19

Collateral, Revolving Credit Facility

Our Revolving Credit Facility is non-recourse to Tesoro, except for TLGP, and is guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas, and secured by substantially all of our assets.

Borrowing capacity, description

Borrowings are available under the Revolving Credit Facility up to the total loan availability of the facility.

Commitment Fee (unused portion)

0.50%

[1]

Revolving Credit Facility | Eurodollar

Debt Instrument, Redemption [Line Items]

Reference Rate Percent

0.17%

[1]

Line of Credit Facility

Eurodollar or Base Rate Margin

2.75%

[1]

Revolving Credit Facility | Base Rate

Debt Instrument, Redemption [Line Items]

Reference Rate Percent

3.25%

[1]

Line of Credit Facility

Eurodollar or Base Rate Margin

1.75%

[1]

5.500% Senior Notes Due 2019

Senior Notes

Aggregate principal amount

500,000,000

Interest rate

5.50%

Maturity date

15-Oct-19

Collateral, Senior Notes

The 2019 Senior Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas and Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

5.875% Senior Notes due 2020

Senior Notes

Aggregate principal amount

250,000,000

350,000,000

Interest rate

5.88%

Maturity date

1-Oct-20

Redemption premium, percentage of face value

102.25%

Redemption, price, percentage of principal amount

5.33%

Collateral, Senior Notes

The 2020 Senior Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and any subsidiaries acquired with the Rockies Natural Gas Business Acquisition, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

Repayments of Long-term Debt

130,000,000

Accrued interest

4,000,000

Debt Instrument Premium Paid Above Par

7,000,000

Write off of unamortized debt issuance cost

3,000,000

6.125% Senior Notes due 2021

Senior Notes

Aggregate principal amount

550,000,000

Interest rate

6.13%

Maturity date

15-Oct-21

Collateral, Senior Notes

The 2021 Senior Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer and any subsidiaries acquired with the Rockies Natural Gas Business Acquisition, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

6.250% Senior Notes Due 2022

Senior Notes

Aggregate principal amount

$800,000,000

Interest rate

6.25%

Maturity date

15-Oct-22

Collateral, Senior Notes

The 2022 Senior Notes are unsecured and guaranteed by all of our consolidated subsidiaries, with the exception of Rendezvous Gas and Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

Debt Instrument, Redemption Period One | 5.875% Senior Notes due 2020

Senior Notes

Redemption premium, percentage of face value

105.88%

Redemption, price, percentage of principal amount

35.00%

Debt Instrument, Redemption Period One | 6.125% Senior Notes due 2021

Senior Notes

Redemption premium, percentage of face value

106.13%

Redemption, price, percentage of principal amount

35.00%

Debt Instrument, Redemption Period One | 6.250% Senior Notes Due 2022

Senior Notes

Redemption premium, percentage of face value

3.13%

Debt Instrument, Redemption Period Two | 5.875% Senior Notes due 2020

Senior Notes

Redemption premium, percentage of face value

2.94%

Debt Instrument, Redemption Period Two | 6.125% Senior Notes due 2021

Senior Notes

Redemption premium, percentage of face value

4.59%

Debt Instrument, Redemption Period Two | 6.250% Senior Notes Due 2022

Senior Notes

Redemption premium, percentage of face value

1.56%

Debt Instrument, Redemption, Period Three | 5.875% Senior Notes due 2020

Senior Notes

Redemption premium, percentage of face value

1.47%

Debt Instrument, Redemption, Period Three | 6.125% Senior Notes due 2021

Senior Notes

Redemption premium, percentage of face value

3.06%

Debt Instrument, Redemption, Period Three | 6.250% Senior Notes Due 2022

Senior Notes

Redemption premium, percentage of face value

106.25%

Redemption, price, percentage of principal amount

35.00%

Debt Instrument, Redemption Period Four | 6.125% Senior Notes due 2021

Senior Notes

Redemption premium, percentage of face value

1.53%

[1]

We have the option to elect if the borrowings will bear interest at either, a base rate plus the base rate margin or a Eurodollar rate, for the applicable period, plus the Eurodollar margin at the time of the borrowing. The applicable margin varies based upon a certain leverage ratio, as defined by the Revolving Credit Facility. We also incur commitment fees for the unused portion of the Revolving Credit Facility at an annual rate. Letters of credit outstanding under the Revolving Credit Facility incur fees at the Eurodollar margin rate.

Debt_Capital_Lease_Details

Debt, Capital Lease (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Capital Leased Assets
Capital lease renewal option	5 years
Total cost of assets under capital lease	$9
Capital Leases, accumulated amortization	1
2015	1
2016	1
2017	1
2018	1
2019	1
Thereafter	7
Total minimum lease payments	12
Less amount representing interest	-4
Capital lease obligations	$8	$8
Capital Lease Obligations
Capital Leased Assets
Capital lease initial term	15 years
Right Of Way
Capital Leased Assets
Capital lease initial term	31 years

Commitments_and_Contingencies_2

Commitments and Contingencies, Commitments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Leases
Site Contingency, Accrual, Assumptions	Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible these estimates will change as additional information becomes available.
Total operating lease expense	$8	$6	$4
Operating Leases
Operating leases due 2015	10
Operating leases due 2016	8
Operating leases due 2017	7
Operating leases due 2018	6
Operating leases due 2019	6
Operating leases due Thereafter	65
Operating leases Total	102
Purchase Obligations
Purchase obligations due 2015	84
Purchase obligations due 2016	85
Purchase obligations due 2017	84
Purchase obligations due 2018	84
Purchase obligations due 2019	84
Purchase obligations due Thereafter	136
Purchase obligations Total	557
Total Contractual Obligation
Total due 2015	94
Total due 2016	93
Total due 2017	91
Total due 2018	90
Total due 2019	90
Total due Thereafter	201
Total	659
Total service agreement expense	117	56	28
Contractual Obligation	$94
Maximum
Operating Leases
Remaining term of Operating leases (years)	20 years
2013 Acquisitions from Tesoro
Operating Leases
Years to identify conditions after the date of purchase (years)	5 years

Commitments_and_Contingencies_3

Commitments and Contingencies (Details) (USD $)	12 Months Ended	24 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	1-May-12	Dec. 31, 2012	Jan. 30, 2014
Changes in Environmental Loss Contingency
Balance at beginning of year	$24
Additions	30
Expenditures	-22
Balance at end of year	32	32
Aggregate annual deductible	1	1
Environmental liability insurance deductible	2	2
Environmental liabilities insurance coverage limit	50
Site Contingency, Accrual, Assumptions	Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible these estimates will change as additional information becomes available.
Tioga Crude Oil Pipeline Release
Changes in Environmental Loss Contingency
Balance at beginning of year	11
Additions	28
Expenditures	-14
Balance at end of year	25	25
Insurance settlement receivable	18	18	14
Environmental liability insurance deductible	1	1
Environmental liabilities insurance coverage limit	25
Excess remediation costs over loss limit	17
Proceeds from Insurance Settlement		7
Chevron Corrective Action Order
Changes in Environmental Loss Contingency
Balance at beginning of year	8
Additions	0
Expenditures	-6
Balance at end of year	2	2	8
Diesel Pipeline Release detection and response date			18-Mar-13
Other Liabilities
Changes in Environmental Loss Contingency
Balance at beginning of year	5
Additions	2
Expenditures	-2
Balance at end of year	5	5
PHMSA | Chevron Corrective Action Order
Changes in Environmental Loss Contingency
Regulatory action issuance date			22-Mar-13
Department Of Environmental Quality Division Of Water | Chevron Corrective Action Order
Changes in Environmental Loss Contingency
Regulatory action issuance date			11-Apr-13
Los Angeles Logistics Assets Acquisition
Changes in Environmental Loss Contingency
Years to identify conditions after the date of purchase (years)	10 years
Los Angeles Terminal Assets Acquisition
Changes in Environmental Loss Contingency
Years to identify conditions after the date of purchase (years)	5 years
Northwest Products System
Changes in Environmental Loss Contingency
Balance at end of year	4	4	5
Questar Gas Company v. QEP Field Services Company
Changes in Environmental Loss Contingency
Complaint filing date				1-May-12
Disputed amount netted from gathering fees					14
Liability for estimated damages	$21	$21
XTO Energy Inc. v. QEP Field Services Company
Changes in Environmental Loss Contingency
Complaint filing date						30-Jan-14

Equity_Equity_Subordinated_Uni

Equity Equity, Subordinated Unit Conversion and ATM Program (Details) (USD $)	0 Months Ended				12 Months Ended
In Millions, except Share data, unless otherwise specified	Aug. 22, 2014	Nov. 22, 2013	Jan. 14, 2013	Oct. 05, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Subordinated units effective conversion date					16-May-14
Common units outstanding (units)					80,125,930	39,148,916
General partner units issued or outstanding (units)					1,631,448	1,110,282
General partnerbs ownership interest					2.00%	2.00%	2.00%
Partners' Capital Account, Units					81,757,378	55,514,088	36,479,740	31,132,429
Equity instrument regulatory filing date					25-Jun-14
Common units, aggregate value					$200
Net proceeds from issuance of units (dollars)	142	310	391	171		709	171
Public-owned common units
Common units outstanding (units)					51,944,182
Tesoro-owned common units
Common units outstanding (units)					28,181,748
General Partner
General partner units issued or outstanding (units)					1,631,448
Partners' Capital Account, Units					1,631,448	1,110,282	729,596	622,649
Net proceeds from issuance of units (dollars)						8	0
Limited Partner, Subordinated units
Partners' Capital Account, Units					0	15,254,890	15,254,890	15,254,890
Net proceeds from issuance of units (dollars)						-9	-3
Tesoro
Limited partnership, Ownership Interest					36.50%
ATM Program
Units issued in equity offering					199,400
Net proceeds from issuance of units (dollars)					$14
ATM Program | General Partner
Units issued in equity offering					0
ATM Program | Limited Partner, Subordinated units
Units issued in equity offering					0

Equity_Allocations_of_Net_Inco

Equity, Allocations of Net Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Net Income Allocation
Net income attributable to partners	$99	[1]	$80	[1]	$57	[1]
General partnerbs IDRs	-41		-11		-2
Special Allocation	7	[2]	0	[2]	0	[2]
Net income available to partners	65		69		55
General partnerbs ownership interest	2.00%		2.00%		2.00%
Total general partnerbs interest in net income	-43	[1]	-12	[1]	-3	[1]
General Partner
Net Income Allocation
Net income attributable to partners			12		3
General partnerbs IDRs	-41		-11		-2
General partnerbs allocated interest in net income	2		1		1
Total general partnerbs interest in net income	$43		$12		$3
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Normal allocations according to percentage interests are made after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions fully allocated to the general partner and any special allocations. The adjustment reflects the special allocation to TLGP common unitholders for the premium paid in connection with the redemption of the senior notes due 2020.

Equity_Units_Rollforward_Detai

Equity, Units Rollforward (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

In Millions, except Share data, unless otherwise specified

Oct. 24, 2014

Aug. 22, 2014

Nov. 22, 2013

Jan. 14, 2013

Oct. 05, 2012

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Jul. 01, 2014

Apr. 30, 2011

Partners' Capital, Units

Balance at period beginning

55,514,088

36,479,740

31,132,429

Unit-based compensation awards

51,881

[1]

6,753

[1]

6,339

[1]

Subordinated units converted

0

Balance at period end

81,757,378

55,514,088

36,479,740

Price per unit (dollars per unit)

$57.47

$51.05

$41.70

$41.80

Net proceeds from issuance of units (dollars)

$142

$310

$391

$171

$709

$171

General partnerbs ownership interest

2.00%

2.00%

2.00%

Proceeds from issuance of common units, net of issuance costs

1,300

1,449

[2]

701

[2]

171

[2]

Amount contributed for general partner units

8

General partner units issued or outstanding (units)

1,631,448

1,110,282

Equity Instruments Conversion Date

16-May-14

Equity instrument regulatory filing date

25-Jun-14

Common units, aggregate value

200

Equity consideration, value

27

Proceeds from Issuance or Sale of Equity

29

[2]

8

[2]

0

[2]

Common

Partners' Capital, Units

Balance at period beginning

39,148,916

20,495,254

15,254,890

Unit-based compensation awards

51,881

[1]

6,753

[1]

6,339

[1]

Subordinated units converted

15,254,890

Balance at period end

80,125,930

39,148,916

20,495,254

Common units sold to the public (units)

23,000,000

6,300,000

9,775,000

4,255,000

14,950,000

Net proceeds from issuance of units (dollars)

710

174

Number of units withheld for taxes

22,933

1,306

654

Equity consideration, number of units (units)

370,843

Tesoro-owned common units

Partners' Capital, Units

Units issued in the acquisitions

8,700,191

Proceeds from issuance of common units, net of issuance costs

500

Option on Securities

Partners' Capital, Units

Common units sold to the public (units)

3,000,000

Subordinated

Partners' Capital, Units

Balance at period beginning

15,254,890

15,254,890

15,254,890

Unit-based compensation awards

0

[1]

0

[1]

0

[1]

Subordinated units converted

-15,254,890

Balance at period end

0

15,254,890

15,254,890

Net proceeds from issuance of units (dollars)

-9

-3

General Partner

Partners' Capital, Units

Balance at period beginning

1,110,282

729,596

622,649

Unit-based compensation awards

0

[1]

0

[1]

0

[1]

Subordinated units converted

0

Balance at period end

1,631,448

1,110,282

729,596

Net proceeds from issuance of units (dollars)

8

0

General partner units issued or outstanding (units)

1,631,448

Equity consideration, number of units (units)

8,856

Proceeds from Issuance or Sale of Equity

27

3

Tesoro

Partners' Capital, Units

Limited partnership, Ownership Interest

36.50%

October 2012 Equity Offering

Partners' Capital, Units

Units issued in equity offering

4,255,000

[3]

October 2012 Equity Offering | Common

Partners' Capital, Units

Units issued in equity offering

4,255,000

[3]

October 2012 Equity Offering | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

[3]

October 2012 Equity Offering | General Partner

Partners' Capital, Units

Units issued in equity offering

0

[3]

January 2013 Equity Offering

Partners' Capital, Units

Units issued in equity offering

9,974,490

[4]

January 2013 Equity Offering | Common

Partners' Capital, Units

Units issued in equity offering

9,775,000

[4]

January 2013 Equity Offering | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

[4]

January 2013 Equity Offering | General Partner

Partners' Capital, Units

Units issued in equity offering

199,490

[4]

November 2013 Equity Offering

Partners' Capital, Units

Units issued in equity offering

6,300,000

[5]

November 2013 Equity Offering | Common

Partners' Capital, Units

Units issued in equity offering

6,300,000

[5]

November 2013 Equity Offering | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

[5]

November 2013 Equity Offering | General Partner

Partners' Capital, Units

Units issued in equity offering

0

[5]

ATM Program

Partners' Capital, Units

Units issued in equity offering

199,400

Net proceeds from issuance of units (dollars)

$14

ATM Program | Common

Partners' Capital, Units

Units issued in equity offering

199,400

ATM Program | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

ATM Program | General Partner

Partners' Capital, Units

Units issued in equity offering

0

August 2014 Equity Offering

Partners' Capital, Units

Units issued in equity offering

2,144,000

[6]

August 2014 Equity Offering | Common

Partners' Capital, Units

Units issued in equity offering

2,100,000

[6]

August 2014 Equity Offering | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

[6]

August 2014 Equity Offering | General Partner

Partners' Capital, Units

Units issued in equity offering

44,000

[6]

October 2014 Equity Offering

Partners' Capital, Units

Units issued in equity offering

23,468,310

[7]

October 2014 Equity Offering | Common

Partners' Capital, Units

Units issued in equity offering

23,000,000

[7]

October 2014 Equity Offering | Subordinated

Partners' Capital, Units

Units issued in equity offering

0

[7]

October 2014 Equity Offering | General Partner

Partners' Capital, Units

Units issued in equity offering

468,310

[7]

5.875% Senior Notes due 2020

Partners' Capital, Units

Interest rate

5.88%

Maturity date

1-Oct-20

Martinez Marine Terminal Acquisition

Partners' Capital, Units

Units issued in the acquisitions

210,574

Martinez Marine Terminal Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

206,362

Martinez Marine Terminal Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

Martinez Marine Terminal Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

4,212

Long Beach Assets Acquisition

Partners' Capital, Units

Units issued in the acquisitions

472,271

Long Beach Assets Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

462,825

Long Beach Assets Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

Long Beach Assets Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

9,446

Anacortes Rail Facility Acquisition

Partners' Capital, Units

Units issued in the acquisitions

403,127

Anacortes Rail Facility Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

309,838

Anacortes Rail Facility Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

Anacortes Rail Facility Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

93,289

Los Angeles Terminal Assets Acquisition

Partners' Capital, Units

Units issued in the acquisitions

1,475,062

Los Angeles Terminal Assets Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

1,445,561

Los Angeles Terminal Assets Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

Los Angeles Terminal Assets Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

29,501

Los Angeles Logistics Assets Acquisition

Partners' Capital, Units

Units issued in the acquisitions

1,278,043

Los Angeles Logistics Assets Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

1,126,348

Los Angeles Logistics Assets Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

Los Angeles Logistics Assets Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

151,695

West Coast Logistics Assets Acquisition

Partners' Capital, Units

Units issued in the acquisitions

379,699

[8]

West Coast Logistics Assets Acquisition | Common

Partners' Capital, Units

Units issued in the acquisitions

370,843

[8]

West Coast Logistics Assets Acquisition | Subordinated

Partners' Capital, Units

Units issued in the acquisitions

0

[8]

West Coast Logistics Assets Acquisition | General Partner

Partners' Capital, Units

Units issued in the acquisitions

8,856

[8]

[1]

Unit-based compensation awards are presented net of 22,933, 1,306 and 654 units withheld for taxes as of December 31, 2014, 2013 and 2012, respectively.

[2]

Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

[3]

On October 5, 2012, we closed a registered public offering of 4,255,000 common units representing limited partner interests, at a public offering price of $41.80 per unit. We used a significant portion of the net proceeds of $171 million, including the proceeds from the exercise of the underwritersb over-allotment option, for the Anacortes Rail Facility Acquisition.

[4]

On January 14, 2013, we closed the January 2013 Equity Offering of 9,775,000 common units representing limited partner interests, at a public offering price of $41.70 per unit. We initially used the net proceeds of $391 million, including the proceeds from the exercise of the underwritersb over-allotment option, to make short-term liquid investments and then applied a significant portion of the proceeds to fund the Northwest Products System Acquisition. In addition, as a result of the January 2013 Equity Offering, TLGP contributed $8 million to maintain its 2% general partnership interest.

[5]

On NovemberB 22, 2013, we closed the November 2013 Equity Offering of 6,300,000 common units representing limited partner interests, at a public offering price of $51.05 per unit. We initially used the net proceeds of $310 million to make short-term liquid investments and then used the net proceeds to fund a portion of the Los Angeles Logistics Assets Acquisition.

[6]

On AugustB 22, 2014, we closed the August 2014 Equity Offering. We used a significant portion of the net proceeds of $142 million to redeem a portion of the 5.875% Senior Notes due 2020. TLGP contributed $3 million to maintain its 2% general partnership interest.

[7]

On OctoberB 24, 2014, we closed a registered public offering of 23 million common units representing limited partner interests, at a public offering price of $57.47 per unit. The net proceeds of $1.3 billion include the purchase of 8,700,191 common units by Tesoro equal to $500 million and an over-allotment option exercised by the underwriters to purchase an additional 3 million common units. Concurrent with the October 2014 Equity Offering, TLGP contributed $27 million to maintain its 2% general partner interest in TLLP.

[8]

On JulyB 1, 2014, we closed on the first portion of the West Coast Logistics Assets Acquisition and issued equity to Tesoro with a fair value of $27 million comprised of 370,843 common units and 8,856 general partner units.

Equity_Incentive_Distribution_

Equity, Incentive Distribution Rights (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Incentive Distribution Rights
General partnerbs ownership interest	2.00%	2.00%	2.00%
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	50.00%
Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner
Total quarterly distribution per unit target amount (dollars per unit)	0.3375
Minimum Quarterly Distribution | Unitholders
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	98.00%
Minimum Quarterly Distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	2.00%
Minimum Quarterly Distribution | Incentive Distribution Rights
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	0.00%
First Target Distribution
Incentive Distribution Made to Managing Member or General Partner
Total quarterly distribution per unit target amount (dollars per unit)	Above $0.337500 up to $0.388125
First Target Distribution | Unitholders
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	98.00%
First Target Distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	2.00%
First Target Distribution | Incentive Distribution Rights
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	0.00%
Second Target Distribution
Incentive Distribution Made to Managing Member or General Partner
Total quarterly distribution per unit target amount (dollars per unit)	Above $0.388125 up to $0.421875
Second Target Distribution | Unitholders
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	85.00%
Second Target Distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	2.00%
Second Target Distribution | Incentive Distribution Rights
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	13.00%
Third Target Distribution
Incentive Distribution Made to Managing Member or General Partner
Total quarterly distribution per unit target amount (dollars per unit)	Above $0.421875 up to $0.506250
Third Target Distribution | Unitholders
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	75.00%
Third Target Distribution | General Partner
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	2.00%
Third Target Distribution | Incentive Distribution Rights
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	23.00%
Thereafter
Incentive Distribution Made to Managing Member or General Partner
Total quarterly distribution per unit target amount (dollars per unit)	Above $0.506250
Thereafter | Unitholders
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	50.00%
Thereafter | General Partner
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	2.00%
Thereafter | Incentive Distribution Rights
Incentive Distribution Made to Managing Member or General Partner
Marginal percentage interest in distributions	48.00%

Equity_Cash_Distributions_Deta

Equity, Cash Distributions (Details) (USD $)	0 Months Ended	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jan. 22, 2015	Dec. 31, 2014
Quarterly cash distribution
Distribution Made to Member or Limited Partner
Declaration date	22-Jan-15
Total Cash Distributions	$70
Cash distributions paid per unit	$0.67
Date of distribution	13-Feb-15
Unitholders record date	2-Feb-15
Rockies Natural Gas Business Acquisition
Distribution Made to Member or Limited Partner
General partner distributions forfeited		($10)

Equity_Distributions_Earned_De

Equity, Distributions Earned (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Distributions Earned By Limited Or General Partners
General partnerbs distributions	$5		$2		$1
General partnerbs IDRs	41		11		2
Total general partnerbs distributions	46	[1]	13	[1]	3	[1]
Limited partners' distributions	171		103		62
Total Cash Distributions	217		116		65
General Partner
Distributions Earned By Limited Or General Partners
General partnerbs IDRs	41		11		2
Total general partnerbs distributions	46	[1]	13	[1]	3	[1]
Common
Distributions Earned By Limited Or General Partners
Limited partners' distributions	157		71		36
Subordinated
Distributions Earned By Limited Or General Partners
Limited partners' distributions	$14		$32		$26
[1]	General partnerbs distributions (including IDRs) consist of the 2% general partner interest and IDRs, which entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. See Note 12 for further discussion related to IDRs.

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information Supplemental Cash Flow Information Narrative (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Additional Information
Interest Paid, Net	$73	$23	$2

Supplemental_Cash_Flow_Informa3

Supplemental Cash Flow Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Elements [Abstract]
Sponsor contributions of assets acquired to the Predecessors	$0	$702	$0
Assets received for deposit paid in prior period	0	40	0
Capital expenditures included in accounts payable at period end	62	12	5
Capital leases and other	4	5	4
Predecessorsb net liabilities not assumed by Tesoro Logistics LP	1	15	2
Receivable from affiliate for capital expenditures	$3	$1	$0

Segment_Disclosures_Narrative_

Segment Disclosures, Narrative Information (Details)	12 Months Ended	0 Months Ended
	Dec. 31, 2014	Oct. 19, 2014	Dec. 02, 2014
	segments		facility
	terminals
Segment Reporting Information
Number of operating segments (segments)	3
Number of assets (assets)	28
Segment reporting, foreign operations	We do not have any foreign operations.
Crude Oil Gathering System
Segment Reporting Information
Number of assets (assets)	1
Gas Processing Complexes
Segment Reporting Information
Number of assets (assets)	2
Fractionation Facility
Segment Reporting Information
Number of assets (assets)	1		1
Crude Oil And Refined Products Terminals And Storage Facilities
Segment Reporting Information
Number of assets (assets)	24
Marine Terminals
Segment Reporting Information
Number of assets (assets)	4
Rail Car Unloading Facility
Segment Reporting Information
Number of assets (assets)	1
Regulated Common Carrier Pipeline
Segment Reporting Information
Number of assets (assets)	1
Jet Fuel Pipeline
Segment Reporting Information
Number of assets (assets)	1
Petroleum Coke Handling And Storage Facility
Segment Reporting Information
Number of assets (assets)	1
Regulated common carrier refined products pipeline system
Segment Reporting Information
Number of assets (assets)	1
Green River Processing, LLC
Segment Reporting Information
Ownership Interest	60.00%
QEPM
Segment Reporting Information
Limited partnership, Ownership Interest	40.00%	55.80%
Ownership Interest	57.80%
Processing | Gas Processing Complexes
Segment Reporting Information
Number of assets (assets)	4

Segment_Disclosures_Results_De

Segment Disclosures, Results (Details) (USD $)	3 Months Ended									12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013		Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
REVENUES
Affiliate										$497	[1]	$273	[1]	$150	[1]
Third-party										103	[1]	40	[1]	14	[1]
Total Revenues	190	150	133	127	101		97	62	53	600	[1]	313	[1]	164	[1]
OPERATING INCOME
Segment Operating Income										245		91		66
Interest and financing costs, net										-109	[1]	-40	[1]	-9	[1]
Equity in earnings of unconsolidated affiliates										1	[1],[2]	0	[1],[2]	0	[1],[2]
Interest income										0	[1]	1	[1]	0	[1]
Net Income	-8	33	31	42	6		1	11	17	98	[1],[2]	35	[1],[2]	48	[1],[2]
Capital Expenditures
Capital Expenditures										244		83		94
Identifiable Assets
Total Assets	4,814				1,533	[2]				4,814		1,533	[2]	391
Gathering
REVENUES
Affiliate										107	[3]	88	[3]	72	[3]
Third-party										30		2		0
Total Revenues										137		90		72
OPERATING INCOME
Segment Operating Income										49		34		26
Capital Expenditures
Capital Expenditures										156		52		17
Identifiable Assets
Total Assets	1,694				155					1,694		155		87
Processing
REVENUES
Affiliate										7		0		0
Third-party										16		0		0
Total Revenues										23		0		0
OPERATING INCOME
Segment Operating Income										4		0		0
Capital Expenditures
Capital Expenditures										4		0		0
Identifiable Assets
Total Assets	1,612				0					1,612		0		0
Terminalling and Transportation
REVENUES
Affiliate										385	[4]	185	[4]	78	[4]
Third-party										57		38		14
Total Revenues										442		223		92
OPERATING INCOME
Segment Operating Income										192		57		40
Capital Expenditures
Capital Expenditures										84		31		77
Identifiable Assets
Total Assets	1,352				1,330					1,352		1,330		233
Other
OPERATING INCOME
Unallocated general and administrative expenses										-39		-17		-9
Identifiable Assets
Total Assets	156				48					156		48		71
Intersegment Eliminations
REVENUES
Total Revenues										($2)	[1],[3]	$0	[1],[3]	$0	[1],[3]
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[3]	Affiliate gathering revenues includes $2 million of intersegment revenues related to transactions between our Gathering and Processing segments for the year ended DecemberB 31, 2014, which is eliminated upon consolidation.
[4]	Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment for assets acquired in the Acquisitions from Tesoro prior to the effective date of each acquisition, except for the RCA tariffs charged to Tesoro on the refined products pipeline included in the acquisition of the West Coast Logistics Assets.

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Quarterly Financial Data
Total Revenues	$190		$150		$133		$127		$101		$97		$62		$53		$600	[1]	$313	[1]	$164	[1]
Operating and maintenance expenses	102		72		63		53		59		60		32		23		290	[1]	174	[1]	87	[1]
Operating Income	37		61		48		60		21		13		18		22		206	[1]	74	[1]	57
Net Income (Loss)	-8		33		31		42		6		1		11		17		98	[1],[2]	35	[1],[2]	48	[1],[2]
Limited partnersb interest in net income (loss)	($25)		$19		$26		$36		$16		$18		$17		$17		$56	[1]	$68	[1]	$54	[1]
Net Income (Loss) per limited partner unit:
Common - basic (dollars per unit)	($0.34)	[3]	$0.33	[3]	$0.45	[3]	$0.64	[3]	$0.33	[3]	$0.37	[3]	$0.38	[3]	$0.40	[3]	$0.96	[3]	$1.48	[3]	$1.90
Common - diluted (dollars per unit)	($0.34)	[3]	$0.33	[3]	$0.45	[3]	$0.64	[3]	$0.33	[3]	$0.37	[3]	$0.38	[3]	$0.40	[3]	$0.96	[3]	$1.47	[3]	$1.89
Subordinated - basic and diluted (dollars per unit)	$0	[3]	$0	[3]	$0.45	[3]	$0.64	[3]	$0.26	[3]	$0.37	[3]	$0.36	[3]	$0.37	[3]	$0.62	[3]	$1.35	[3]	$1.47
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[3]	The sum of four quarters may not equal annual results due to rounding or the quarterly number of shares outstanding.

Condensed_Consolidating_Financ2

Condensed Consolidating Financial Information Condensed Consolidating Financial Information Narrative (Details)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Percentage ownership of subsidiary guarantors	100.00%

Condensed_Consolidating_Financ3

Condensed Consolidating Financial Information Statement of Operations (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
REVENUES
Affiliate									$497	[1]	$273	[1]	$150	[1]
Third-party									103	[1]	40	[1]	14	[1]
Total Revenues	190	150	133	127	101	97	62	53	600	[1]	313	[1]	164	[1]
COSTS AND EXPENSES
Operating and maintenance expenses	102	72	63	53	59	60	32	23	290	[1]	174	[1]	87	[1]
Imbalance settlement gains and reimbursement from Tesoro									-43	[1]	-12	[1]	-12	[1]
General and administrative expenses									74	[1]	32	[1]	16	[1]
Depreciation and amortization expenses									77	[1],[2]	45	[2]	15	[2]
Gain on asset disposals and impairments									-4	[1],[2]	0	[1],[2]	1	[1],[2]
Total Costs and Expenses									394	[1]	239	[1]	107	[1]
OPERATING INCOME (LOSS)	37	61	48	60	21	13	18	22	206	[1]	74	[1]	57
Interest and financing costs, net									-109	[1]	-40	[1]	-9	[1]
Equity in earnings of unconsolidated affiliates									1	[1],[2]	0	[1],[2]	0	[1],[2]
Equity in earnings of subsidiaries									0
Net Income	-8	33	31	42	6	1	11	17	98	[1],[2]	35	[1],[2]	48	[1],[2]
Loss attributable to Predecessors									4	[1],[3]	45	[1]	9	[1]
Net income attributable to noncontrolling interest									-3	[1]	0	[1]	0	[1]
Net income attributable to partners									99	[1]	80	[1]	57	[1]
Parent
REVENUES
Affiliate									6
Third-party									0
Total Revenues									6
COSTS AND EXPENSES
Operating and maintenance expenses									9
Imbalance settlement gains and reimbursement from Tesoro									0	[1]
General and administrative expenses									37
Depreciation and amortization expenses									1
Gain on asset disposals and impairments									0
Total Costs and Expenses									47
OPERATING INCOME (LOSS)									-41
Interest and financing costs, net									-115
Equity in earnings of unconsolidated affiliates									0
Equity in earnings of subsidiaries									251
Net Income									95
Loss attributable to Predecessors									4	[3]
Net income attributable to noncontrolling interest									0
Net income attributable to partners									99
Guarantor Subsidiaries
REVENUES
Affiliate									484
Third-party									74
Total Revenues									558
COSTS AND EXPENSES
Operating and maintenance expenses									266
Imbalance settlement gains and reimbursement from Tesoro									-43	[1]
General and administrative expenses									34
Depreciation and amortization expenses									68
Gain on asset disposals and impairments									-4
Total Costs and Expenses									321
OPERATING INCOME (LOSS)									237
Interest and financing costs, net									6
Equity in earnings of unconsolidated affiliates									0
Equity in earnings of subsidiaries									0
Net Income									243
Loss attributable to Predecessors									0	[3]
Net income attributable to noncontrolling interest									0
Net income attributable to partners									243
Non-Guarantors
REVENUES
Affiliate									7
Third-party									29
Total Revenues									36
COSTS AND EXPENSES
Operating and maintenance expenses									15
Imbalance settlement gains and reimbursement from Tesoro									0	[1]
General and administrative expenses									3
Depreciation and amortization expenses									8
Gain on asset disposals and impairments									0
Total Costs and Expenses									26
OPERATING INCOME (LOSS)									10
Interest and financing costs, net									0
Equity in earnings of unconsolidated affiliates									1
Equity in earnings of subsidiaries									0
Net Income									11
Loss attributable to Predecessors									0	[3]
Net income attributable to noncontrolling interest									-3
Net income attributable to partners									8
Eliminations
REVENUES
Affiliate									0
Third-party									0
Total Revenues									0
COSTS AND EXPENSES
Operating and maintenance expenses									0
Imbalance settlement gains and reimbursement from Tesoro									0	[1]
General and administrative expenses									0
Depreciation and amortization expenses									0
Gain on asset disposals and impairments									0
Total Costs and Expenses									0
OPERATING INCOME (LOSS)									0
Interest and financing costs, net									0
Equity in earnings of unconsolidated affiliates									0
Equity in earnings of subsidiaries									-251
Net Income									-251
Loss attributable to Predecessors									0	[3]
Net income attributable to noncontrolling interest									0
Net income attributable to partners									($251)
[1]	All periods include the historical results of the Predecessors. Prior year amounts have been adjusted to include amounts related to the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[2]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.
[3]	Amounts attributable to Predecessors have been reflected in the Parent column.

Condensed_Consolidating_Financ4

Condensed Consolidating Financial Information Balance Sheet (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
In Millions, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$19	[1]	$23	[1]	$19	[1]	$18	[1]
Receivables, net
Trade	122		9	[1]
Affiliate	69		43	[1]
Other	18		14	[1]
Prepayments and other	7		7	[1]
Total Current Assets	235		96	[1]
Net property, plant and equipment	3,306		1,398	[1]
Intangibles	973		0	[1]
Goodwill	164		9	[1]
Investment in unconsolidated affiliates	57		0	[1]
Investments in subsidiaries	0
Long-term intercompany receivable	0
Other noncurrent assets	79		30	[1]
Total Assets	4,814		1,533	[1]	391
Accounts payable
Trade	126		22	[1]
Affiliate	53		14	[1]
Accrued interest and financing costs	28		23	[1]
Other current liabilities	79		30	[1]
Total Current Liabilities	286		89	[1]
Long-term intercompany payable	0
Other noncurrent liabilities	45		6	[1]
Debt	2,593		1,164	[1]
Equity - TLLP	1,455
Equity-Noncontrolling interest	435		0	[1]
Total Liabilities and Equity	4,814		1,533	[1]
Parent
CURRENT ASSETS
Cash and cash equivalents	0		23
Receivables, net
Trade	0
Affiliate	3
Other	0
Prepayments and other	3
Total Current Assets	6
Net property, plant and equipment	1
Intangibles	0
Goodwill	0
Investment in unconsolidated affiliates	0
Investments in subsidiaries	4,348
Long-term intercompany receivable	0
Other noncurrent assets	49
Total Assets	4,404
Accounts payable
Trade	6
Affiliate	2
Accrued interest and financing costs	28
Other current liabilities	21
Total Current Liabilities	57
Long-term intercompany payable	307
Other noncurrent liabilities	0
Debt	2,585
Equity - TLLP	1,455
Equity-Noncontrolling interest	0
Total Liabilities and Equity	4,404
Guarantor Subsidiaries
CURRENT ASSETS
Cash and cash equivalents	0		0
Receivables, net
Trade	13
Affiliate	52
Other	18
Prepayments and other	2
Total Current Assets	85
Net property, plant and equipment	1,569
Intangibles	0
Goodwill	9
Investment in unconsolidated affiliates	0
Investments in subsidiaries	0
Long-term intercompany receivable	307
Other noncurrent assets	7
Total Assets	1,977
Accounts payable
Trade	57
Affiliate	40
Accrued interest and financing costs	0
Other current liabilities	33
Total Current Liabilities	130
Long-term intercompany payable	0
Other noncurrent liabilities	14
Debt	8
Equity - TLLP	1,825
Equity-Noncontrolling interest	0
Total Liabilities and Equity	1,977
Non-Guarantors
CURRENT ASSETS
Cash and cash equivalents	19		0
Receivables, net
Trade	109
Affiliate	14
Other	0
Prepayments and other	2
Total Current Assets	144
Net property, plant and equipment	1,736
Intangibles	973
Goodwill	155
Investment in unconsolidated affiliates	57
Investments in subsidiaries	0
Long-term intercompany receivable	0
Other noncurrent assets	23
Total Assets	3,088
Accounts payable
Trade	63
Affiliate	11
Accrued interest and financing costs	0
Other current liabilities	25
Total Current Liabilities	99
Long-term intercompany payable	0
Other noncurrent liabilities	31
Debt	0
Equity - TLLP	2,523
Equity-Noncontrolling interest	435
Total Liabilities and Equity	3,088
Eliminations
CURRENT ASSETS
Cash and cash equivalents	0		0
Receivables, net
Trade	0
Affiliate	0
Other	0
Prepayments and other	0
Total Current Assets	0
Net property, plant and equipment	0
Intangibles	0
Goodwill	0
Investment in unconsolidated affiliates	0
Investments in subsidiaries	-4,348
Long-term intercompany receivable	-307
Other noncurrent assets	0
Total Assets	-4,655
Accounts payable
Trade	0
Affiliate	0
Accrued interest and financing costs	0
Other current liabilities	0
Total Current Liabilities	0
Long-term intercompany payable	-307
Other noncurrent liabilities	0
Debt	0
Equity - TLLP	-4,348
Equity-Noncontrolling interest	0
Total Liabilities and Equity	($4,655)
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.

Condensed_Consolidating_Financ5

Condensed Consolidating Financial Information Statement of Cash Flows (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	$185	[1]	$93	[1]	$72	[1]
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	-199	[1]	-76	[1]	-93	[1]
Acquisitions	-2,479	[1]	-315	[1]	-40	[1]
Intercompany notes, net	0
Distributions to parents	0	[1]	0	[1]	5	[1]
Proceeds from sale of assets	10	[1]	0	[1]	0	[1]
Net cash used in investing activities	-2,668	[1]	-391	[1]	-128	[1]
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	1,300	[1]	806	[1]	350	[1]
Proceeds from issuance of common units, net of issuance costs	1,449	[1]	701	[1]	171	[1]
Proceeds from Issuance of general partner units, net of issuance costs	29	[1]	8	[1]	0	[1]
Distributions related to acquisitions	-243	[1]	-1,129	[1]	-419	[1]
Quarterly distributions to unitholders	-148	[1]	-93	[1]	-51	[1]
Quarterly distributions to general partner	-35	[1]	-9	[1]	-2	[1]
Repayments under revolving credit agreement	-386	[1]	-794	[1]	-118	[1]
Borrowings under revolving credit agreement	646	[1]	794	[1]	68	[1]
Repayments of debt	-130	[1]	0	[1]	0	[1]
Contributions by parent	0
Intercompany borrowings (payments)	0
Sponsor contributions of equity to the Predecessors	3		29		61
Financing costs	-32
Capital contributions by affiliate	26	[1]	5	[1]	6	[1]
Net cash from (used in) financing activities	2,479	[1]	302	[1]	57	[1]
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-4	[1]	4	[1]	1	[1]
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	23	[1]	19	[1]	18	[1]
CASH AND CASH EQUIVALENTS, END OF YEAR	19	[1]	23	[1]	19	[1]
Parent
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	-138
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	-1	[1]
Acquisitions	0
Intercompany notes, net	-2,510
Distributions to parents	15
Proceeds from sale of assets	0
Net cash used in investing activities	-2,496
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	1,300
Proceeds from issuance of common units, net of issuance costs	1,449
Proceeds from Issuance of general partner units, net of issuance costs	29
Distributions related to acquisitions	-243	[1]
Quarterly distributions to unitholders	-148	[1]
Quarterly distributions to general partner	-35	[1]
Repayments under revolving credit agreement	-386	[1]
Borrowings under revolving credit agreement	646	[1]
Repayments of debt	-130	[1]
Contributions by parent	0
Intercompany borrowings (payments)	132
Sponsor contributions of equity to the Predecessors	3
Financing costs	-32
Capital contributions by affiliate	26
Net cash from (used in) financing activities	2,611
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-23
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	23
CASH AND CASH EQUIVALENTS, END OF YEAR	0
Guarantor Subsidiaries
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	317
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	-195	[1]
Acquisitions	0
Intercompany notes, net	0
Distributions to parents	0
Proceeds from sale of assets	10
Net cash used in investing activities	-185
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	0
Proceeds from issuance of common units, net of issuance costs	0
Proceeds from Issuance of general partner units, net of issuance costs	0
Distributions related to acquisitions	0	[1]
Quarterly distributions to unitholders	0	[1]
Quarterly distributions to general partner		[1]
Repayments under revolving credit agreement	0	[1]
Borrowings under revolving credit agreement	0	[1]
Repayments of debt	0	[1]
Contributions by parent	0
Intercompany borrowings (payments)	-132
Sponsor contributions of equity to the Predecessors	0
Financing costs	0
Capital contributions by affiliate	0
Net cash from (used in) financing activities	-132
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	0
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0
CASH AND CASH EQUIVALENTS, END OF YEAR	0
Non-Guarantors
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	6
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	-3	[1]
Acquisitions	-2,479
Intercompany notes, net	0
Distributions to parents	-15
Proceeds from sale of assets	0
Net cash used in investing activities	-2,497
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	0
Proceeds from issuance of common units, net of issuance costs	0
Proceeds from Issuance of general partner units, net of issuance costs	0
Distributions related to acquisitions	0	[1]
Quarterly distributions to unitholders	0	[1]
Quarterly distributions to general partner		[1]
Repayments under revolving credit agreement	0	[1]
Borrowings under revolving credit agreement	0	[1]
Repayments of debt	0	[1]
Contributions by parent	2,510
Intercompany borrowings (payments)	0
Sponsor contributions of equity to the Predecessors	0
Financing costs	0
Capital contributions by affiliate	0
Net cash from (used in) financing activities	2,510
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	19
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0
CASH AND CASH EQUIVALENTS, END OF YEAR	19
Eliminations
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES:
Net cash from (used in) operating activities	0
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES:
Capital expenditures	0	[1]
Acquisitions	0
Intercompany notes, net	2,510
Distributions to parents	0
Proceeds from sale of assets	0
Net cash used in investing activities	2,510
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES:
Proceeds from debt offering	0
Proceeds from issuance of common units, net of issuance costs	0
Proceeds from Issuance of general partner units, net of issuance costs	0
Distributions related to acquisitions	0	[1]
Quarterly distributions to unitholders	0	[1]
Quarterly distributions to general partner		[1]
Repayments under revolving credit agreement	0	[1]
Borrowings under revolving credit agreement	0	[1]
Repayments of debt	0	[1]
Contributions by parent	-2,510
Intercompany borrowings (payments)	0
Sponsor contributions of equity to the Predecessors	0
Financing costs	0
Capital contributions by affiliate	0
Net cash from (used in) financing activities	-2,510
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	0
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0
CASH AND CASH EQUIVALENTS, END OF YEAR	$0
[1]	Adjusted to include the historical results of the West Coast Logistics Assets. See Notes 1 and 2 for further discussion.