10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10‑Q

(Mark One)

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

For the quarterly period ended September 30, 2015

or

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

For the transition period from______________to __________

Commission File Number 1‑35143

TESORO LOGISTICS LP

(Exact name of registrant as specified in its charter)

Delaware	27‑4151603
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)
19100 Ridgewood Pkwy, San Antonio, Texas 78259-1828
(Address of principal executive offices) (Zip Code)
210-626-6000
(Registrant’s telephone number, including area code)

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

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

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

Large accelerated filer  þ	Accelerated filer ¨
Non-accelerated filer  ¨  (Do not check if a smaller reporting company)	Smaller reporting company ¨

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

There were 88,633,988 common units and 1,631,448general partner units of the registrant outstanding at October 26, 2015.

TESORO LOGISTICS LP

QUARTERLY REPORT ON FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2015

TABLE OF CONTENTS

PART I. FINANCIAL INFORMATION		Page
Item 1.	Financial Statements (Unaudited)	3
	Condensed Statements of Combined Consolidated Operations - Three and Nine Months Ended September 30, 2015 and 2014	3
	Condensed Consolidated Balance Sheets - September 30, 2015 and December 31, 2014	4
	Condensed Statements of Combined Consolidated Cash Flows - Nine Months Ended September 30, 2015 and 2014	5
	Notes to Condensed Combined Consolidated Financial Statements	6
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	42
Item 4.	Controls and Procedures	43
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	44
Item 1A.	Risk Factors	44
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
Item 6.	Exhibits	44
SIGNATURES		46

2

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

TESORO LOGISTICS LP

CONDENSED STATEMENTS OF COMBINED CONSOLIDATED OPERATIONS

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
	(In millions, except per unit amounts)
Revenues
Affiliate	$	152		$	130		$	454		$	358
Third-party	130			20			366			52
Total Revenues	282			150			820			410
Costs and Expenses
Operating and maintenance expenses	108			72			307			187
Imbalance settlement gains and reimbursements	(10		)	(17		)	(29		)	(32		)
General and administrative expenses	28			16			81			39
Depreciation and amortization expenses	44			18			132			51
Net gain on asset disposals and impairments	—			—			—			(4		)
Total Costs and Expenses	170			89			491			241
Operating Income	112			61			329			169
Interest and financing costs, net	(37		)	(28		)	(112		)	(63		)
Equity in earnings of unconsolidated affiliates	2			—			6			—
Net Earnings	$	77		$	33		$	223		$	106
Loss attributable to Predecessors	$	—		$	—		$	—		$	4
Net earnings attributable to noncontrolling interest	(3		)	—			(19		)	—
Net Earnings Attributable to Partners	74			33			204			110
General partner’s interest in net earnings, including incentive distribution rights	(20		)	(14		)	(51		)	(29		)
Limited Partners’ Interest in Net Earnings	$	54		$	19		$	153		$	81
Net Earnings per Limited Partner Unit:
Common - basic	$	0.62		$	0.33		$	1.85		$	1.50
Common - diluted	$	0.62		$	0.33		$	1.85		$	1.50
Subordinated - basic and diluted	$	—		$	—		$	—		$	1.28
Weighted Average Limited Partner Units Outstanding:
Common units - basic	86.6			55.9			82.5			47.4
Common units - diluted	86.7			56.0			82.6			47.5
Subordinated units - basic and diluted	—			—			—			7.5
Cash Distributions Paid Per Unit	$	0.7225		$	0.6150		$	2.0850		$	1.7700

See accompanying notes to condensed combined consolidated financial statements.

3

TESORO LOGISTICS LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2015			December 31, 2014
	(In millions, except unit amounts)
ASSETS
Current Assets
Cash and cash equivalents	$	11		$	19
Receivables, net
Trade	132			122
Affiliate	80			69
Other	—			18
Prepayments and other	8			7
Total Current Assets	231			235
Net Property, Plant and Equipment	3,432			3,306
Acquired Intangibles, net	952			973
Goodwill	157			164
Investment in Unconsolidated Affiliates	56			57
Other Noncurrent Assets	23			30
Total Assets	$	4,851		$	4,765
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	85		$	126
Affiliate	52			53
Accrued interest and financing costs	65			28
Other current liabilities	64			79
Total Current Liabilities	266			286
Other Noncurrent Liabilities	49			45
Debt, Net of Unamortized Issuance Costs	2,569			2,544
Commitments and Contingencies (Note 7)
Equity
Common unitholders; 88,633,988 units issued and outstanding (80,125,930 in 2014)	1,887			1,474
General partner; 1,631,448 units issued and outstanding (1,631,448 in 2014)	(4		)	(19		)
Noncontrolling interest	84			435
Total Equity	1,967			1,890
Total Liabilities and Equity	$	4,851		$	4,765

See accompanying notes to condensed combined consolidated financial statements.

4

TESORO LOGISTICS LP

CONDENSED STATEMENTS OF COMBINED CONSOLIDATED CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2015			2014
Cash Flows From (Used In) Operating Activities:	(In millions)
Net earnings	$	223		$	106
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	132			51
Other non-cash operating activities	12			2
Changes in current assets and current liabilities	(1		)	(8		)
Changes in noncurrent assets and liabilities	(2		)	3
Net cash from operating activities	364			154
Cash Flows From (Used In) Investing Activities:
Capital expenditures	(234		)	(116		)
Acquisitions	(6		)	—
Proceeds from sale of assets	—			10
Net cash used in investing activities	(240		)	(106		)
Cash Flows From (Used In) Financing Activities:
Proceeds from issuance of units, net of issuance costs	71			159
Quarterly distributions to unitholders	(173		)	(97		)
Quarterly distributions to general partner	(48		)	(21		)
Distributions to noncontrolling interest	(20		)	—
Distributions in connection with acquisitions	—			(243		)
Borrowings under revolving credit agreement	346			295
Repayments under revolving credit agreement	(326		)	(52		)
Repayments of senior notes	—			(130		)
Capital contributions by affiliate	18			20
Other financing activities	—			2
Net cash used in financing activities	(132		)	(67		)
Decrease in Cash and Cash Equivalents	(8		)	(19		)
Cash and Cash Equivalents, Beginning of Period	19			23
Cash and Cash Equivalents, End of Period	$	11		$	4

See accompanying notes to condensed combined consolidated financial statements.

5

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 1 - ORGANIZATION AND BASIS OF PRESENTATION

Organization

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, 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. 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.

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. TLLP entered into an Agreement and Plan of Merger on April 6, 2015, with TLGP, QEPFS, TLLP Merger Sub LLC (“Merger Sub”), QEP Midstream Partners, LP (“QEPM”), and QEP Midstream Partners GP, LLC (“QEPM GP”). In July 2015, TLLP and QEPM completed the transaction, in which the Merger Sub merged with and into QEPM, with QEPM surviving the merger as a wholly-owned subsidiary of TLLP (the “Merger”). QEPM GP remained the general partner of QEPM following the Merger, and all outstanding common units representing limited partnership interests in QEPM other than QEPM Common Units held by QEPFS (the “QEPM Common Units”) were converted into 0.3088 common units representing limited partnership interests in TLLP (the “TLLP Common Units”). The Merger was completed on July 22, 2015 and TLLP issued approximately 7.1 million TLLP Common Units to QEPM unitholders. No fractional TLLP Common Units were issued in the Merger, and holders of QEPM Common Units other than QEPFS received cash in lieu of fractional TLLP Common Units.

Principles of Combination and Consolidation and Basis of Presentation

In 2014, we entered into transactions with Tesoro and TLGP, pursuant to which TLLP acquired from Tesoro 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 (collectively referred to as the “West Coast Logistics Assets Acquisition”). The West Coast Logistics Assets Acquisition was a transfer between entities under common control. As an entity under common control with Tesoro, we recorded the assets that we acquired 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 condensed combined consolidated financial statements and related notes of TLLP have been retrospectively adjusted to include the historical results of the assets acquired in the West Coast Logistics Assets Acquisition for all periods presented. We refer to the historical results of the West Coast Logistics Assets prior to their respective acquisition dates as our “Predecessor.”

The accompanying condensed combined consolidated financial statements and related notes present the results of operations and cash flows of our Predecessor at historical cost. The financial statements of our Predecessor 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 Predecessor had been operated as an unaffiliated entity. Our Predecessor did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment, with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

The interim condensed combined consolidated financial statements and notes thereto have been prepared by management without audit according to the rules and regulations of the Securities and Exchange Commission (“SEC”) and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of results for the periods presented. Such adjustments are of a normal recurring nature, unless otherwise disclosed.

Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) have been condensed or omitted pursuant to the SEC’s rules and regulations. However, management believes that the disclosures presented herein are adequate to present the information fairly. The accompanying interim condensed combined consolidated financial statements and notes should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2014.

6

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

We prepare our condensed combined consolidated financial statements in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the amounts of assets and liabilities and revenues and expenses reported as of and during the periods presented. 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. The results of operations of the Partnership, or our Predecessor, for any interim period are not necessarily indicative of results for the full year.

We believe the carrying value of our cash and cash equivalents, receivables, accounts payable and certain accrued liabilities approximates fair value. Our fair value assessment incorporates a variety of considerations, including:

• the short term duration of the instruments (approximately 1% of our trade payables and 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 trade receivables excludes amounts that are greater than 90 days related to legal disputes, primarily XTO Energy Inc.’s (“XTO”) legal dispute with QEPFS. See further discussion regarding the XTO litigation in Note 7.

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 borrowings under our amended revolving credit facility (the “Revolving Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were both approximately $2.6 billion as of September 30, 2015 and December 31, 2014. These carrying and fair values of our debt do not include any unamortized issuance costs associated with our total debt.

New Accounting Standards and Disclosures

Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”), which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017 given the FASB’s recent deferral of ASU 2014-09’s effective date. Entities may choose to early adopt ASU 2014-09 as of the original effective date. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the standard to determine the method of adoption and the impact of ASU 2014-09 on our financial statements and related disclosures.

Pushdown Accounting. In November 2014, the SEC released a Staff Accounting Bulletin 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 fair value of 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. We plan to apply pushdown accounting to applicable entities acquired as part of the Rockies Natural Gas Business Acquisition upon finalization of the purchase price allocation.

Consolidation.  In February 2015, the FASB issued ASU 2015-02, “Amendments to the Consolidation Analysis” (“ASU 2015-02”). This standard modifies existing consolidation guidance for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. ASU 2015-02 is effective for interim and annual periods beginning after December 15, 2015, and requires either a retrospective or a modified retrospective approach to adoption. Early adoption is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements, as well as the available transition methods.

7

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Treatment of Predecessor in EPU calculation. In April 2015, the FASB issued ASU 2015-06 (“ASU 2015-06”), which requires a master limited partnership to allocate earnings or losses of transferred net assets for periods prior to asset purchases from an entity under common control entirely to the general partner when calculating earnings per unit (“EPU”). ASU 2015-06 is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. We elected to adopt this guidance beginning in the first quarter of 2015. Adoption of ASU 2015-06 did not impact the disclosed amounts of earnings per unit attributable to limited partners; however, the allocation of earnings presented in our EPU disclosure for the three and nine months ended September 30, 2014 has been modified to conform to the requirements of the final standard. There were no asset purchases from Tesoro during the three and nine months ended September 30, 2015.

Debt Issuance Costs. In April 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest” (“ASU 2015-03”), which will simplify the presentation of debt issuance costs. Under ASU 2015-03, debt issuance costs related to a recognized debt liability will be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability. As a result, our balance sheet will reflect a reclassification of unamortized debt issuance costs from other noncurrent assets to debt. ASU 2015-03 is effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. We adopted this standard in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. The adoption of this standard resulted in the reclassification of $49 million from other noncurrent assets to debt on the balance sheet at December 31, 2014. Unamortized debt issuance costs of $43 million are recorded as a reduction to debt on the balance sheet at September 30, 2015.

Business Combinations. In September 2015, the FASB issued ASU 2015-16, “Simplifying the Accounting for Measurement-Period Adjustments” (“ASU 2015-16”). The standard requires an acquirer to recognize the cumulative impact of adjustments to provisional purchase price amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The standard also requires an entity to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. ASU 2015-16 is effective for interim and annual periods beginning after beginning after December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. Early application is permitted for financial statements that have not been issued.

NOTE 2 - ACQUISITIONS

Rockies Natural Gas Business Acquisition

On December 2, 2014, the Partnership closed the acquisition with QEP Resources, Inc. (“QEP Resources”), in which we agreed to purchase all of the limited liability company interests of QEPFS for approximately $2.5 billion in cash. 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 Williston Basin located in North Dakota (the “Bakken Region”). At the acquisition date, QEPFS held an approximate 56% limited partner interest in QEPM and 100% of the limited liability company interests of QEPM GP, which itself held a 2% general partner interest and all of the incentive distribution rights (“IDRs”) in QEPM. Pursuant to the Merger effected on July 22, 2015, we acquired all remaining limited partner interest in QEPM through the issuance of TLLP common units. There was no impact to the purchase price allocation as a result of the Merger. Refer to Note 1 for further information.

The acquired assets include natural gas and crude oil gathering and transmission pipelines within the Rockies and Bakken Regions, 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.

8

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Finalization of the purchase price allocation is pending and adjustments can be made through the end of our measurement period, which is not to exceed one year from the acquisition date. During the nine months ended September 30, 2015, the original purchase price was increased by $6 million for the settlement of acquisition date net working capital with QEP Resources. We recorded $148 million of goodwill in connection with the Rockies Natural Gas Business Acquisition, of which $13 million was included in our Gathering segment, and $135 million was included in our Processing segment. Acquired intangibles other than goodwill 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. 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 expenses on our condensed statement of combined consolidated operations. The gross carrying value of our finite life intangibles was $976 million and the accumulated amortization was $24 million as of September 30, 2015. During the three and nine months ended September 30, 2015, we incurred $7 million and $21 million, respectively, of amortization expense related to these intangibles.

The table below reflects the preliminary acquisition date purchase price allocation as of September 30, 2015 (in millions):

Cash	$	32
Receivables	120
Prepayments and other	8
Property, plant and equipment	1,735
Intangibles	976
Goodwill	148
Investment in unconsolidated affiliates	57
Other noncurrent assets	23
Accounts payable	(67		)
Other current liabilities	(51		)
Other noncurrent liabilities	(33		)
Noncontrolling interest	(432		)
Total purchase price	$	2,516

If the Rockies Natural Gas Business Acquisition had occurred on January 1, 2014, our pro forma revenues would have been $241 million and $690 million for the three and nine months ended September 30, 2014, respectively. Our pro forma net earnings would have been $25 million and $81 million for the three and nine months ended September 30, 2014, respectively.

West Coast Logistics Assets Acquisition

On July 1, 2014, we acquired the first portion of the West Coast Logistics Assets and we acquired the second portion of the assets on September 30, 2014, upon receiving the required regulatory approval. The operations of the West Coast Logistics Assets are included in our Terminalling and Transportation segment. These transactions were transfers between entities under common control. See our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the West Coast Logistics Assets Acquisition and the commercial agreements executed in connection with this acquisition.

NOTE 3 - RELATED-PARTY TRANSACTIONS

Affiliate Agreements

The Partnership has various long-term, fee-based commercial agreements with Tesoro, under which we provide pipeline transportation, trucking, terminal distribution, storage and petroleum-coke handling services to Tesoro, and Tesoro commits to provide us with minimum monthly throughput volumes of crude oil and refined products.

We entered into the Third Amended and Restated Omnibus Agreement (the “Amended Omnibus Agreement”) and the Secondment and Logistics Services Agreement in connection with the West Coast Logistics Assets Acquisition. We also entered into the First Amended and Restated Omnibus Agreement of QEPM (the “QEPM Omnibus Agreement”) and the Keep-Whole Commodity Fee Agreement in connection with the Rockies Natural Gas Business Acquisition. See Notes 3 and 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of these agreements. On August 3, 2015, subsequent to the Merger, TLLP and QEPM terminated the QEPM Omnibus Agreement.

9

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

On February 20, 2015, we entered into an amendment to the Amended Omnibus Agreement. The amendment, effective December 31, 2014, clarifies certain provisions regarding the responsibilities for costs incurred by TLLP in connection with hydro-testing conducted on our gathering and transportation system located in the Bakken Region. As a result of the termination of the QEPM Omnibus Agreement discussed above, we further amended the Amended Omnibus Agreement to increase the annual administrative fee payable by the Partnership to Tesoro by $3.6 million. This increase, effective July 1, 2015, accounts for the additional fixed costs and expenses related to the administration of the assets of QEPM and its subsidiaries that were previously payable under the QEPM Omnibus Agreement.

Summary of Affiliate Transactions

A summary of revenue and expense transactions with Tesoro, including expenses directly charged and allocated to our Predecessors, are as follows (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Revenues (a)	$	152	$	130	$	454	$	358
Operating and maintenance expenses	28		18		77		56
Imbalance settlement gains and reimbursements from    Tesoro (b)	12		17		31		32
General and administrative expenses	16		11		51		28

_______________

(a) Tesoro accounted for 54% and 55%of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

(b) Includes imbalance settlement gains of$2 million and $9 million for the three months ended September 30, 2015 and 2014, respectively, and $6 million and $14 millionfor the nine months ended September 30, 2015 and 2014, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $10 million and $8 million for the three months ended September 30, 2015 and 2014, respectively, and $25 million and $18 million for the nine months ended September 30, 2015 and 2014, respectively.

Predecessor Transactions. Related-party transactions of our Predecessor were settled through equity. The balance in receivables and accounts payable from affiliated companies represents the amount owed from or to Tesoro related to certain affiliate transactions. Our Predecessor did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment, with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

Distributions. In accordance with our partnership agreement, the unitholders of our common and general partner interests are entitled to receive quarterly distributions of available cash. In connection with the Rockies Natural Gas Business Acquisition, our general partner has waived its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). For the three and nine months ended September 30, 2015, our general partner waived $2.5 million and $7.5 million, respectively, of general partner distributions with respect to IDRs. During the nine months ended September 30, 2015, we paid quarterly cash distributions of $106 million to Tesoro and TLGP, including IDRs. On October 22, 2015, we declared a quarterly cash distribution of $0.7500 per unit, which will be paid on November 13, 2015. The distribution will include payments of $41 million to Tesoro and TLGP, including IDRs.

NOTE 4 - NET EARNINGS PER UNIT

We use the two-class method when calculating the net earnings per unit applicable to limited partners, because we have more than one participating security. At September 30, 2015, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the limited and general partners in accordance with our partnership agreement. We base our calculation of net earnings per unit on the weighted average number of common and subordinated limited partner units outstanding during the period.

Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. Basic and diluted net earnings per unit applicable to subordinated limited partners were 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.

10

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The calculation of net earnings per unit is as follows (in millions, except per unit amounts):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Net earnings	$	77		$	33		$	223		$	106
Net earnings attributable to noncontrolling interest	(3		)	—			(19		)	—
Special allocations of net earnings (“Special Allocations”) (a)	—			7			—			7
Net earnings, excluding noncontrolling interest (b)	74			40			204			113
General partner’s distributions	(1		)	(1		)	(4		)	(3		)
General partner’s IDRs (c)	(19		)	(13		)	(47		)	(26		)
Limited partners’ distributions on common units	(66		)	(52		)	(186		)	(104		)
Limited partners’ distributions on subordinated units (d)	—			—			—			(14		)
Distributions greater than earnings	$	(12	)	$	(26	)	$	(33	)	$	(34	)
General partner’s earnings:
Distributions	$	1		$	1		$	4		$	3
General partner’s IDRs (c)	19			13			47			26
Allocation of distributions greater than earnings (b)	—			—			—			(4		)
Total general partner’s earnings	$	20		$	14		$	51		$	25
Limited partners’ earnings on common units:
Distributions	$	66		$	52		$	186		$	104
Special Allocations	—			(7		)	—			(7		)
Allocation of distributions greater than earnings	(12		)	(26		)	(33		)	(26		)
Total limited partners’ earnings on common units	$	54		$	19		$	153		$	71
Limited partners’ earnings on subordinated units (d):
Distributions	$	—		$	—		$	—		$	14
Allocation of distributions greater than earnings	—			—			—			(4		)
Total limited partners’ earnings on subordinated units	$	—		$	—		$	—		$	10
Weighted average limited partner units outstanding
Common units - basic	86.6			55.9			82.5			47.4
Common unit equivalents	0.1			0.1			0.1			0.1
Common units - diluted	86.7			56.0			82.6			47.5
Subordinated units - basic and diluted (d)	—			—			—			7.5
Net earnings per limited partner unit:
Common - basic	$	0.62		$	0.33		$	1.85		$	1.50
Common - diluted	$	0.62		$	0.33		$	1.85		$	1.50
Subordinated - basic and diluted	$	—		$	—		$	—		$	1.28

_______________

(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 TLLP common unitholders for the premium paid in connection with the redemption of senior notes during the three and nine months ended September 30, 2014.

(b) In April 2015, the FASB issued ASU 2015-06 concerning historical earnings per unit for master limited partnership drop down transactions. We have revised the historical allocation of general partner earnings to include the Predecessor losses TLLP incurred of $4 million during the nine months ended September 30, 2014. There were no earnings or losses for the three months ended September 30, 2014. See Note 1 for additional information on the new guidance.

(c) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $2.5 millionand $7.5 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP in connection with the Rockies Natural Gas Business Acquisition. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2014, for further discussion related to IDRs.

11

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(d) On May 16, 2014, the 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 earnings were allocated to the subordinated units through May 15, 2014.

NOTE 5 - PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment, at cost, is as follows (in millions):

	September 30, 2015			December 31, 2014
Gathering	$	1,695		$	1,507
Processing	546			539
Terminalling and Transportation	1,525			1,478
Other	23			27
Gross Property, Plant and Equipment	3,789			3,551
Accumulated depreciation	(357		)	(245		)
Net Property, Plant and Equipment	$	3,432		$	3,306

NOTE 6 - DEBT

Our debt balance at September 30, 2015 and December 31, 2014 was as follows (in millions):

	September 30, 2015			December 31, 2014
Total debt	$	2,608		$	2,588
Unamortized issuance costs (a) (b)	(39		)	(44		)
Current maturities	—			—
Debt, net of current maturities and unamortized issuance costs	$	2,569		$	2,544

_________

(a) Includes unamortized premium associated with our 5.875% Senior Notes due 2020 of $4 million and $5 million as of September 30, 2015 and December 31, 2014, respectively.

(b) We adopted ASU 2015-03 in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. See Note 1 for further discussion.

Revolving Credit Facility

As of September 30, 2015, our Revolving Credit Facility provided for total loan availability of $900 million. 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. Borrowings are available under the Revolving Credit Facility up to the total loan availability of the 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 Services L.L.C., and secured by substantially all of our assets. We had $280 millionof borrowings outstanding under the Revolving Credit Facility, resulting in a total unused loan availability of $620 million or 69% of the borrowing capacity as of September 30, 2015. The weighted average interest rate for borrowings under our Revolving Credit Facility was 2.69% at September 30, 2015. The Revolving Credit Facility is scheduled to mature on December 2, 2019.

12

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 7 - COMMITMENTS AND CONTINGENCIES

Tesoro Indemnification

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 TLLP initial public offering (“Initial Offering”) and subsequent acquisitions from Tesoro, excluding certain Los Angeles assets acquired from Tesoro in 2013. Under the Carson Assets Indemnity Agreement (the “Carson Assets Indemnity Agreement”), Tesoro retained responsibility for remediation of known environmental liabilities due to the use or operation of certain Los Angeles assets prior to the acquisition dates, and has indemnified the Partnership for any losses incurred by the Partnership arising out of those remediation obligations. See Note 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

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 accrues 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. We have accrued liabilities for these expenses and believe these accruals are adequate based on current information and projections that can be reasonably estimated. Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible that these estimates will change as more information becomes available. Our accruals for these environmental expenditures totaled $15 million and $32 million at September 30, 2015 and December 31, 2014, respectively.

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 to restore the site for agricultural use. We spent $17 million during the nine months ended September 30, 2015 on remediation related to the Crude Oil Pipeline Release. Our condensed consolidated balance sheet included $8 million and $25 million in accrued environmental liabilities related to the Crude Oil Pipeline Release at September 30, 2015 and December 31, 2014, respectively.This incident was covered by our pollution legal liability insurance policy, subject to a $1 million deductible and a $25 million loss limit. Pursuant to this policy, there were no insurance recovery receivables related to the Crude Oil Pipeline Release at September 30, 2015, and $18 million at December 31, 2014. As of September 30, 2015, the total estimated remediation costs were $42 million, which exceeded our pollution liability legal insurance policy and we are continuously seeking to improve remediation methods and associated costs.

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.

13

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Chevron Diesel Pipeline Release. On March 18, 2013, Chevron Pipe Line Company and Northwest Terminalling Company (collectively, “Chevron”) detected and responded to the release of diesel fuel (the “Diesel Pipeline Release”) that occurred near Willard, Utah on the northwest products system (the “Northwest Products System”). As a result of this release, a Corrective Action Order (the “CAO”) was issued on March 22, 2013 by PHMSA. Chevron retained the financial and operational responsibility to remediate the site of the Diesel Pipeline Release, including the payment of any monetary fines and penalties assessed by any government authority arising from this incident, prior to and subsequent to the date of acquisition until June 19, 2015. 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. On March 6, 2015, PHMSA issued a closure letter indicating that we have complied with all the terms of the CAO and that no further action is required. We have recognized $4 million and $6 million in as environmental remediation liabilities at September 30, 2015 and December 31, 2014, respectively, representing our best estimate of liabilities remaining for all assets acquired from Chevron.

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. TLLP has agreed to indemnify QEP Field Services Company 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, the assets and agreement discussed above were 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 $18 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 Energy Inc. (“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. XTO has also withheld payments for amounts unrelated to the allocation of charges they have challenged. While we cannot currently estimate the final amount or timing of the resolution of this matter, we believe the outcome will not have a material impact on our liquidity, financial position, or results of operations.

NOTE 8 - EQUITY

We had 60,452,240 common public units outstanding as of September 30, 2015. 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 September 30, 2015, which together constitutes a 33% ownership interest in us.

14

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

ATM Programs. On June 25, 2014, we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission 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 “2014 ATM Program”). The 2014 ATM Program expired during the second quarter of 2015. During the nine months ended September 30, 2015, we issued an aggregate of 819,513 common units, under our 2014 ATM Program, generating net proceeds of approximately $45 million. There were no common units issued during the three months ended September 30, 2015. The net proceeds from sales under the 2014 ATM Program were used for general partnership purposes, which included debt repayment, acquisitions, capital expenditures and additions to working capital.

On August 21, 2015, we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission on August 6, 2015, authorizing the continuous issuance of up to an aggregate of $750 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 “2015 ATM Program”). During the three and nine months ended September 30, 2015, we issued an aggregate of 537,014 common units under our 2015 ATM Program, generating net proceeds of approximately $26 million. The net proceeds from sales under the 2015 ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

The table below summarizes changes in the number of units outstanding from December 31, 2014 through September 30, 2015 (in million units):

	Partnership
	Common	General Partner	Total
Balance at December 31, 2014	80.1	1.6	81.7
Issuance of units under ATM Program	1.4	—	1.4
Issuance of units to QEPM unitholders (a)	7.1	—	7.1
Balance at September 30, 2015	88.6	1.6	90.2

_____________

(a) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

The summarized changes in the carrying amount of our equity are as follows (in millions):

	Partnership
	Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2014	$	1,474		$	(19	)	$	435		$	1,890
Equity offering under ATM Program, net of issuance costs	66			5			—			71
Distributions (a)	(173		)	(48		)	(20		)	(241		)
Net earnings	153			51			19			223
Contributions (b)	14			7			—			21
QEPM Merger (c)	350			—			(350		)	—
Other	3			—			—			3
Balance at September 30, 2015	$	1,887		$	(4	)	$	84		$	1,967

_____________

(a) Represents cash distributions declared and paid during the nine months ended September 30, 2015 relating to the fourth quarter of 2014 through the second quarter of 2015.

(b) Includes Tesoro and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

(c) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

15

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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 connection with the Rockies Natural Gas Business Acquisition, our general partner has waived its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). The table below summarizes the quarterly distributions related to our quarterly financial results:

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2014	$	0.6675	$	70	February 13, 2015	February 2, 2015
March 31, 2015	0.6950		70		May 15, 2015	May 4, 2015
June 30, 2015	0.7225		81		August 14, 2015	August 3, 2015
September 30, 2015 (a)	0.7500		86		November 13, 2015	November 2, 2015

_____________

(a) This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

NOTE 9 - SEGMENT DISCLOSURES

Our revenues are derived from three operating segments: Gathering, Processing, Terminalling and Transportation. 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 Green River Processing, LLC (“GRP”), which owns one fractionation facility and two gas processing complexes. Our Terminalling and Transportation segment consists of:

• 24 crude oil and refined products terminals and storage facilities in the western and midwestern U.S.;

• four marine terminals in California;

• 130 miles of pipelines, which transport products and crude oil from Tesoro’s refineries to nearby facilities in Salt Lake City and Los Angeles;

• 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 rail-car unloading facility in Washington;

• a petroleum coke handling and storage facility in Los Angeles; and

• a regulated common carrier refined products pipeline system connecting Tesoro’s Kenai refinery to terminals in Anchorage, Alaska.

Our revenues are generated from 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 natural gas liquids. The commercial agreements with Tesoro are described in greater detail in Note 3 to our Annual Report on Form 10-K for the year ended December 31, 2014. We do not have any foreign operations.

Our operating segments are strategic business units that offer different services in various geographical locations. We evaluate the performance of each segment based on its respective operating income. Certain general and administrative expenses, interest and financing costs and equity in earnings of unconsolidated affiliates 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 and other assets that are not associated with a specific operating segment.

16

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Segment information related to continuing operations is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Revenues
Gathering:
Affiliate	$	18		$	27		$	71		$	75
Third-party	69			5			182			9
Total Gathering	87			32			253			84
Processing
Affiliate	26			—			71			—
Third-party	45			—			134			—
Total Processing	71			—			205			—
Terminalling and Transportation:
Affiliate	108			103			312			283
Third-party	16			15			50			43
Total Terminalling and Transportation	124			118			362			326
Total Segment Revenues	$	282		$	150		$	820		$	410
Segment Operating Income
Gathering	$	42		$	15		$	121		$	38
Processing	29			—			77			—
Terminalling and Transportation	57			52			174			145
Total Segment Operating Income	128			67			372			183
Unallocated general and administrative expenses	(16		)	(6		)	(43		)	(14		)
Interest and financing costs, net	(37		)	(28		)	(112		)	(63		)
Equity in earnings of unconsolidated affiliates	2			—			6			—
Net Earnings	$	77		$	33		$	223		$	106
Capital Expenditures
Gathering	$	72		$	40		$	177		$	92
Processing	5			—			10			—
Terminalling and Transportation	15			23			48			45
Total Capital Expenditures	$	92		$	63		$	235		$	137

17

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 10 - CONDENSED CONSOLIDATING FINANCIAL INFORMATION

Separate condensed consolidating financial information of Tesoro Logistics LP (the “Parent”), subsidiary guarantors and non-guarantors are presented below. QEPFS, our wholly-owned subsidiary acquired on December 2, 2014, and certain of its subsidiaries were elected guarantors of these obligations in January 2015. As of September 30, 2015, TLLP and certain subsidiary guarantors have fully and unconditionally guaranteed our registered 2020 Senior Notes and 2021 Senior Notes. 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 condensed consolidated financial statements and notes thereto. The December 31, 2014 balance sheet has been adjusted to conform to the guarantor structure as of September 30, 2015, and now includes QEPM and GRP within the guarantor subsidiaries column as a result of the Merger. 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 wholly-owned and are jointly and severally liable for TLLP’s outstanding senior notes. The separate condensed consolidating financial information is presented using the equity method of accounting for investments in subsidiaries. Intercompany transactions between subsidiaries are presented gross and eliminated in the consolidating adjustments column. Additionally, certain fair value adjustments resulting from the purchase price allocation for the Rockies Natural Gas Business Acquisition were not pushed down to previously non-wholly owned subsidiaries that are now included as guarantor subsidiaries as a result of the Merger as well as non-guarantor subsidiaries; rather, the fair value adjustments are included within the consolidating adjustments column.

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 its guarantors 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 the three and nine months ended September 30, 2014.

18

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Condensed Consolidating Statement of Operations

For the Three Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	153		$	7		$	(8	)	$	152
Third-party	—			129			1			—			130
Total Revenues	—			282			8			(8		)	282
Costs and Expenses
Operating and maintenance expenses	—			115			—			(7		)	108
Imbalance settlement gains and reimbursements	—			(10		)	—			—			(10		)
General and administrative expenses	9			19			—			—			28
Depreciation and amortization expenses	—			36			3			5			44
Total Costs and Expenses	9			160			3			(2		)	170
Operating Income (Loss)	(9		)	122			5			(6		)	112
Interest and financing costs, net	—			(34		)	—			(3		)	(37		)
Equity in earnings of unconsolidated affiliates	—			2			—			—			2
Equity in earnings of subsidiaries	83			4			—			(87		)	—
Net Earnings	$	74		$	94		$	5		$	(96	)	$	77
Net earnings attributable to noncontrolling interest	—			(2		)	(1		)	—			(3		)
Net earnings attributable to partners	$	74		$	92		$	4		$	(96	)	$	74

19

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Condensed Consolidating Statement of Operations

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	454		$	20		$	(20	)	$	454
Third-party	—			365			4			(3		)	366
Total Revenues	—			819			24			(23		)	820
Costs and Expenses
Operating and maintenance expenses	—			326			1			(20		)	307
Imbalance settlement gains and reimbursements	—			(29		)	—			—			(29		)
General and administrative expenses	21			60			—			—			81
Depreciation and amortization expenses	—			107			9			16			132
Loss on asset disposals and impairments	—			5			—			(5		)	—
Total Costs and Expenses	21			469			10			(9		)	491
Operating Income (Loss)	(21		)	350			14			(14		)	329
Interest and financing costs, net	—			(103		)	—			(9		)	(112		)
Equity in earnings of unconsolidated affiliates	—			7			—			(1		)	6
Equity in earnings of subsidiaries	225			11			—			(236		)	—
Net Earnings	$	204		$	265		$	14		$	(260	)	$	223
Net earnings attributable to noncontrolling interest	—			(16		)	(3		)	—			(19		)
Net earnings attributable to partners	$	204		$	249		$	11		$	(260	)	$	204

20

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Condensed Consolidating Balance Sheet as of September 30, 2015

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	7	$	—	$	4	$	—		$	11
Receivables, net
Trade	—		131		1		—			132
Affiliate	2		81		2		(5		)	80
Prepayments and other	5		5		—		(2		)	8
Total Current Assets	14		217		7		(7		)	231
Net property, plant and equipment	—		2,778		179		475			3,432
Acquired intangibles, net	—		577		—		375			952
Goodwill	—		63		—		94			157
Investment in unconsolidated affiliates	—		42		—		14			56
Investments in subsidiaries	4,814		142		—		(4,956		)	—
Long-term intercompany receivable	—		184		—		(184		)	—
Other noncurrent assets	1		22		—		—			23
Total Assets	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	2	$	83	$	—	$	—		$	85
Affiliate	4		53		—		(5		)	52
Accrued interest and financing costs	65		—		—		—			65
Other current liabilities	21		44		1		(2		)	64
Total Current Liabilities	92		180		1		(7		)	266
Long-term intercompany payable	292		—		2		(294		)	—
Other noncurrent liabilities	—		57		1		(9		)	49
Debt, net of unamortized issuance costs	2,561		8		—		—			2,569
Equity - TLLP	1,884		3,780		142		(3,923		)	1,883
Equity - Noncontrolling interest	—		—		40		44			84
Total Liabilities and Equity	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851

21

TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Condensed Consolidating Balance Sheet as of December 31, 2014 (a)

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	—	$	17	$	2	$	—		$	19
Receivables, net
Trade	—		121		1		—			122
Affiliate	3		66		—		—			69
Other	—		18		—		—			18
Prepayments and other	3		4		—		—			7
Total Current Assets	6		226		3		—			235
Net property, plant and equipment	1		2,639		188		478			3,306
Acquired intangibles, net	—		590		—		383			973
Goodwill	—		48		—		116			164
Investment in unconsolidated affiliates	—		43		—		14			57
Investments in subsidiaries	4,233		152		—		(4,385		)	—
Long-term intercompany receivable	—		196		5		(201		)	—
Other noncurrent assets	—		30		—		—			30
Total Assets	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	6	$	120	$	—	$	—		$	126
Affiliate	3		50		—		—			53
Accrued interest and financing costs	28		—		—		—			28
Other current liabilities	21		60		—		(2		)	79
Total Current Liabilities	58		230		—		(2		)	286
Long-term intercompany payable	191		5		—		(196		)	—
Other noncurrent liabilities	—		54		1		(10		)	45
Debt, net of unamortized issuance costs	2,536		8		—		—			2,544
Equity - TLLP	1,455		3,598		152		(3,750		)	1,455
Equity - Noncontrolling interest	—		29		43		363			435
Total Liabilities and Equity	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765

_____________

(a) Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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TESORO LOGISTICS LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Condensed Consolidating Statement of Cash Flows

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Cash Flows From (Used In) Operating Activities:
Net cash from (used in) operating activities	$	19		$	355		$	21		$	(31	)	$	364
Cash Flows From (Used In) Investing Activities:
Capital expenditures	—			(234		)	—			—			(234		)
Acquisitions	—			(6		)	—			—			(6		)
Investments in subsidiaries	(6		)	—			—			6			—
Net cash used in investing activities	(6		)	(240		)	—			6			(240		)
Cash Flows From (Used In) Financing Activities:
Proceeds from issuance of common units, net of issuance costs	71			—			—			—			71
Quarterly distributions to unitholders	(173		)	—			—			—			(173		)
Quarterly distributions to general partner	(49		)	—			(20		)	21			(48		)
Distributions to noncontrolling interest	—			(15		)	(5		)	—			(20		)
Distributions to subsidiaries	—			—			—			—			—
Borrowings under revolving credit agreement	346			—			—			—			346
Repayments under revolving credit agreement	(326		)	—			—			—			(326		)
Contributions	—			6			—			(6		)	—
Intercompany borrowings (payments)	107			(123		)	6			10			—
Capital contributions by affiliate	18			—			—			—			18
Net cash from (used in) financing activities	(6		)	(132		)	(19		)	25			(132		)
Increase (Decrease) in Cash and Cash Equivalents	7			(17		)	2			—			(8		)
Cash and Cash Equivalents, Beginning of Period	—			17			2			—			19
Cash and Cash Equivalents, End of Period	$	7		$	—		$	4		$	—		$	11

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Unless the context otherwise requires, references in this report to “Tesoro Logistics LP,” “TLLP,” “the Partnership,” “we,” “us” or “our” 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 interest in QEP Midstream Partners, LP (“QEPM”), 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” refer collectively to Tesoro Corporation and any of its subsidiaries, other than Tesoro Logistics LP, its subsidiaries and its general partner.

In 2014, as part of our strategy to make capital investments to expand our existing asset base, we entered into transactions with Tesoro and Tesoro Logistics GP, LLC (“TLGP”), our general partner, pursuant to which TLLP acquired from Tesoro 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 (collectively referred to as the “West Coast Logistics Assets Acquisition”). We refer to the historical results of the West Coast Logistics Assets prior to their respective acquisition dates as our “Predecessor.” In connection with the West Coast Logistics Assets Acquisition we entered into the Third Amended and Restated Omnibus Agreement (the “Amended Omnibus Agreement”). See Notes 3 and 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of this agreement.

On December 2, 2014, we acquired QEP Field Services, LLC (“QEPFS”), which as of the acquisition date included a 56% limited partner interest in QEP Midstream Partners, LP (“QEPM”) and 100% of the limited liability company interests of QEPM’s general partner, QEP Midstream Partners GP, LLC (“QEPM GP”), which itself holds a 2% general partner interest and 100% of the incentive distribution rights (“IDRs”) in QEPM from QEP Resources, Inc. (“QEP Resources”) (collectively the “Rockies Natural Gas Business Acquisition”). On April 6, 2015, TLLP entered into an Agreement and Plan of Merger (the “Merger Agreement”) with TLGP, QEPFS, TLLP Merger Sub LLC (“Merger Sub”), QEPM, and QEPM GP. On July 22, 2015, TLLP and QEPM completed the transaction, in which the Merger Sub merged with and into QEPM, with QEPM surviving the merger as a wholly- owned subsidiary of TLLP (the “Merger”). Pursuant to the Merger, we acquired all remaining limited partner interest in QEPM through the issuance of TLLP common units. Refer to Note 1 for further information.

Those statements in this section that are not historical in nature should be deemed forward-looking statements that are inherently uncertain. See “Important Information Regarding Forward-Looking Statements” section for a discussion of the factors that could cause actual results to differ materially from those projected in these statements.

This section should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2014.

BUSINESS STRATEGY AND OVERVIEW

We are a leading full-service logistics company operating primarily in the western and mid-continent regions of the United States. We own and operate over 3,500 miles of crude oil, refined products and natural gas pipelines and 28 crude oil and refined products truck and marine terminals and have over 9 million barrels of 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. For the three and nine months ended September 30, 2015, approximately 54% and 55%, respectively, of our total revenues were derived from Tesoro under various long-term, fee-based commercial agreements, many of which include minimum volume commitments.

Our financial information includes the historical results of our Predecessor and the results of TLLP for the three and nine months ended September 30, 2014. The financial statements of our Predecessor 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 Predecessor had been operated as an unaffiliated entity. Most notably, this applies to the revenue associated with the terms of the commercial agreements as our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment, with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

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We generate revenues 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. We are generally not exposed to commodity price risk with respect to any of the crude oil, natural gas, natural gas liquids (“NGLs”) or refined products that we handle, with the exception of a nominal amount of condensate. 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 movements 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, through their effects on our customers’ operations, these risks indirectly influence our activities and results of operations over the long term.

Rockies Natural Gas Business Acquisition. As a part of our strategy to focus on stable fee-based business, optimize existing assets, and grow through strategic acquisitions, we acquired QEPFS on December 2, 2014 for an aggregate purchase price of approximately $2.5 billion. The purchase price also includes post-closing adjustments for net working capital. QEPFS either directly or indirectly owns 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 Williston Basin located in North Dakota (the “Bakken Region”).

The assets acquired in the Rockies Natural Gas Business Acquisition include over 2,000 miles of natural gas and crude oil gathering and transmission pipelines, with natural gas throughput capacity of 2.9 billion cubic feet per day (“bcf/d”) and crude oil throughput capacity of over 54,000 barrels per day (“bpd”). Additionally, the acquired assets include four natural gas processing complexes with total capacity of 1.5 bcf/d and one fractionation facility with 15,000 bpd of throughput capacity (“Rockies Natural Gas Assets”). The natural gas and crude oil gathering operations are included in our Gathering segment, and the natural gas processing operations are included in the Processing segment.

On April 6, 2015, TLLP entered into the Merger Agreement with TLGP, QEPFS, the Merger Sub, QEPM, and QEPM GP. The Merger transaction was completed on July 22, 2015. QEPM GP remained the general partner of QEPM following the Merger, and all outstanding common units representing limited partnership interests in QEPM other than QEPM Common Units held by QEPFS (the “QEPM Common Units”) were converted into 0.3088 common units representing limited partnership interests in TLLP (the “TLLP Common Units”). As a result of the Merger, TLLP issued approximately 7.1 million TLLP Common Units to QEPM unitholders. No fractional TLLP Common Units were issued in the Merger, and holders of QEPM Common Units other than QEPFS received cash in lieu of fractional TLLP Common Units.

Open Season. In December 2014, we launched an additional binding open season, to assess shipper interest in firm priority capacity on our common carrier pipeline in North Dakota and Montana (the “High Plains Pipeline”). While we did not receive interest at that time to move forward with the full open season project, based on shipper interest, as well as current strong demand for pipeline take-away capacity in the McKenzie County area of North Dakota, we intend to proceed with a portion of the expansion projects in the core Bakken production areas. The projects are expected to provide incremental capacity to move crude oil from the core production areas to our existing interconnections with rail facilities and regional pipelines. The projects will require estimated capital expenditures of approximately $50 million and are expected to be completed in 2016.

Charging Eagle Gathering System. On October 28, 2015, we announced our plans to build a new gathering and treating system, the Charging Eagle Gathering System (“Charging Eagle Gathering System”), in the Bakken region in North Dakota. The Charging Eagle Gathering System will aggregate crude oil and produced water from various points in southeastern Dunn County and deliver crude oil to the High Plains Pipeline. This project is fully backed with annual minimum volume commitments and is expected to generate competitive returns in-line with TLLP’s previous projects. Capital expenditures for this project are estimated to be $40 million to $50 million and construction is expected to begin in 2016.

Strategy and Goals

Our primary business objectives are to maintain stable cash flows and to increase our quarterly cash distribution per unit over time. We intend to accomplish these objectives by executing the following strategies:

• focus on opportunities to provide committed fee-based logistics services to Tesoro and third parties;

• evaluate investment opportunities that may arise from the growth of Tesoro’s refining and marketing business or from increased third-party activity to make capital investments to expand our existing asset base;

• pursue acquisitions of complementary assets from Tesoro as well as third parties; and

• seek to enhance the profitability of our existing assets by pursuing opportunities to add Tesoro and third-party volumes, improve operating efficiencies and increase utilization.

25

We have been implementing our strategy and goals discussed above, allowing us to steadily increase our cash flow available to be distributed to unitholders (“Distributable Cash Flow”) and to increase our distributions by 17% over the last year.

Relative to these goals, in 2015, we intend to continue to implement this strategy and have completed or announced plans to:

• expand our assets on our gathering and transportation system, located in the Bakken Region (the “High Plains System”) in support of growing third-party demand for transportation services and Tesoro’s increased demand for Bakken crude oil in the mid-continent and west coast refining systems, including:

◦ further expanding capacity and capabilities of our High Plains Pipeline;

◦ expanding our gathering footprint in the Bakken Region, including crude oil, natural gas and water, to enhance and improve overall basin logistics efficiencies;

◦ adding other origin and destination points on the High Plains System to increase volumes; and

◦ expanding utilization of our proprietary truck fleet, which should generate cost and operating efficiencies.

• increase our terminalling volumes by expanding capacity and growing our third-party services at certain of our terminals;

• optimize Tesoro volumes and grow third-party volumes at our terminalling and transportation assets; and

• expand and optimize our assets acquired in the Rockies Natural Gas Business Acquisition.

Current Market Conditions

For more than a year, the spot prices of the commodities that we handle, including crude oil, natural gas, natural gas liquids and refined products, have declined, due in part to the rapid growth of domestic supplies of these commodities. A weakened and volatile commodity price environment has created challenges for crude oil and natural gas producers who have modified their drilling and production plans. According to the last Baker Hughes Rig Count report, the United States drilling rig count has declined more than 58% over the last 12 months. At the same time, our downstream refining and marketing customers have seen an increased demand for refined products. We continue to monitor the impact of these changes in market prices and demand on our business in the western United States, including values recognized in connection with the recently acquired Rockies Natural Gas Business. We believe our diversified portfolio of business as well as our minimum volume commitments are sufficient to continue to meet our goals and objectives outlined above.

RESULTS OF OPERATIONS

A discussion and analysis of the factors contributing to our results of operations presented below includes the combined financial results of our Predecessors and the consolidated financial results of TLLP. The financial statements, together with the following information, are intended to provide investors with a reasonable basis for assessing our historical operations, but should not serve as the only criteria for predicting our future performance.

Non-GAAP Measures

Our management uses a variety of financial and operating measures to analyze operating segment performance. Our management also uses additional measures that are known as “non-GAAP” financial measures in its evaluation of past performance and prospects for the future to supplement our financial information presented in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). These measures are significant factors in assessing our operating results and profitability and include earnings before interest, income taxes, loss attributable to Predecessors, and depreciation and amortization expense (“EBITDA”), Adjusted EBITDA and Distributable Cash Flow. In 2015, we updated our presentation of EBITDA, Adjusted EBITDA and Distributable Cash Flow to include noncontrolling interest in these calculations. Management uses EBITDA and Adjusted EBITDA to manage our operations and business as a whole without regard to amounts attributable to noncontrolling interests. As a result of the change in EBITDA and Adjusted EBITDA, our definition of Distributable Cash Flow was revised to adjust for noncontrolling interest amounts since they continue to impact cash available for distribution to our unitholders.

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We define adjusted EBITDA as EBITDA plus or minus amounts determined to be “special items” by our management based on their unusual nature and relative significance to earnings in a certain period. We define Distributable Cash Flow as adjusted EBITDA plus or minus amounts determined to be “special items” by our management based on their relative significance to cash flow in a certain period. We define Pro Forma Distributable Cash Flow as Distributable Cash Flow plus or minus adjustments for the acquisition of noncontrolling interest in connection with the Merger. We provide complete reconciliation and discussion of items identified as special items with our presentation of adjusted EBITDA and Distributable Cash Flow. Prior periods have been adjusted to conform to current presentation. EBITDA, adjusted EBITDA, Distributable Cash Flow and Pro Forma Distributable Cash Flow are not measures prescribed by U.S. GAAP but are supplemental financial measures that are used by management and may be used by external users of our financial statements, such as industry analysts, investors, lenders and rating agencies, to assess:

• our operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard to historical cost basis or financing methods;

• the ability of our assets to generate sufficient cash flow to make distributions to our unitholders;

• our ability to incur and service debt and fund capital expenditures; and

• the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.

The U.S. GAAP measures most directly comparable to EBITDA and adjusted EBITDA are net earnings and net cash from operating activities. EBITDA and adjusted EBITDA should not be considered as an alternative to U.S. GAAP net earnings or net cash from operating activities. EBITDA and adjusted EBITDA have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings and net cash from operating activities. We have updated our Distributable Cash Flow to adjust for the impact of our noncontrolling interest acquired in the Rockies Natural Gas Business. The U.S. GAAP measure most directly comparable to Distributable Cash Flow and Pro Forma Distributable Cash Flow is net earnings.

Investors and analysts use these financial measures to help analyze and compare companies in the industry on the basis of operating performance. These non-GAAP financial measures should not be considered in isolation or as a substitute for analysis of revenues, operating expenses, segment operating income, or any other measure of financial performance presented in accordance with U.S. GAAP. Our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, because they may be defined differently by other companies in our industry, thereby diminishing their utility.

Operating Metrics

Management utilizes the following operating metrics to evaluate performance and compare profitability to other companies in the industry: average revenue per barrel, average revenue per MMBtu, and average keep-whole fee per barrel. There are a variety of ways to calculate average revenue per barrel, average revenue per MMBtu, and average keep-whole fee per barrel; other companies may calculate these in different ways. We calculate average revenue per barrel as revenue divided by total throughput (barrels). We calculate average revenue per MMBtu as revenue divided by total throughput (MMBtu). We calculate average keep-whole fee per barrel as revenue divided by total throughput (barrels).

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Summary

The following table and discussion is a summary of our results of operations for the three and nine months ended September 30, 2015 and 2014, including a reconciliation of EBITDA and adjusted EBITDA to net earnings and net cash from operating activities and Distributable Cash Flow to net earnings (in millions, except per unit amounts). Our financial results may not be comparable as our Predecessor recorded revenues and general and administrative expenses, and financed operations differently than the Partnership. See “Factors Affecting the Comparability of Our Financial Results” in our Annual Report on Form 10-K for the year ended December 31, 2014.

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Revenues
Gathering	$	87		$	32		$	253		$	84
Processing	71			—			205			—
Terminalling and Transportation (a)	124			118			362			326
Total Revenues	282			150			820			410
Costs and Expenses
Operating and maintenance expenses (b)	98			55			278			155
General and administrative expenses	28			16			81			39
Depreciation and amortization expenses	44			18			132			51
Net gain on asset disposals and impairments	—			—			—			(4		)
Total Costs and Expenses	170			89			491			241
Operating Income	112			61			329			169
Interest and financing costs, net	(37		)	(28		)	(112		)	(63		)
Equity in earnings of unconsolidated affiliates	2			—			6			—
Net Earnings	$	77		$	33		$	223		$	106
Loss attributable to Predecessors	$	—		$	—		$	—		$	4
Net earnings attributable to noncontrolling interest	(3		)	—			(19		)	—
Net Earnings Attributable to Partners	74			33			204			110
General partner’s interest in net earnings, including incentive distribution rights	(20		)	(14		)	(51		)	(29		)
Limited Partners’ Interest in Net Earnings	$	54		$	19		$	153		$	81
Net Earnings per Limited Partner Unit:
Common - basic	$	0.62		$	0.33		$	1.85		$	1.50
Common - diluted	$	0.62		$	0.33		$	1.85		$	1.50
Subordinated - basic and diluted	$	—		$	—		$	—		$	1.28
Weighted Average Limited Partner Units Outstanding:
Common units - basic	86.6			55.9			82.5			47.4
Common units - diluted	86.7			56.0			82.6			47.5
Subordinated units - basic and diluted	—			—			—			7.5
EBITDA	$	158		$	79		$	467		$	223
Adjusted EBITDA	$	158		$	80		$	481		$	224
Distributable Cash Flow	$	116		$	53		$	318		$	169

See pages 29 and 30 for footnotes to this table.

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	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Reconciliation of EBITDA, Adjusted EBITDA and Distributable Cash Flow to Net Earnings:
Net earnings	$	77		$	33		$	223		$	106
Loss attributable to Predecessors	—			—			—			4
Depreciation and amortization expenses, net of Predecessor expense	44			18			132			50
Interest and financing costs, net of capitalized interest	37			28			112			63
EBITDA	158			79			467			223
Gain on sale of Boise Terminal (c)	—			—			—			(5		)
Acquisition costs included in general and administrative expenses (d)	—			1			1			1
Billing of deficiency payments (e)	—			—			13			—
Inspection and maintenance capital expenses associated with the Northwest Products System (f)	—			—			—			5
Adjusted EBITDA	158			80			481			224
Interest and financing costs, net	(37		)	(21		)	(112		)	(56		)
Maintenance capital expenditures (g)	(11		)	(13		)	(35		)	(20		)
Other adjustments for noncontrolling interest (h)	—			—			(20		)	—
Net earnings attributable to noncontrolling interest (i)	(1		)	—			(17		)	—
Reimbursement for maintenance capital expenditures (g)	1			3			4			4
Other non-cash operating activities	6			4			17			7
Proceeds from sale of assets	—			—			—			10
Distributable Cash Flow	116			53			318			169
Pro forma adjustment for acquisition of noncontrolling interest (j)	—			—			36			—
Pro Forma Distributable Cash Flow	$	116		$	53		$	354		$	169
Reconciliation of EBITDA to Net Cash from Operating Activities:
Net cash from operating activities	$	142		$	68		$	364		$	154
Interest and financing costs, net	37			28			112			63
Changes in assets and liabilities	(18		)	(13		)	3			5
Other non-cash operating activities	(3		)	(4		)	(12		)	(6		)
Predecessor impact	—			—			—			3
Net gain on asset disposals and impairments	—			—			—			4
EBITDA	$	158		$	79		$	467		$	223

____________

(a) Our Predecessor 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 with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

(b) Operating and maintenance expenses includes imbalance settlement gains of $9 million for the three months ended September 30, 2014, and imbalance settlement gains of $4 million and $14 million for the nine months ended September 30, 2015 and 2014, respectively. There were no gains or losses for the three months ended September 30, 2015. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $10 million and $8 million for the three months ended September 30, 2015 and 2014, respectively, and $25 million and $18 million for the nine months ended September 30, 2015 and 2014, respectively.

(c) Includes a gain of $5 million for the nine months ended September 30, 2014 resulting from TLLP’s sale of its Boise terminal.

(d) Reflects acquisition costs included in general and administrative expenses primarily related to the merger of QEPM into TLLP.

29

(e) Several of our contracts contain minimum volume commitments that allow us to charge the customer a deficiency payment if the customer’s actual throughput volumes are less than its minimum volume commitments for the applicable period. In certain contracts, if a customer makes a deficiency payment, that customer may be entitled to offset gathering fees or processing fees in one or more subsequent periods to the extent that such customer’s throughput volumes in those periods exceed its minimum volume commitment. Depending on the specific terms of the contract, revenue under these agreements may be classified as deferred revenue and recognized once all contingencies or potential performance obligations associated with these related volumes have either been satisfied through the gathering or processing of future excess volumes of natural gas, or are expected to expire or lapse through the passage of time pursuant to terms of the applicable agreement. During the nine months ended September 30, 2015, we invoiced customers for deficiency payments. We did not recognize $13 million of revenue related to the billing period as it represented an opening balance sheet asset for the Rockies Natural Gas Business Acquisition; however, TLLP is entitled to the cash receipt from such billings. The timing and amount of deficiency billings vary based on actual shortfall and terms under the applicable agreements.

(f) Includes costs for detailed inspection and maintenance program on the Northwest Products System, which improved the integrity of the Northwest Products Pipeline to meet the intent of the compliance order. The purchase price of the Northwest Products System was reduced to compensate the Partnership for assuming responsibilities to perform this work.

(g) Maintenance capital expenditures include expenditures required to ensure the safety, reliability, integrity and regulatory compliance of our assets. Maintenance capital expenditures included in the Distributable Cash Flow calculation are presented net of Predecessor amounts.

(h) Adjustments represent cash distributions in excess of (or less than) our controlling interest in income and depreciation as well as other adjustments for depreciation and maintenance capital expenditures applicable to the noncontrolling interest obtained in the Rockies Natural Gas Business Acquisition.

(i) Excludes $2 million of undistributed QEPM earnings prior to the Merger for the three and nine months ended September 30, 2015 that unitholders of QEPM were entitled to receive, but TLLP unitholders will now be entitled to receive as a result of the Merger.

(j) Reflects the adjustment to include the noncontrolling interest in QEPM as controlling interest based on the pro forma assumption that the Merger occurred on January 1, 2015.

Consolidated Results

Our net earnings for the three months ended September 30, 2015 (“2015 Quarter”) increased$44 million to $77 million from $33 million for the three months ended September 30, 2014 (“2014 Quarter”). The increase in net earnings was due to an increase in revenue of $132 million, or 88%, to $282 million driven primarily by the Rockies Natural Gas Business Acquisition and the West Coast Logistics Assets Acquisition. The increase in revenue was partially offset by:

• an increase in operating and maintenance expenses of $43 million, or 78%, primarily related to the operations of the Rockies Natural Gas Assets;

• an increase in general and administrative expenses of $12 million, or 75%, primarily related to higher allocated overhead to support the Partnership’s growing business;

• an increase in depreciation and amortization expenses of $26 million, primarily as a result of depreciation on the assets and intangibles acquired in the Rockies Natural Gas Business Acquisition; and

• an increase in net interest and financing costs of $9 million, primarily related to the issuance of senior notes used to fund the Rockies Natural Gas Business Acquisition.

Our net earnings for the nine months ended September 30, 2015 (“2015 Period”) increased$117 million to $223 million from $106 million for the nine months ended September 30, 2014 (“2014 Period”). The increase in net earnings was due to an increase in revenue of $410 million, or 100%, to $820 million driven primarily by the Rockies Natural Gas Business Acquisition and the West Coast Logistics Assets Acquisition. The increase in revenue was partially offset by:

• an increase in operating and maintenance expenses of $123 million, or 79%, primarily related to the operations of the Rockies Natural Gas Assets;

• an increase in general and administrative expenses of $42 million, or 108%, primarily related to higher allocated overhead to support the Partnership’s growing business as well as $7 million related to acquisition and integration expenses for the Rockies Natural Gas Business Acquisition and the Merger;

• an increase in depreciation and amortization expenses of $81 million, primarily as a result of depreciation on the assets and intangibles acquired in the Rockies Natural Gas Business Acquisition; and

• an increase in net interest and financing costs of $49 million, related to the issuance of senior notes used to fund the Rockies Natural Gas Business Acquisition.

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Gathering Segment

The following table and discussion is an explanation of our results of operations of the Gathering segment for the three and nine months ended September 30, 2015 and 2014 (in millions, except volumes, revenue per barrel and revenue per million British thermal units (“MMBtu”) amounts). Our financial information for the Gathering segment includes the results of the crude oil and natural gas gathering systems acquired in the Rockies Natural Gas Business Acquisition for the three and nine months ended September 30, 2015.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Revenues
Crude oil gathering pipeline revenues	$	31	$	17	$	88	$	42
Crude oil gathering trucking revenues	10		15		37		42
Gas gathering revenues (a)	46		—		128		—
Total Revenues	87		32		253		84
Costs and Expenses
Operating and maintenance expenses (b)	27		13		74		38
General and administrative expenses	2		2		8		3
Depreciation and amortization expenses	16		2		50		5
Total Costs and Expenses	45		17		132		46
Gathering Segment Operating Income	$	42	$	15	$	121	$	38
Volumes
Crude oil gathering pipeline throughput (bpd)	198,929		135,510		181,962		114,359
Average crude oil gathering pipeline revenue per barrel	$	1.71	$	1.38	$	1.77	$	1.35
Crude oil gathering trucking volume (bpd)	34,495		50,746		41,918		47,466
Average crude oil gathering trucking revenue per barrel	$	3.14	$	3.30	$	3.24	$	3.24
Gas gathering throughput (thousands of MMBtu/d) (a)	1,115		—		1,069		—
Average gas gathering revenue per MMBtu	$	0.45	$	—	$	0.44	$	—

_____________

(a) Natural gas gathering revenues and volumes relate to the operations acquired in the Rockies Natural Gas Business Acquisition.

(b) Operating and maintenance expenses include imbalance settlement losses of $1 millionand imbalance settlement gains of $1 million for the three and nine months ended September 30, 2015, respectively, inclusive of a $2 million market loss adjustment and imbalance settlement gains of $3 million and $6 million for the three and nine months ended September 30, 2014, respectively.

Three Months EndedSeptember 30, 2015 Compared to Three Months EndedSeptember 30, 2014

Volumes. Average crude oil gathering pipeline throughput volumes increased63,419 bpd, or 47%, in the 2015 Quarter as a result of the expansion of our High Plains System and the acquisition of the Rockies Natural Gas Assets, including a 67,023 bpd increase in third-party volumes, offset by a 3,638 bpd decrease in affiliate volumes. Crude oil gathering trucking volumes decreased 16,251 bpd, or 32%, during the 2015 Quarter as more volumes were gathered directly on to our High Plains Pipeline. Average gas gathering throughput volumes were 1,115 thousand MMBtu/d for the 2015 Quarter, which contributed approximately 53% of total Gathering segment revenue.

Financial Results. Gathering revenues increased$55 million, or 172%, to $87 million for the 2015 Quarter compared to $32 million in the 2014 Quarter primarily due to the Rockies Natural Gas Assets as well as higher crude oil pipeline throughput on our High Plains Pipeline. Partially offsetting the increase are decreases in revenues due to lower crude oil gathering trucking volumes in the 2015 Quarter relative to the 2014 Quarter due to increased usage of the High Plains Pipeline in lieu of trucking.

Operating and maintenance expenses increased$14 million, or 108%, to $27 million in the 2015 Quarter compared to $13 million in the 2014 Quarter primarily related to costs associated with the Rockies Natural Gas Assets as well as the increased throughput on the High Plains System.

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Nine Months EndedSeptember 30, 2015 Compared to Nine Months EndedSeptember 30, 2014

Volumes. Average crude oil gathering pipeline throughput volumes increased67,603 bpd, or 59%, in the 2015 Period as a result of the expansion of our High Plains System and the acquisition of the Rockies Natural Gas Assets. This increase was almost entirely due to third-party volumes. Crude oil gathering trucking volumes decreased 5,548 bpd during the 2015 Period as more volumes were gathered on to our High Plains Pipeline. Average gas gathering throughput volumes were 1,069 thousand MMBtu/d for the 2015 Period, which contributed approximately 51% of total Gathering segment revenue.

Financial Results. Gathering revenues increased$169 million, or 201%, to $253 million for the 2015 Period compared to $84 million in the 2014 Period primarily as a result of the Rockies Natural Gas Assets as well as higher crude oil pipeline throughput on our High Plains Pipeline and increased third-party volumes. Partially offsetting the increase are decreases in revenues due to lower crude oil gathering trucking volumes in the 2015 Period relative to the 2014 Period due, in part, to declines in crude oil drilling and increased usage of the High Plains Pipeline in lieu of trucking.

Operating and maintenance expenses increased$36 million, or 95%, to $74 million in the 2015 Period compared to $38 million in the 2014 Period primarily related to costs associated with the Rockies Natural Gas Assets as well as the increased throughput on the High Plains System.

Processing Segment

The following table and discussion is an explanation of our results of operations of the Processing segment for the three and nine months ended September 30, 2015 (in millions, except MMBtu/d, bpd and revenue per MMBtu and fee per barrel). The Processing segment was added as a result of the Rockies Natural Gas Business Acquisition on December 2, 2014, which included natural gas processing operations. Therefore, there was no activity to report for the processing segment for the three and nine months ended September 30, 2014.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2015		2015
Revenues
NGL processing revenues	$	26	$	71
Fee-based processing revenues	28		81
Other processing revenues (a)	17		53
Total Revenues	71		205
Costs and Expenses
Operating and maintenance expenses (a)	31		91
General and administrative expenses	—		4
Depreciation and amortization expenses	11		33
Total Costs and Expenses	42		128
Processing Segment Operating Income	$	29	$	77
Volumes
NGL processing throughput (bpd)	7,813		7,517
Average keep-whole fee per barrel of NGL	$	35.75	$	34.26
Fee-based processing throughput (thousands of MMBtu/d)	767		742
Average fee-based processing revenue per MMBtu	$	0.39	$	0.40

_____________

(a) Other processing revenues include revenues associated with transportation and fractionation services that are settled with the customers based on actual costs incurred, which are included within operating and maintenance expenses.

Three Months Ended September 30, 2015

Volumes. Average fee-based processing volumes were 767 thousand MMBtu/d and average NGL processing volumes totaled 7,813 bpd for the 2015 Quarter.

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Financial Results. Total processing revenues were $71 million contributing approximately 25% to the Partnership’s total revenues for the 2015 Quarter. Operating and maintenance expenses were $31 million in the 2015 Quarter, which represents approximately 32% of total operating and maintenance expenses for the 2015 Quarter.

Nine Months Ended September 30, 2015

Volumes. Average fee-based processing volumes were 742 thousand MMBtu/d and average NGL processing volumes totaled 7,517 bpd for the 2015 Period.

Financial Results. Total processing revenues were $205 million contributing approximately 25% to the Partnership’s total revenues for the 2015 Period. Operating and maintenance expenses were $91 million in the 2015 Period, which represents approximately 33% of total operating and maintenance expenses for the 2015 Period.

Terminalling and Transportation Segment

The following tables and discussion are an explanation of our results of operations of the Terminalling and Transportation segment for the three and nine months ended September 30, 2015 and 2014 (in millions, except barrel and per barrel amounts).

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Revenues
Terminalling revenues	$	93	$	89	$	275	$	244
Pipeline transportation revenues	31		29		87		82
Total Revenues	124		118		362		326
Costs and Expenses
Operating and maintenance expenses (a)	40		42		113		117
General and administrative expenses	10		8		26		22
Depreciation and amortization expenses	17		16		49		46
Net gain on asset disposals and impairments	—		—		—		(4		)
Total Costs and Expenses	67		66		188		181
Terminalling and Transportation Operating Income	$	57	$	52	$	174	$	145
Volumes
Terminalling throughput (bpd)	964,314		942,930		931,752		919,356
Average terminalling revenue per barrel	$	1.05	$	1.03	$	1.08	$	0.97
Pipeline transportation throughput (bpd)	838,212		843,293		819,239		824,468
Average pipeline transportation revenue per barrel	$	0.40	$	0.36	$	0.39	$	0.36

____________

(a) Operating and maintenance expenses include imbalance settlement gains of $1 million and $7 million forthe three months ended September 30, 2015 and 2014, respectively, and $3 million and $9 million for the nine months ended September 30, 2015 and 2014, respectively.

Three Months EndedSeptember 30, 2015 Compared to Three Months EndedSeptember 30, 2014

Volumes. Terminalling throughput volumes increased21,384 bpd in the 2015 Quarter compared to the 2014 Quarter due to lower 2014 Quarter throughput at our California marine terminals. Pipeline transportation throughput volumes decreased 5,081 bpd in the 2015 Quarter compared to the 2014 Quarter primarily due to scheduled maintenance on our Tesoro Alaska Pipeline.

Financial Results. Revenues increased$6 million, or 5%, to $124 million in the 2015 Quarter compared to $118 million in the 2014 Quarter primarily as a result of the commercial agreements executed with Tesoro at the time of the West Coast Logistics Assets Acquisition.

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Nine Months EndedSeptember 30, 2015 Compared to Nine Months EndedSeptember 30, 2014

Volumes. Terminalling throughput volumes increased12,396 bpd in the 2015 Period compared to the 2014 Period primarily as a result of higher volumes at our southern California terminals, which was partially offset by lower volumes at our Salt Lake City terminal. Pipeline transportation throughput volumes decreased 5,229 bpd in the 2015 Period compared to the 2014 Period due to planned maintenance at Tesoro’s Utah refinery and scheduled maintenance on our Tesoro Alaska Pipeline.

Financial Results. Revenues increased$36 million, or 11%, to $362 million in the 2015 Period compared to $326 million in the 2014 Period primarily as a result of the higher volumes at our southern California terminals and the commercial agreements executed with Tesoro at the time of the West Coast Logistics Assets Acquisition.

CAPITAL RESOURCES AND LIQUIDITY

Our primary cash requirements relate to funding capital expenditures, meeting operational needs and paying distributions to our unitholders. We expect our ongoing sources of liquidity to include cash generated from operations, reimbursement for certain maintenance and expansion expenditures, borrowings under the revolving credit facility (the “Revolving Credit Facility”) and issuances of additional debt and equity securities. We believe that cash generated from these sources will be sufficient to meet our short-term working capital, long-term capital expenditure, acquisition and debt servicing requirements and allow us to fund at least the minimum quarterly cash distributions.

ATM Program. On June 25, 2014, we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission (“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 “2014 ATM Program”). The 2014 ATM Program expired during the second quarter of 2015. During the nine months ended September 30, 2015, we issued an aggregate of 819,513 common units, under our 2014 ATM Program, generating net proceeds of approximately $45 million. There were no common units issued during the three months ended September 30, 2015. The net proceeds from sales under the 2014 ATM Program were used for general partnership purposes, which included debt repayment, acquisitions, capital expenditures and additions to working capital.

On August 21, 2015,we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission on August 6, 2015, authorizing the continuous issuance of up to an aggregate of $750 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 “2015 ATM Program”). During the three and nine months ended September 30, 2015, we issued an aggregate of 537,014common units under our 2015 ATM Program, generating net proceeds of approximately$26 million. The net proceeds from sales under the 2015 ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

We paid total fees of approximately $1 millionrelated to the issuance of units under the 2014 and 2015 ATM programs for the nine months ended September 30, 2015.

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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 connection with the Rockies Natural Gas Business Acquisition, our general partner has waived its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). The table below summarizes the quarterly distributions related to our quarterly financial results:

Quarter Ended	Total Quarterly Distribution Per Unit		Total Quarterly Distribution Per Unit, Annualized		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2014	$	0.6675	$	2.67	$	70	February 13, 2015	February 2, 2015
March 31, 2015	0.6950		2.78		70		May 15, 2015	May 4, 2015
June 30, 2015	0.7225		2.89		81		August 14, 2015	August 3, 2015
September 30, 2015 (a)	0.7500		3.00		86		November 13, 2015	November 2, 2015

______________

(a) This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

Debt Overview

Our debt, net of unamortized issuance costs, of$2.6 billion at September 30, 2015 is summarized as follows (in millions):

Debt principal, including current maturities:	September 30, 2015
Revolving Credit Facility	$	280
5.500% Senior Notes due 2019	500
5.875% Senior Notes due 2020	470
6.125% Senior Notes due 2021	550
6.250% Senior Notes due 2022	800
Capital lease obligations	8
Total Debt	2,608
Unamortized Issuance Costs (b)	(39		)
Debt, Net of Unamortized Issuance Costs	$	2,569

____________

(b) Includes unamortized premium associated with our 5.875% Senior Notes due 2020 of $4 million as of September 30, 2015.

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Revolving Credit Facility

As of September 30, 2015, 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. Borrowings are available under the Revolving Credit Facility up to the total loan availability of the 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 Services L.L.C., and secured by substantially all of our assets. We had$280 million of borrowings outstanding under the Revolving Credit Facility, resulting in a total unused loan availability of $620 million or 69% of the borrowing capacity as of September 30, 2015. The weighted average interest rate for borrowings under our Revolving Credit Facility was 2.69% at September 30, 2015. The Revolving Credit Facility is scheduled to mature on December 2, 2019.

The Revolving Credit Facility was subject to the following expenses and fees at September 30, 2015:

Credit Facility	30 day Eurodollar (LIBOR) Rate	Eurodollar Margin	Base Rate	Base Rate Margin	Commitment Fee (unused portion)
Revolving Credit Facility (c)	0.19%	2.50%	3.25%	1.50%	0.50%

____________

(c) 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.

The Revolving Credit Facility and our Senior Notes due 2019, 2020, 2021 and 2022 contain covenants that may, among other things, limit or restrict our ability (as well as the ability of our subsidiaries) to engage in certain activities. There have been no changes in these covenants from those described in the Annual Report on 10-K for the year ended December 31, 2014. We do not believe that these limitations will restrict our ability to pay distributions. Additionally, the Revolving Credit Facility contains covenants that require us to maintain certain interest coverage and leverage ratios. We submit compliance certifications to the bank quarterly, and we were in compliance with our debt covenants as of September 30, 2015.

Cash Flow Summary

Components of our cash flows are set forth below (in millions):

	Nine Months Ended September 30,
	2015			2014
Cash Flows From (Used In):
Operating Activities	$	364		$	154
Investing Activities	(240		)	(106		)
Financing Activities	(132		)	(67		)
Decrease in Cash and Cash Equivalents	$	(8	)	$	(19	)

Operating Activities. Net cash from operating activities increased$210 million to $364 million in the 2015 Period compared to $154 million for the 2014 Period primarily due to a significant contribution of operating income from the Rockies Natural Gas Business Acquisition as well as incremental cash flow from growth on the High Plains System and commercial agreements executed in connection with the West Coast Logistics Assets Acquisition.

Investing Activities. Net cash used in investing activities for the 2015 Period increased$134 millionto $240 million compared to $106 million in the 2014 Period. The increase related to this outflow was a result of higher capital expenditures in the 2015 Period including spending related to the construction of the Connolly Gathering System, the second phase of the Bakken area storage hub, and various projects on our Southern California distribution system. See “Capital Expenditures” below for a discussion of the various maintenance and growth projects in the 2015 Period, including those reimbursed by our customers.

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Financing Activities. Net cash used in financing activities for the 2015 Period was $132 million compared to $67 million for the 2014 Period. We paid higher quarterly cash distributions totaling $221 millionduring the 2015 Period compared to quarterly cash distributions totaling $118 million paid in the 2014 Period. Additionally, we paid $20 million in distributions to the common public unitholders of QEPM and QEPM’s subsidiaries during the 2015 Period. Cash distributions were offset by $71 million in proceeds from the issuance of units under our 2015 ATM Program and 2014 ATM Program and $20 million of net borrowings under our Revolving Credit Facility during the 2015 Period.

Capital Expenditures

The Partnership’s operations are capital intensive, requiring investments to expand, upgrade or enhance existing operations and to maintain assets, ensuring regulatory compliance. The cost estimates described below are subject to further review, analysis and permitting requirements and include estimates for capitalized interest and labor. Maintenance capital expenditures include expenditures required to maintain equipment reliability and integrity and to address regulatory compliance. Growth capital expenditures include expenditures to purchase or construct new assets and to expand existing facilities or services that may increase throughput capacity on our pipelines, in our terminals and at our processing facilities, increase storage capacity, increase well connections and compression as well as other services at our facilities.

Our total 2015 expected capital expenditures of approximately $345 million includes $45 million of maintenance capital expenditures. We expect to receive reimbursements of $15 million primarily for our maintenance capital expenditures. During the third quarter of 2015, we reduced our estimate for growth capital expenditures by $90 million as a result of cost reductions, scope changes and deferred expenditure timing of several growth projects.

The following table is a summary of our capital expenditures for the three and nine months ended September 30, 2015 and 2014 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Growth	$	81	$	50	$	200	$	117
Maintenance (a)	11		13		35		20
Total Capital Expenditures	$	92	$	63	$	235	$	137

____________________

(a) Reimbursements for maintenance capital expenditures totaled $1 million and $3 million for the 2015 Quarter and 2014 Quarter, respectively, and $4 million for each of the 2015 Period and 2014 Period.

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Growth Capital Expenditures

Our major growth projects include the following:

	Total Project Expected Capital Expenditures		Actual 2015 Capital Expenditures		Expected Capital Expenditures for Remainder of 2015		Expected In-service Date
Connolly Gathering System (a)	$	150	$	93	$	22	2015
Anacortes Light Products Truck Rack (b)	23		10		—		2015
Pinedale and Uinta Compression (c)	110		9		16		2016-2017
High Plains Pipeline Expansion (d)	50		1		13		2016
Charging Eagle Gathering System (e)	40 - 50		—		1		2016
Bakken Area Storage Hub (f)	30		16		13		2016
Southern California Distribution System (g)	20 - 25		17		3		2016-2017

____________________

(a) Connolly Gathering System construction with estimated capital spending of $115 million in 2015. The Connolly Gathering System will gather crude oil from various points in Dunn County, North Dakota for delivery at the existing Connolly Station and is expected to have a capacity of approximately 60,000 bpd. The first barrels were delivered into the main line at the end of 2014 and the project is expected to be completed in November 2015.

(b) A new light products truck rack at the site of the existing Anacortes terminal acquired as part of the West Coast Logistics Assets, which is expected to add an additional 6,000 to 7,000 barrels per day of gasoline and diesel throughput. The project is expected to be operational in November 2015.

(c) Projects to increase compression for our Pinedale and Uinta natural gas gathering systems and expand our gathering system in the Uinta basin with estimated capital spending of $25 million in 2015.

(d) Projects to expand crude oil gathering throughputs on the High Plains Pipeline in McKenzie County, North Dakota.

(e) The construction of the Charging Eagle Gathering System, a crude oil and produced water gathering and treating system in eastern Dunn County, North Dakota.

(f) The construction of the second phase of the Bakken Area Storage Hub (“BASH”) provides storage for the Bakken region with tanks located in two strategic areas of the basin. It has current storage capacity of approximately 780,000 barrels, growing to over 1 million barrels of capacity.

(g) Projects to expand and optimize the southern California distribution system with 2015 expected spending of $20 million. The projects are expected to increase throughput and expand ancillary service capabilities.

Environmental and Other Matters

Environmental Regulation

We are subject to extensive federal, state and local environmental laws and regulations. These laws, which change frequently, regulate the discharge of materials into the environment or otherwise relate to protection of the environment. Compliance with these laws and regulations may require us to remediate environmental damage from any discharge of petroleum, natural gas or chemical substances from our facilities or require us to install additional pollution control equipment on our equipment and facilities. Our failure to comply with these or any other environmental or safety-related regulations could result in the assessment of administrative, civil, or criminal penalties, the imposition of investigatory and remedial liabilities and the issuance of injunctions that may subject us to additional operational constraints.

Future expenditures may be required to comply with the federal, state and local environmental requirements for our various sites, including our storage facilities, pipelines, gas processing complexes and refined products terminals. The impact of these legislative and regulatory developments, if enacted or adopted, could result in increased compliance costs and additional operating restrictions on our business, each of which could have an adverse impact on our liquidity, financial position or results of operations. 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 our initial public offering in April 2011 (“Initial Offering”) and subsequent acquisitions from Tesoro.

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Environmental Liabilities

Contamination resulting from spills of crude oil, natural gas and refined products is not unusual within the terminalling, pipeline, gathering or processing industries. Historic spills at certain of our assets as a result of past operations have resulted in contamination of the environment, including soils and groundwater. Site conditions, including soils and groundwater, are being evaluated at our properties where releases of hydrocarbons and other wastes have occurred. A number of our properties have known hydrocarbon or other hazardous material contamination in the soil and groundwater. See below for our discussion of the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement for more information regarding the indemnification of certain environmental matters provided to us by Tesoro and discussion of certain environmental obligations that were retained by Chevron Pipe Line Company and Northwest Terminalling Company (collectively, “Chevron”) in conjunction with the acquisition of the northwest products system (the “Northwest Products System”).

The Partnership has been party to various environmental matters arising in the ordinary course of business. The outcome of these matters cannot always be accurately predicted, but the Partnership recognizes liabilities for these matters based on estimates and applicable accounting guidelines and principles. We have accrued liabilities for these expenses and believe these accruals are adequate based on current information and projections that can be reasonably estimated. Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible that these estimates will change as more information becomes available. Our accruals for these environmental expenditures totaled $15 million and $32 million at September 30, 2015 and December 31, 2014, respectively.

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 to restore the site for agricultural use. We spent $17 millionduring the nine months ended September 30, 2015 on remediation related to the Crude Oil Pipeline Release. Our condensed consolidated balance sheet included $8 millionand $25 million in accrued environmental liabilities related to the Crude Oil Pipeline Release at September 30, 2015 and December 31, 2014, respectively. This incident was covered by our pollution legal liability insurance policy, subject to a $1 million deductible and a $25 million loss limit.Pursuant to this policy, there were no insurance recovery receivables related to the Crude Oil Pipeline Release at September 30, 2015, and $18 million at December 31, 2014. As of September 30, 2015, the total estimated remediation costs were $42 million, which exceeded our pollution liability legal insurance policy and we are continuously seeking to improve remediation methods and associated costs.

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”) and the NOV received from the North Dakota Department of Health that is discussed further in Item 1 of Part II of this Quarterly Report on Form 10-Q 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 Pipe Line Company and Northwest Terminalling Company (collectively, “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. Chevron retained the financial and operational responsibility to remediate the site of the Diesel Pipeline Release, including the payment of any monetary fines and penalties assessed by any government authority arising from this incident, prior to and subsequent to the date of acquisition until June 19, 2015. 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. On March 6, 2015, PHMSA issued a closure letter indicating that we have complied with all the terms of the CAO and that no further action is required. We have recognized $4 million and $6 million in as environmental remediation liabilities at September 30, 2015 and December 31, 2014, respectively, representing our best estimate of liabilities remaining for all assets acquired from Chevron.

Other Environmental Spending

We completed a detailed inspection and maintenance program in the 2015 Period, which included spending of $22 million inception to date to perform inspections and repairs that improved the integrity of the Northwest Products System. This included the costs to comply with the CAO and also costs expected for inspections and repairs on other sections of the pipeline. The purchase price of the Northwest Products system was reduced by $45 million to compensate the Partnership for assuming responsibilities under the CAO and to perform additional inspection and maintenance as the Partnership deemed necessary.

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Tesoro 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 subsequent acquisitions from Tesoro. See Note 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of the Amended Omnibus Agreement.

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 QEP Field Services Company 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, the assets and agreement discussed above were 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 $18 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 Energy Inc. (“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. XTO has also withheld payments for amounts unrelated to the allocation of charges they have challenged. While we cannot currently estimate the final amount or timing of the resolution of this matter, we believe the outcome will not have a material impact on our liquidity, financial position, or results of operations.

IMPORTANT INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (including information incorporated by reference) includes and references “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. These statements relate to, among other things, expectations regarding revenues, cash flows, capital expenditures and other financial items. These statements also relate to our business strategy, goals and expectations concerning our market position, future operations and profitability. We have used the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will,” “would” and similar terms and phrases to identify forward-looking statements in this Quarterly Report on Form 10-Q, which speak only as of the date the statements were made.

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Although we believe the assumptions upon which these forward-looking statements are based are reasonable, any of these assumptions could prove to be inaccurate and the forward-looking statements based on these assumptions could be incorrect. The matters discussed in these forward-looking statements are subject to risks, uncertainties and other factors that could cause actual results and trends to differ materially from those made, projected, or implied in or by the forward-looking statements depending on a variety of uncertainties or other factors including, but not limited to:

• the suspension, reduction or termination of our customer’s obligation under commercial agreements or our secondment agreement;

• changes in global economic conditions and the effects of a global economic downturn on Tesoro’s business and the business of its suppliers, customers, business partners and credit lenders;

• a material decrease in Tesoro’s profitability;

• a material decrease in the crude oil and natural gas produced in the Bakken Region;

• a material decrease in the natural gas produced in the Rockies Region;

• disruptions due to equipment interruption or failure at our facilities, Tesoro’s facilities or third-party facilities on which Tesoro’s business is dependent;

• changes in the expected value of and benefits derived from acquisitions, including the Rockies Natural Gas Business acquisition;

• impact of QEP Resources’ and Questar Gas Company’s failure to perform under the terms of our gathering agreements as they are our largest customers in TLLP’s natural gas business;

• the risk of contract cancellation, non-renewal or failure to perform by Tesoro’s customers and Tesoro’s inability to replace such contracts and/or customers;

• Tesoro’s ability to remain in compliance with the terms of its outstanding indebtedness;

• the timing and extent of changes in commodity prices and demand for refined products, natural gas and NGLs;

• actions of customers and competitors;

• changes in our cash flow from operations;

• state and federal environmental, economic, health and safety, energy and other policies and regulations, including those related to climate change and any changes therein and any legal or regulatory investigations, delays or other factors beyond our control;

• operational hazards inherent in refining operations and in transporting and storing crude oil, natural gas, NGLs and refined products;

• earthquakes or other natural disasters affecting operations;

• changes in capital requirements or in execution of planned capital projects;

• the availability and costs of crude oil, other refinery feedstocks and refined products;

• changes in the cost or availability of third-party vessels, pipelines and other means of delivering and transporting crude oil, feedstocks and refined products;

• direct or indirect effects on our business resulting from actual or threatened terrorist incidents or acts of war;

• weather conditions affecting our or Tesoro’s operations or the areas in which Tesoro markets its refined products;

• seasonal variations in demand for refined products;

• adverse rulings, judgments, or settlements in litigation or other legal or tax matters, including unexpected environmental remediation costs in excess of any accruals, which affect us or Tesoro;

• risks related to labor relations and workplace safety;

• changes in insurance markets impacting costs and the level and types of coverage available;

• the coverage and ability to recover claims under our insurance policies; and

• political developments.

Many of these factors, as well as other factors, are described in our filings with the SEC. All future written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the previous statements. We undertake no obligation to update any information contained herein or to publicly release the results of any revisions to any forward-looking statements that may be made to reflect events or circumstances that occur, or that we become aware of, after the date of this Quarterly Report on Form 10-Q.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market Risk

Market risk is the risk of loss arising from adverse changes in market rates and prices. As we do not own the refined products, natural gas or crude oil that are shipped through our pipelines, distributed through our terminals or held in our storage facilities we have minimal direct exposure to risks associated with fluctuating commodity prices. In addition, our commercial agreements with Tesoro are indexed for inflation and contain fuel surcharge provisions that are designed to substantially mitigate our exposure to increases in diesel fuel prices and the cost of other supplies used in our business. Our exposure to commodity price risk related to imbalance gains and losses or to diesel fuel or other supply costs are currently not expected to be material to our financial position and we do not intend to hedge our exposure.

We bear a limited degree of commodity price risk with respect to our gathering contracts. Specifically, pursuant to our contracts, we retain and sell condensate that is recovered during the gathering of natural gas. Thus, a portion of our revenue is dependent on the price received for the condensate. Condensate historically sells at a price representing a slight discount to the price of crude oil. We consider our exposure to commodity price risk associated with these arrangements to be minimal based on the amount of revenues generated under these arrangements compared to our overall revenues. We do not enter into commodity derivative instruments because of the minimal impact of commodity price risk on our liquidity, financial position and results of operations. Assuming all other factors remained constant, a $1 change in condensate pricing, based on our quarter-to-date average throughput, would be immaterial to our consolidated operating income. This analysis may differ from actual results.

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 British thermal unit 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. 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 (the “Keep-Whole Commodity Agreement”). 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.

Interest Rate Risk

Our use of debt directly exposes us to interest rate risk. Variable-rate debt, such as borrowings under our Revolving Credit Facility, exposes us to short-term changes in market rates that impact our interest expense. Fixed rate debt, such as our Senior Notes, exposes us to changes in the fair value of our debt due to changes in market interest rates. Fixed rate debt also exposes us to the risk that we may need to refinance maturing debt with new debt at higher rates, or that we may be obligated to rates higher than the current market. The fair value of our fixed rate debt was estimated using quoted market prices. The carrying value and fair value of our debt were both approximately $2.6 billion as of September 30, 2015 and December 31, 2014. These carrying and fair values of our debt do not include the unamortized issuance costs associated with our total debt. Unless interest rates increase significantly in the future, our exposure to interest rate risk should be minimal. With all other variables constant, a 0.25% change in the interest rate associated with the borrowings outstanding under our Revolving Credit Facility at September 30, 2015 would change annual interest expense by less than $1 million. As of September 30, 2015, we had $280 millionof borrowings under our Revolving Credit Facility. Any change in interest rates would affect cash flows, but not the fair value of the debt we incur under our Revolving Credit Facility.

We do not currently have in place any hedges or forward contracts to reduce our exposure to interest rate risks; however, we continue to monitor the market and our exposure, and may enter into these transactions in the future. We believe in the short-term we have acceptable interest rate risk and continue to monitor the risk on our long-term obligations.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Our disclosure controls and procedures are designed to provide reasonable assurance that the information that we are required to disclose in reports we file under the Securities Exchange Act of 1934, as amended (“the Exchange Act”), is accumulated and appropriately communicated to management. In 2014, we completed a transition from the 1992 framework of the Committee of Sponsoring Organizations of the Treadway Commission to its 2013 framework for assessing our internal control effectiveness over financial reporting. There have been no significant changes in our internal controls over financial reporting (as defined by applicable Securities and Exchange Commission rules) during the quarter ended September 30, 2015 that have materially affected or are reasonably likely to materially affect these controls.

We carried out an evaluation required by Rule 13a-15(b) of the Exchange Act, under the supervision and with the participation of our management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures at the end of the reporting period. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective.

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PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

In the ordinary course of business, we become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. Large, and sometimes unspecified, damages or penalties may be sought from us in some matters and certain matters may require years to resolve. Although we cannot provide assurance, we believe that an adverse resolution of the matters described below, except as may be specifically disclosed, will not have a material adverse impact on our liquidity, financial position, or results of operations.

On October 7, 2015, we received an offer to settle a Notice of Violation (“NOV”) received from the North Dakota Department of Health. The NOV was issued on March 21, 2015 and alleges violations of water pollution regulations as a result of a release of crude oil that occurred near Tioga, North Dakota on our gathering and transportation pipeline system in September 2013. While we are evaluating the settlement offer, we cannot currently estimate the timing of the resolution of this matter. The ultimate resolution of this matter will not have a material impact on our liquidity, financial position, or results of operations.

ITEM 1A. RISK FACTORS

There have been no significant changes from the risk factors previously disclosed in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2014.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

We may acquire units to satisfy tax withholding obligations in connection with the vesting of units issued to certain employees. There were no such units acquired during the three months ended September 30, 2015.

ITEM 6. EXHIBITS

(a)Exhibits

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Exhibit Number	Description of Exhibit
2.1	Agreement and Plan of Merger, dated as of April 6, 2015, by and among Tesoro Logistics LP, Tesoro Logistics GP, LLC, QEP Field Services, LLC, TLLP Merger Sub LLC, QEP Midstream Partners, LP, and QEP Midstream Partners GP, LLC (incorporated by reference herein to Exhibit 2.1 to the Partnership’s Current Report on Form 8-K filed on April 6, 2015, File 1-35143).
4.1	Second Supplemental Indenture, dated as of May 21, 2015, among TLLP Merger Sub LLC, Tesoro Logistics LP, Tesoro Logistics Finance Corp., the guarantors named therein and U.S. Bank National Association, as trustee, relating to the 5.50% Senior Notes due 2019 and the 6.25% Senior Notes due 2022 (incorporated by reference herein to Exhibit 4.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
4.2	Fourth Supplemental Indenture, dated as of May 21, 2015, among TLLP Merger Sub LLC, Tesoro Logistics LP, Tesoro Logistics Finance Corp., the guarantors named therein and U.S. Bank National Association, as trustee, relating to the 6.125% Senior Notes due 2021 (incorporated by reference herein to Exhibit 4.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
4.3	Sixth Supplemental Indenture, dated as of May 21, 2015, among TLLP Merger Sub LLC, Tesoro Logistics LP, Tesoro Logistics Finance Corp., the guarantors named therein and U.S. Bank National Association, as trustee, relating to the 5.875% Senior Notes due 2020 (incorporated by reference herein to Exhibit 4.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
10.1	Support Agreement, dated as of April 6, 2015 by and among QEP Midstream Partners, LP, Tesoro Logistics LP, and QEP Field Services, LLC (incorporated by reference herein to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K filed on April 6, 2015, File 1-35143).
10.2	Tesoro Logistics LP Non-Employee Director Compensation Program. (incorporated by reference herein to Exhibit 10.2 to the Partnership’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2015, File 1-35143)
10.3	Amendment No. 2 to the Third Amended and Restated Omnibus Agreement, dated as of August 3, 2015, among Tesoro Corporation, Tesoro Refining & Marketing Company LLC, Tesoro Companies, Inc., Tesoro Alaska Company LLC, Tesoro Logistics LP and Tesoro Logistics GP, LLC (incorporated by reference herein to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
10.4	Termination of First Amended and Restated Omnibus Agreement, dated as of August 3, 2015, among Tesoro Logistics LP and Tesoro Logistics GP, LLC, QEP Midstream Partners GP, LLC, QEP Midstream Partners, LP, and QEP Midstream Partners Operating, LLC (incorporated by reference herein to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
10.5	Termination of Credit Agreement, dated as of August 3, 2015, between QEP Field Services, LLC and QEP Midstream Partners, LP (incorporated by reference herein to Exhibit 10.5 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2015, File No. 1‑35143).
10.6	Amended and Restated QEP Midstream Partners, LP 2013 Long-Term Incentive Plan (incorporated by reference herein from Exhibit 10.1 to the Partnership’s Current Report on Form 8-K filed on July 23, 2015, File No. 1-35143).
*31.1	Certification by Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2	Certification by Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*32.1	Certification by Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*32.2	Certification by Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
**101.INS	XBRL Instance Document
**101.SCH	XBRL Taxonomy Extension Schema Document
**101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
**101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
**101.LAB	XBRL Taxonomy Extension Label Linkbase Document
**101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

______________

* Filed herewith

** Submitted electronically herewith

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SIGNATURES

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

		TESORO LOGISTICS LP
		By:	Tesoro Logistics GP, LLC
			Its general partner
Date:	October 29, 2015	By:	/s/ GREGORY J. GOFF
			Gregory J. Goff
			Chief Executive Officer
			(Principal Executive Officer)
Date:	October 29, 2015	By:	/s/ STEVEN M. STERIN
			Steven M. Sterin
			Vice President and Chief Financial Officer
			(Principal Financial Officer)

46

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Gregory J. Goff, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Tesoro Logistics LP;

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this quarterly report based on such evaluation; and

(d) Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 29, 2015	/s/ GREGORY J. GOFF
		Gregory J. Goff
		Chief Executive Officer of Tesoro Logistics GP, LLC
		(the general partner of Tesoro Logistics LP)

EX-31.2

Exhibit 31.2

CERTIFICATION PURSUANT TO

SECTION 302 OF

THE SARBANES-OXLEY ACT OF 2002

I, Steven M. Sterin, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Tesoro Logistics LP;

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this quarterly report based on such evaluation; and

(d) Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	October 29, 2015	/s/ STEVEN M. STERIN
		Steven M. Sterin
		Chief Financial Officer of Tesoro Logistics GP, LLC
		(the general partner of Tesoro Logistics LP)

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Tesoro Logistics LP (the “Partnership”) on Form 10-Q for the period ended September 30, 2015 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gregory J. Goff, Chief Executive Officer of Tesoro Logistics GP, LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

/s/ GREGORY J. GOFF

Gregory J. Goff

Chief Executive Officer of Tesoro Logistics GP, LLC

(the general partner of Tesoro Logistics LP)

October 29, 2015

A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Tesoro Logistics LP (the “Partnership”) on Form 10-Q for the period ended September 30, 2015 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven M. Sterin, Chief Financial Officer of Tesoro Logistics GP, LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

/s/ STEVEN M. STERIN

Steven M. Sterin

Chief Financial Officer of Tesoro Logistics GP, LLC

(the general partner of Tesoro Logistics LP)

October 29, 2015

A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Equity Equity, Narrative (Details) - shares	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Common units outstanding (units)	88,633,988	80,125,930
General partner units outstanding (units)	1,631,448	1,631,448
General partner's ownership interest	2.00%
Public common units
Common units outstanding (units)	60,452,240
Tesoro common units
Common units outstanding (units)	28,181,748
General Partner
General partner units outstanding (units)	1,631,448
Tesoro
Tesoro's ownership interest	33.00%

XML

Condensed Consolidating Financial Information Balance Sheet (Details) - USD ($) $ in Millions		Sep. 30, 2015	Dec. 31, 2014		Sep. 30, 2014	Dec. 31, 2013
Current Assets
Cash and cash equivalents		$ 11	$ 19	[1]	$ 4	$ 23
Receivables, net
Trade		132	122	[1]
Affiliate		80	69	[1]
Other		0	18	[1]
Prepayments and other		8	7	[1]
Total Current Assets		231	235	[1]
Net property, plant and equipment		3,432	3,306	[1]
Acquired intangibles, net		952	973	[1]
Goodwill		157	164	[1]
Investment in Unconsolidated Affiliates		56	57	[1]
Investments in subsidiaries		0	0	[1]
Long-term intercompany receivable		0	0	[1]
Other Noncurrent Assets		23	30	[1]
Total Assets		4,851	4,765	[1]
Accounts payable
Trade		85	126	[1]
Affiliate		52	53	[1]
Accrued interest and financing costs		65	28	[1]
Other current liabilities		64	79	[1]
Total Current Liabilities		266	286	[1]
Long-term intercompany payable		0	0	[1]
Other noncurrent liabilities		49	45	[1]
Debt, net of unamortized issuance costs		2,569	2,544	[1]
Equity - TLLP		1,883	1,455	[1]
Equity - Noncontrolling interest		84	435	[1]
Total Liabilities and Equity		4,851	4,765	[1]
Parent
Current Assets
Cash and cash equivalents		7	0	[1]
Receivables, net
Trade		0	0	[1]
Affiliate		2	3	[1]
Other	[1]		0
Prepayments and other		5	3	[1]
Total Current Assets		14	6	[1]
Net property, plant and equipment		0	1	[1]
Acquired intangibles, net		0	0	[1]
Goodwill		0	0	[1]
Investment in Unconsolidated Affiliates		0	0	[1]
Investments in subsidiaries		4,814	4,233	[1]
Long-term intercompany receivable		0	0	[1]
Other Noncurrent Assets		1	0	[1]
Total Assets		4,829	4,240	[1]
Accounts payable
Trade		2	6	[1]
Affiliate		4	3	[1]
Accrued interest and financing costs		65	28	[1]
Other current liabilities		21	21	[1]
Total Current Liabilities		92	58	[1]
Long-term intercompany payable		292	191	[1]
Other noncurrent liabilities		0	0	[1]
Debt, net of unamortized issuance costs		2,561	2,536	[1]
Equity - TLLP		1,884	1,455	[1]
Equity - Noncontrolling interest		0	0	[1]
Total Liabilities and Equity		4,829	4,240	[1]
Guarantor Subsidiaries
Current Assets
Cash and cash equivalents		0	17	[1]
Receivables, net
Trade		131	121	[1]
Affiliate		81	66	[1]
Other	[1]		18
Prepayments and other		5	4	[1]
Total Current Assets		217	226	[1]
Net property, plant and equipment		2,778	2,639	[1]
Acquired intangibles, net		577	590	[1]
Goodwill		63	48	[1]
Investment in Unconsolidated Affiliates		42	43	[1]
Investments in subsidiaries		142	152	[1]
Long-term intercompany receivable		184	196	[1]
Other Noncurrent Assets		22	30	[1]
Total Assets		4,025	3,924	[1]
Accounts payable
Trade		83	120	[1]
Affiliate		53	50	[1]
Accrued interest and financing costs		0	0	[1]
Other current liabilities		44	60	[1]
Total Current Liabilities		180	230	[1]
Long-term intercompany payable		0	5	[1]
Other noncurrent liabilities		57	54	[1]
Debt, net of unamortized issuance costs		8	8	[1]
Equity - TLLP		3,780	3,598	[1]
Equity - Noncontrolling interest		0	29	[1]
Total Liabilities and Equity		4,025	3,924	[1]
Non-Guarantors
Current Assets
Cash and cash equivalents		4	2	[1]
Receivables, net
Trade		1	1	[1]
Affiliate		2	0	[1]
Other	[1]		0
Prepayments and other		0	0	[1]
Total Current Assets		7	3	[1]
Net property, plant and equipment		179	188	[1]
Acquired intangibles, net		0	0	[1]
Goodwill		0	0	[1]
Investment in Unconsolidated Affiliates		0	0	[1]
Investments in subsidiaries		0	0	[1]
Long-term intercompany receivable		0	5	[1]
Other Noncurrent Assets		0	0	[1]
Total Assets		186	196	[1]
Accounts payable
Trade		0	0	[1]
Affiliate		0	0	[1]
Accrued interest and financing costs		0	0	[1]
Other current liabilities		1	0	[1]
Total Current Liabilities		1	0	[1]
Long-term intercompany payable		2	0	[1]
Other noncurrent liabilities		1	1	[1]
Debt, net of unamortized issuance costs		0	0	[1]
Equity - TLLP		142	152	[1]
Equity - Noncontrolling interest		40	43	[1]
Total Liabilities and Equity		186	196	[1]
Consolidating Adjustments
Current Assets
Cash and cash equivalents		0	0	[1]
Receivables, net
Trade		0	0	[1]
Affiliate		(5)	0	[1]
Other	[1]		0
Prepayments and other		(2)	0	[1]
Total Current Assets		(7)	0	[1]
Net property, plant and equipment		475	478	[1]
Acquired intangibles, net		375	383	[1]
Goodwill		94	116	[1]
Investment in Unconsolidated Affiliates		14	14	[1]
Investments in subsidiaries		(4,956)	(4,385)	[1]
Long-term intercompany receivable		(184)	(201)	[1]
Other Noncurrent Assets		0	0	[1]
Total Assets		(4,189)	(3,595)	[1]
Accounts payable
Trade		0	0	[1]
Affiliate		(5)	0	[1]
Accrued interest and financing costs		0	0	[1]
Other current liabilities		(2)	(2)	[1]
Total Current Liabilities		(7)	(2)	[1]
Long-term intercompany payable		(294)	(196)	[1]
Other noncurrent liabilities		(9)	(10)	[1]
Debt, net of unamortized issuance costs		0	0	[1]
Equity - TLLP		(3,923)	(3,750)	[1]
Equity - Noncontrolling interest		44	363	[1]
Total Liabilities and Equity		$ (4,189)	$ (3,595)	[1]

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Condensed Consolidating Financial Information Condensed Consolidating Financial Information Narrative (Details)	9 Months Ended
	Sep. 30, 2015
5.875% Senior Notes due 2020
Debt instrument, maturity date	Oct. 01, 2020
6.125% Senior Notes due 2021
Debt instrument, maturity date	Oct. 15, 2021

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Related-Party Transactions, Summary of Affiliate Transactions (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Related Party Transactions
Revenues	[1]	$ 152	$ 130	$ 454	$ 358
Operating and maintenance expenses		28	18	77	56
Imbalance settlement gains and reimbursements from Tesoro	[2]	12	17	31	32
General and administrative expenses		$ 16	$ 11	$ 51	$ 28

[1] Tesoro accounted for 54% and 55% of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

[2] Includes imbalance settlement gains of $2 million and $9 million for the three months ended September 30, 2015 and 2014, respectively, and $6 million and $14 million for the nine months ended September 30, 2015 and 2014, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $10 million and $8 million for the three months ended September 30, 2015 and 2014, respectively, and $25 million and $18 million for the nine months ended September 30, 2015 and 2014, respectively.

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Condensed Consolidating Financial Information (Tables)

9 Months Ended

Sep. 30, 2015

Condensed Consolidating Statement of Operations

Condensed Consolidating Statement of Operations

For the Three Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	153		$	7		$	(8	)	$	152
Third-party	—			129			1			—			130
Total Revenues	—			282			8			(8		)	282
Costs and Expenses
Operating and maintenance expenses	—			115			—			(7		)	108
Imbalance settlement gains and reimbursements	—			(10		)	—			—			(10		)
General and administrative expenses	9			19			—			—			28
Depreciation and amortization expenses	—			36			3			5			44
Total Costs and Expenses	9			160			3			(2		)	170
Operating Income (Loss)	(9		)	122			5			(6		)	112
Interest and financing costs, net	—			(34		)	—			(3		)	(37		)
Equity in earnings of unconsolidated affiliates	—			2			—			—			2
Equity in earnings of subsidiaries	83			4			—			(87		)	—
Net Earnings	$	74		$	94		$	5		$	(96	)	$	77
Net earnings attributable to noncontrolling interest	—			(2		)	(1		)	—			(3		)
Net earnings attributable to partners	$	74		$	92		$	4		$	(96	)	$	74

Condensed Consolidating Statement of Operations

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	454		$	20		$	(20	)	$	454
Third-party	—			365			4			(3		)	366
Total Revenues	—			819			24			(23		)	820
Costs and Expenses
Operating and maintenance expenses	—			326			1			(20		)	307
Imbalance settlement gains and reimbursements	—			(29		)	—			—			(29		)
General and administrative expenses	21			60			—			—			81
Depreciation and amortization expenses	—			107			9			16			132
Loss on asset disposals and impairments	—			5			—			(5		)	—
Total Costs and Expenses	21			469			10			(9		)	491
Operating Income (Loss)	(21		)	350			14			(14		)	329
Interest and financing costs, net	—			(103		)	—			(9		)	(112		)
Equity in earnings of unconsolidated affiliates	—			7			—			(1		)	6
Equity in earnings of subsidiaries	225			11			—			(236		)	—
Net Earnings	$	204		$	265		$	14		$	(260	)	$	223
Net earnings attributable to noncontrolling interest	—			(16		)	(3		)	—			(19		)
Net earnings attributable to partners	$	204		$	249		$	11		$	(260	)	$	204

Condensed Consolidating Balance Sheet

Condensed Consolidating Balance Sheet as of September 30, 2015

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	7	$	—	$	4	$	—		$	11
Receivables, net
Trade	—		131		1		—			132
Affiliate	2		81		2		(5		)	80
Prepayments and other	5		5		—		(2		)	8
Total Current Assets	14		217		7		(7		)	231
Net property, plant and equipment	—		2,778		179		475			3,432
Acquired intangibles, net	—		577		—		375			952
Goodwill	—		63		—		94			157
Investment in unconsolidated affiliates	—		42		—		14			56
Investments in subsidiaries	4,814		142		—		(4,956		)	—
Long-term intercompany receivable	—		184		—		(184		)	—
Other noncurrent assets	1		22		—		—			23
Total Assets	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	2	$	83	$	—	$	—		$	85
Affiliate	4		53		—		(5		)	52
Accrued interest and financing costs	65		—		—		—			65
Other current liabilities	21		44		1		(2		)	64
Total Current Liabilities	92		180		1		(7		)	266
Long-term intercompany payable	292		—		2		(294		)	—
Other noncurrent liabilities	—		57		1		(9		)	49
Debt, net of unamortized issuance costs	2,561		8		—		—			2,569
Equity - TLLP	1,884		3,780		142		(3,923		)	1,883
Equity - Noncontrolling interest	—		—		40		44			84
Total Liabilities and Equity	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851

Condensed Consolidating Balance Sheet as of December 31, 2014 (a)

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	—	$	17	$	2	$	—		$	19
Receivables, net
Trade	—		121		1		—			122
Affiliate	3		66		—		—			69
Other	—		18		—		—			18
Prepayments and other	3		4		—		—			7
Total Current Assets	6		226		3		—			235
Net property, plant and equipment	1		2,639		188		478			3,306
Acquired intangibles, net	—		590		—		383			973
Goodwill	—		48		—		116			164
Investment in unconsolidated affiliates	—		43		—		14			57
Investments in subsidiaries	4,233		152		—		(4,385		)	—
Long-term intercompany receivable	—		196		5		(201		)	—
Other noncurrent assets	—		30		—		—			30
Total Assets	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	6	$	120	$	—	$	—		$	126
Affiliate	3		50		—		—			53
Accrued interest and financing costs	28		—		—		—			28
Other current liabilities	21		60		—		(2		)	79
Total Current Liabilities	58		230		—		(2		)	286
Long-term intercompany payable	191		5		—		(196		)	—
Other noncurrent liabilities	—		54		1		(10		)	45
Debt, net of unamortized issuance costs	2,536		8		—		—			2,544
Equity - TLLP	1,455		3,598		152		(3,750		)	1,455
Equity - Noncontrolling interest	—		29		43		363			435
Total Liabilities and Equity	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765

_____________

(a) Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

Condensed Consolidating Statement of Cash Flows

Condensed Consolidating Statement of Cash Flows

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Cash Flows From (Used In) Operating Activities:
Net cash from (used in) operating activities	$	19		$	355		$	21		$	(31	)	$	364
Cash Flows From (Used In) Investing Activities:
Capital expenditures	—			(234		)	—			—			(234		)
Acquisitions	—			(6		)	—			—			(6		)
Investments in subsidiaries	(6		)	—			—			6			—
Net cash used in investing activities	(6		)	(240		)	—			6			(240		)
Cash Flows From (Used In) Financing Activities:
Proceeds from issuance of common units, net of issuance costs	71			—			—			—			71
Quarterly distributions to unitholders	(173		)	—			—			—			(173		)
Quarterly distributions to general partner	(49		)	—			(20		)	21			(48		)
Distributions to noncontrolling interest	—			(15		)	(5		)	—			(20		)
Distributions to subsidiaries	—			—			—			—			—
Borrowings under revolving credit agreement	346			—			—			—			346
Repayments under revolving credit agreement	(326		)	—			—			—			(326		)
Contributions	—			6			—			(6		)	—
Intercompany borrowings (payments)	107			(123		)	6			10			—
Capital contributions by affiliate	18			—			—			—			18
Net cash from (used in) financing activities	(6		)	(132		)	(19		)	25			(132		)
Increase (Decrease) in Cash and Cash Equivalents	7			(17		)	2			—			(8		)
Cash and Cash Equivalents, Beginning of Period	—			17			2			—			19
Cash and Cash Equivalents, End of Period	$	7		$	—		$	4		$	—		$	11

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Equity, Equity Activity (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Changes in carrying amount of Equity
Balance at December 31, 2014				$ 1,890
Distributions	[1]			(241)
Net earnings		$ 77	$ 33	223	$ 106
Contributions	[2]			21
Other				3
Balance at September 30, 2015		1,967		1,967
Common
Changes in carrying amount of Equity
Balance at December 31, 2014				1,474
Distributions	[1]			(173)
Net earnings				153
Contributions	[2]			14
Other				3
Balance at September 30, 2015		1,887		1,887
General Partner
Changes in carrying amount of Equity
Balance at December 31, 2014				(19)
Distributions	[1]			(48)
Net earnings				51
Contributions	[2]			7
Other				0
Balance at September 30, 2015		(4)		(4)
Noncontrolling Interest
Changes in carrying amount of Equity
Balance at December 31, 2014				435
Distributions	[1]			(20)
Net earnings				19
Contributions	[2]			0
Other				0
Balance at September 30, 2015		$ 84		84
QEP Midstream Partners, LP
Changes in carrying amount of Equity
Equity offering, net of issuance costs	[3]			0
QEP Midstream Partners, LP | Common
Changes in carrying amount of Equity
Equity offering, net of issuance costs	[3]			350
QEP Midstream Partners, LP | General Partner
Changes in carrying amount of Equity
Equity offering, net of issuance costs	[3]			0
QEP Midstream Partners, LP | Noncontrolling Interest
Changes in carrying amount of Equity
Equity offering, net of issuance costs	[3]			(350)
2014 ATM Program
Changes in carrying amount of Equity
Equity offering, net of issuance costs				71
2014 ATM Program | Common
Changes in carrying amount of Equity
Equity offering, net of issuance costs				66
2014 ATM Program | General Partner
Changes in carrying amount of Equity
Equity offering, net of issuance costs				5
2014 ATM Program | Noncontrolling Interest
Changes in carrying amount of Equity
Equity offering, net of issuance costs				$ 0

[1] Represents cash distributions declared and paid during the nine months ended September 30, 2015 relating to the fourth quarter of 2014 through the second quarter of 2015.

[2] Includes Tesoro and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

[3] On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

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Debt, Revolving Credit Facility(Details) - Revolving credit facility $ in Millions	9 Months Ended
	Sep. 30, 2015 USD ($)
Revolving Credit Facility
Total loan availability	$ 900
Maximum loan availability	1,500
Borrowings under Revolving Credit Facility	280
Unused loan availability	$ 620
Unused loan availability, percentage	69.00%
Weighted average interest rate	2.69%
Revolver maturity date	Dec. 02, 2019
Collateral	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 Services L.L.C., and secured by substantially all of our assets.

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Condensed Consolidating Financial Information Statement of Operations (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
Affiliate	[1]	$ 152	$ 130	$ 454	$ 358
Third-party		130	20	366	52
Total Revenues		282	150	820	410
Costs and Expenses
Operating and maintenance expenses		108	72	307	187
Imbalance settlement gains and reimbursements		(10)	(17)	(29)	(32)
General and administrative expenses		28	16	81	39
Depreciation and amortization expenses		44	18	132	51
Loss on asset disposals and impairments		0	0	0	(4)
Total Costs and Expenses		170	89	491	241
OPERATING INCOME (Loss)		112	61	329	169
Interest and financing costs, net		(37)	(28)	(112)	(63)
Equity in earnings of unconsolidated affiliates		2	0	6	0
Equity in earnings of subsidiaries		0		0
Net Earnings		77	33	223	106
Net earnings attributable to noncontrolling interest		(3)	0	(19)	0
Net Earnings Attributable to Partners		74	$ 33	204	$ 110
Parent
Revenues
Affiliate		0		0
Third-party		0		0
Total Revenues		0		0
Costs and Expenses
Operating and maintenance expenses		0		0
Imbalance settlement gains and reimbursements		0		0
General and administrative expenses		9		21
Depreciation and amortization expenses		0		0
Loss on asset disposals and impairments				0
Total Costs and Expenses		9		21
OPERATING INCOME (Loss)		(9)		(21)
Interest and financing costs, net		0		0
Equity in earnings of unconsolidated affiliates		0		0
Equity in earnings of subsidiaries		83		225
Net Earnings		74		204
Net earnings attributable to noncontrolling interest		0		0
Net Earnings Attributable to Partners		74		204
Guarantor Subsidiaries
Revenues
Affiliate		153		454
Third-party		129		365
Total Revenues		282		819
Costs and Expenses
Operating and maintenance expenses		115		326
Imbalance settlement gains and reimbursements		(10)		(29)
General and administrative expenses		19		60
Depreciation and amortization expenses		36		107
Loss on asset disposals and impairments				5
Total Costs and Expenses		160		469
OPERATING INCOME (Loss)		122		350
Interest and financing costs, net		(34)		(103)
Equity in earnings of unconsolidated affiliates		2		7
Equity in earnings of subsidiaries		4		11
Net Earnings		94		265
Net earnings attributable to noncontrolling interest		(2)		(16)
Net Earnings Attributable to Partners		92		249
Non-Guarantors
Revenues
Affiliate		7		20
Third-party		1		4
Total Revenues		8		24
Costs and Expenses
Operating and maintenance expenses		0		1
Imbalance settlement gains and reimbursements		0		0
General and administrative expenses		0		0
Depreciation and amortization expenses		3		9
Loss on asset disposals and impairments				0
Total Costs and Expenses		3		10
OPERATING INCOME (Loss)		5		14
Interest and financing costs, net		0		0
Equity in earnings of unconsolidated affiliates		0		0
Equity in earnings of subsidiaries		0		0
Net Earnings		5		14
Net earnings attributable to noncontrolling interest		(1)		(3)
Net Earnings Attributable to Partners		4		11
Consolidating Adjustments
Revenues
Affiliate		(8)		(20)
Third-party		0		(3)
Total Revenues		(8)		(23)
Costs and Expenses
Operating and maintenance expenses		(7)		(20)
Imbalance settlement gains and reimbursements		0		0
General and administrative expenses		0		0
Depreciation and amortization expenses		5		16
Loss on asset disposals and impairments				(5)
Total Costs and Expenses		(2)		(9)
OPERATING INCOME (Loss)		(6)		(14)
Interest and financing costs, net		(3)		(9)
Equity in earnings of unconsolidated affiliates		0		(1)
Equity in earnings of subsidiaries		(87)		(236)
Net Earnings		(96)		(260)
Net earnings attributable to noncontrolling interest		0		0
Net Earnings Attributable to Partners		$ (96)		$ (260)

[1] Tesoro accounted for 54% and 55% of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

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Net Earnings Per Unit (Notes)

9 Months Ended

Sep. 30, 2015

Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax [Abstract]

Net Earnings Per Unit

NET EARNINGS PER UNIT

We use the two-class method when calculating the net earnings per unit applicable to limited partners, because we have more than one participating security. At September 30, 2015, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the limited and general partners in accordance with our partnership agreement. We base our calculation of net earnings per unit on the weighted average number of common and subordinated limited partner units outstanding during the period.

Diluted net earnings per unit include the effects of potentially dilutive units on our common units, which consist of unvested service and performance phantom units. Basic and diluted net earnings per unit applicable to subordinated limited partners were 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.

The calculation of net earnings per unit is as follows (in millions, except per unit amounts):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Net earnings	$	77		$	33		$	223		$	106
Net earnings attributable to noncontrolling interest	(3		)	—			(19		)	—
Special allocations of net earnings (“Special Allocations”) (a)	—			7			—			7
Net earnings, excluding noncontrolling interest (b)	74			40			204			113
General partner’s distributions	(1		)	(1		)	(4		)	(3		)
General partner’s IDRs (c)	(19		)	(13		)	(47		)	(26		)
Limited partners’ distributions on common units	(66		)	(52		)	(186		)	(104		)
Limited partners’ distributions on subordinated units (d)	—			—			—			(14		)
Distributions greater than earnings	$	(12	)	$	(26	)	$	(33	)	$	(34	)
General partner’s earnings:
Distributions	$	1		$	1		$	4		$	3
General partner’s IDRs (c)	19			13			47			26
Allocation of distributions greater than earnings (b)	—			—			—			(4		)
Total general partner’s earnings	$	20		$	14		$	51		$	25
Limited partners’ earnings on common units:
Distributions	$	66		$	52		$	186		$	104
Special Allocations	—			(7		)	—			(7		)
Allocation of distributions greater than earnings	(12		)	(26		)	(33		)	(26		)
Total limited partners’ earnings on common units	$	54		$	19		$	153		$	71
Limited partners’ earnings on subordinated units (d):
Distributions	$	—		$	—		$	—		$	14
Allocation of distributions greater than earnings	—			—			—			(4		)
Total limited partners’ earnings on subordinated units	$	—		$	—		$	—		$	10
Weighted average limited partner units outstanding
Common units - basic	86.6			55.9			82.5			47.4
Common unit equivalents	0.1			0.1			0.1			0.1
Common units - diluted	86.7			56.0			82.6			47.5
Subordinated units - basic and diluted (d)	—			—			—			7.5
Net earnings per limited partner unit:
Common - basic	$	0.62		$	0.33		$	1.85		$	1.50
Common - diluted	$	0.62		$	0.33		$	1.85		$	1.50
Subordinated - basic and diluted	$	—		$	—		$	—		$	1.28

_______________

(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 TLLP common unitholders for the premium paid in connection with the redemption of senior notes during the three and nine months ended September 30, 2014.

(b) In April 2015, the FASB issued ASU 2015-06 concerning historical earnings per unit for master limited partnership drop down transactions. We have revised the historical allocation of general partner earnings to include the Predecessor losses TLLP incurred of $4 million during the nine months ended September 30, 2014. There were no earnings or losses for the three months ended September 30, 2014. See Note 1 for additional information on the new guidance.

(c) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $2.5 millionand $7.5 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP in connection with the Rockies Natural Gas Business Acquisition. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2014, for further discussion related to IDRs.

(d) On May 16, 2014, the 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 earnings were allocated to the subordinated units through May 15, 2014.

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Equity, Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Millions			3 Months Ended				9 Months Ended
		Oct. 22, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2015
Distribution Made to Member or Limited Partner
Quarterly Distribution Per Unit				$ 0.7225	$ 0.6950	$ 0.6675
Total Cash Distribution including general partner IDRs				$ 81.0	$ 70.0	$ 70.0
Date of Distribution				Aug. 14, 2015	May 15, 2015	Feb. 13, 2015
Unitholders Record Date				Aug. 03, 2015	May 04, 2015	Feb. 02, 2015
Subsequent Event
Distribution Made to Member or Limited Partner
Quarterly Distribution Per Unit	[1]	$ 0.7500
Total Cash Distribution including general partner IDRs	[1]	$ 86.0
Date of Distribution	[1]	Nov. 13, 2015
Unitholders Record Date	[1]	Nov. 02, 2015
Declaration date		Oct. 22, 2015
Rockies Natural Gas Business Acquisition
Distribution Made to Member or Limited Partner
General partner distribution amount forfeited			$ 2.5				$ 7.5
Annually | Rockies Natural Gas Business Acquisition
Distribution Made to Member or Limited Partner
General partner distribution amount forfeited							$ 10.0

[1] This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

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Acquisitions Rockies Natural Gas Business Acquisition Narrative (Details) $ in Millions			3 Months Ended		9 Months Ended
	Jul. 22, 2015	Dec. 02, 2014 USD ($)	Sep. 30, 2015 USD ($) facility	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) facility	Sep. 30, 2014 USD ($)	Dec. 31, 2014 USD ($)	[1]
Acquisition
General partner's ownership interest					2.00%
Effective date of Merger Completion	Jul. 22, 2015
Goodwill			$ 157		$ 157		$ 164
Weighted average useful life					35 years
Gross carrying value of intangible assets			976		$ 976
Accumulated amortization			24		24
Amortization expense			7		21
Rockies Natural Gas Business Acquisition
Acquisition
Effective date of acquisition		Dec. 02, 2014
Purchase price		$ 2,500
Purchase price adjustment					6
Goodwill			$ 148		$ 148
Pro forma revenues				$ 241		$ 690
Pro forma net income				$ 25		$ 81
QEP Midstream Partners, LP
Acquisition
Ownership interest		56.00%
General partner's ownership interest		2.00%
QEP Midstream Partners GP, LLC
Acquisition
Ownership interest		100.00%
Processing | Gas Processing Complexes
Acquisition
Number of assets (assets) | facility			4		4
Processing | Rockies Natural Gas Business Acquisition
Acquisition
Goodwill			$ 135		$ 135
Gathering | Rockies Natural Gas Business Acquisition
Acquisition
Goodwill			$ 13		$ 13
Green River Processing, LLC | Gas Processing Complexes
Acquisition
Number of assets (assets) | facility			2		2
Green River Processing, LLC | Fractionation Facility
Acquisition
Number of assets (assets) | facility			1		1

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Organization and Basis of Presentation New Accounting Standards (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
New Accounting Pronouncements or Change in Accounting Principle
Percent of trade receivables outstanding	1.00%
New Accounting Pronouncement, Early Adoption, Effect
New Accounting Pronouncements or Change in Accounting Principle
Unamortized debt issuance cost	$ 43	$ 49

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Segment Disclosures, Narrative Information (Details)	9 Months Ended
	Sep. 30, 2015 mi terminals segments facility
Segment Reporting Information
Number of operating segments (segments) | segments	3
Segment reporting, foreign operations	We do not have any foreign operations.
Crude oil and natural gas gathering systems
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
Regulated Common Carrier Refined Products Pipeline
Segment Reporting Information
Number of assets (assets)	1
Crude oil and refined products terminals and storage facilities
Segment Reporting Information
Number of assets (assets) | terminals	24
Marine terminals
Segment Reporting Information
Number of assets (assets) | terminals	4
Rail car unloading facility
Segment Reporting Information
Number of assets (assets)	1
Petroleum coke handling and storage facility
Segment Reporting Information
Number of assets (assets)	1
Pipelines which transport products and crude oil
Segment Reporting Information
Number of miles (miles) | mi	130
Processing | Gas Processing Complexes
Segment Reporting Information
Number of assets (assets)	4
Green River Processing, LLC | Gas Processing Complexes
Segment Reporting Information
Number of assets (assets)	2
Green River Processing, LLC | Fractionation Facility
Segment Reporting Information
Number of assets (assets)	1

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Acquisitions Rockies Natural Gas Business Acquisition Preliminary Acquisition Date Purchase Price Allocation (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014	[1]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Goodwill	$ 157	$ 164
Investment in unconsolidated affiliates	56	$ 57
Rockies Natural Gas Business Acquisition
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract]
Cash	32
Receivables	120
Prepayments and other	8
Property, plant and equipment	1,735
Intangibles	976
Goodwill	148
Investment in unconsolidated affiliates	57
Other noncurrent assets	23
Accounts payable	(67)
Other current liabilities	(51)
Other noncurrent liabilities	(33)
Noncontrolling interest	(432)
Total purchase price	$ 2,516

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Acquisitions 2014 Acquisition (Details) - West Coast Logistics Assets Acquisition	Sep. 30, 2014	Jul. 01, 2014
Phase One
Acquisition
Effective date of acquisition		Jul. 01, 2014
Phase Two
Acquisition
Effective date of acquisition	Sep. 30, 2014

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Related-Party Transactions (Notes)

9 Months Ended

Sep. 30, 2015

Related Party Transactions [Abstract]

Related-Party Transactions

RELATED-PARTY TRANSACTIONS

Affiliate Agreements

The Partnership has various long-term, fee-based commercial agreements with Tesoro, under which we provide pipeline transportation, trucking, terminal distribution, storage and petroleum-coke handling services to Tesoro, and Tesoro commits to provide us with minimum monthly throughput volumes of crude oil and refined products.

We entered into the Third Amended and Restated Omnibus Agreement (the “Amended Omnibus Agreement”) and the Secondment and Logistics Services Agreement in connection with the West Coast Logistics Assets Acquisition. We also entered into the First Amended and Restated Omnibus Agreement of QEPM (the “QEPM Omnibus Agreement”) and the Keep-Whole Commodity Fee Agreement in connection with the Rockies Natural Gas Business Acquisition. See Notes 3 and 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of these agreements. On August 3, 2015, subsequent to the Merger, TLLP and QEPM terminated the QEPM Omnibus Agreement.

On February 20, 2015, we entered into an amendment to the Amended Omnibus Agreement. The amendment, effective December 31, 2014, clarifies certain provisions regarding the responsibilities for costs incurred by TLLP in connection with hydro-testing conducted on our gathering and transportation system located in the Bakken Region. As a result of the termination of the QEPM Omnibus Agreement discussed above, we further amended the Amended Omnibus Agreement to increase the annual administrative fee payable by the Partnership to Tesoro by $3.6 million. This increase, effective July 1, 2015, accounts for the additional fixed costs and expenses related to the administration of the assets of QEPM and its subsidiaries that were previously payable under the QEPM Omnibus Agreement.

Summary of Affiliate Transactions

A summary of revenue and expense transactions with Tesoro, including expenses directly charged and allocated to our Predecessors, are as follows (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Revenues (a)	$	152	$	130	$	454	$	358
Operating and maintenance expenses	28		18		77		56
Imbalance settlement gains and reimbursements from    Tesoro (b)	12		17		31		32
General and administrative expenses	16		11		51		28

_______________

(a) Tesoro accounted for 54% and 55%of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

(b) Includes imbalance settlement gains of$2 million and $9 million for the three months ended September 30, 2015 and 2014, respectively, and $6 million and $14 millionfor the nine months ended September 30, 2015 and 2014, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $10 million and $8 million for the three months ended September 30, 2015 and 2014, respectively, and $25 million and $18 million for the nine months ended September 30, 2015 and 2014, respectively.

Predecessor Transactions. Related-party transactions of our Predecessor were settled through equity. The balance in receivables and accounts payable from affiliated companies represents the amount owed from or to Tesoro related to certain affiliate transactions. Our Predecessor did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment, with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

Distributions. In accordance with our partnership agreement, the unitholders of our common and general partner interests are entitled to receive quarterly distributions of available cash. In connection with the Rockies Natural Gas Business Acquisition, our general partner has waived its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). For the three and nine months ended September 30, 2015, our general partner waived $2.5 million and $7.5 million, respectively, of general partner distributions with respect to IDRs. During the nine months ended September 30, 2015, we paid quarterly cash distributions of $106 million to Tesoro and TLGP, including IDRs. On October 22, 2015, we declared a quarterly cash distribution of $0.7500 per unit, which will be paid on November 13, 2015. The distribution will include payments of $41 million to Tesoro and TLGP, including IDRs.

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Related-Party Transactions Related-Party Transactions, Summary of Transactions Narrative (Details) - USD ($) $ / shares in Units, $ in Millions						3 Months Ended					9 Months Ended
		Oct. 22, 2015	Aug. 03, 2015	Jul. 01, 2015	Feb. 20, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Related Party Transactions
Concentration risk, percentage						54.00%				86.00%	55.00%	87.00%
Imbalance settlement gains						$ 2.0				$ 9.0	$ 6.0	$ 14.0
Reimbursements from Tesoro						10.0				$ 8.0	25.0	18.0
Cash distributions paid to Tesoro and TLGP											173.0	$ 97.0
Cash distributions per unit (dollars per unit)							$ 0.7225	$ 0.6950	$ 0.6675
Distribution date							Aug. 14, 2015	May 15, 2015	Feb. 13, 2015
Further Amended Omnibus Agreement
Related Party Transactions
Agreement Date				Jul. 01, 2015
Related Party Transaction increase In general and administrative fee payable to Related Party				$ 3.6
Related party transactions with Tesoro and subsidiaries
Related Party Transactions
Cash distributions paid to Tesoro and TLGP											106.0
QEP Midstream Partners, LP | Amended Omnibus Agreement
Related Party Transactions
Agreement Date			Aug. 03, 2015
TLLP | Amended Omnibus Agreement
Related Party Transactions
Agreement Date					Feb. 20, 2015
Rockies Natural Gas Business Acquisition
Related Party Transactions
General partner distribution amount forfeited						$ 2.5					7.5
Rockies Natural Gas Business Acquisition | Annually
Related Party Transactions
General partner distribution amount forfeited											$ 10.0
Subsequent Event
Related Party Transactions
Declaration date		Oct. 22, 2015
Cash distributions per unit (dollars per unit)	[1]	$ 0.7500
Distribution date	[1]	Nov. 13, 2015
Distribution declared (including IDRs)		$ 41.0

[1] This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

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Equity Equity, ATM Program (Details) - USD ($) $ in Millions					3 Months Ended	9 Months Ended
	Aug. 21, 2015	Aug. 06, 2015	Jul. 22, 2015	Jun. 25, 2014	Sep. 30, 2015	Sep. 30, 2015
Issuance of units			7,100,000
2014 ATM Program
Supplemental prospectus, filing date				Jun. 25, 2014
Common Units Aggregate Value				$ 200
Issuance of units					0	819,513
Equity offering, net of issuance costs						$ 45
2015 ATM Program
Supplemental prospectus, filing date	Aug. 21, 2015
Registration Filing Date		Aug. 06, 2015
Common Units Aggregate Value	$ 750
Issuance of units					537,014	537,014
Equity offering, net of issuance costs					$ 26	$ 26

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Condensed Statements of Combined Consolidated Operations (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
Affiliate	[1]	$ 152	$ 130	$ 454	$ 358
Third-party		130	20	366	52
Total Revenues		282	150	820	410
Costs and Expenses
Operating and maintenance expenses		108	72	307	187
Imbalance settlement gains and reimbursements		(10)	(17)	(29)	(32)
General and administrative expenses		28	16	81	39
Depreciation and amortization expenses		44	18	132	51
Net gain on asset disposals and impairments		0	0	0	(4)
Total Costs and Expenses		170	89	491	241
OPERATING INCOME (Loss)		112	61	329	169
Interest and financing costs, net		(37)	(28)	(112)	(63)
Equity in earnings of unconsolidated affiliates		2	0	6	0
Net Earnings		77	33	223	106
Loss attributable to Predecessors		0	0	0	4
Net earnings attributable to noncontrolling interest		(3)	0	(19)	0
Net Earnings Attributable to Partners		74	33	204	110
General partner's interest in net earnings, including incentive distribution rights		(20)	(14)	(51)	(29)
Limited Partners’ Interest in Net Earnings		$ 54	$ 19	$ 153	$ 81
Net Earnings per Limited Partner Unit
Common - basic		$ 0.62	$ 0.33	$ 1.85	$ 1.50
Common - diluted		0.62	0.33	1.85	1.50
Subordinated - basic and diluted		$ 0.00	$ 0.00	$ 0.00	$ 1.28
Weighted average limited partner units outstanding:
Common units - basic		86.6	55.9	82.5	47.4
Common units - diluted		86.7	56.0	82.6	47.5
Subordinated units - basic and diluted	[2]	0.0	0.0	0.0	7.5
Cash distributions paid per unit		$ 0.7225	$ 0.6150	$ 2.0850	$ 1.7700

[1] Tesoro accounted for 54% and 55% of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

[2] On May 16, 2014, the 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 earnings were allocated to the subordinated units through May 15, 2014.

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Segment Disclosures, Results (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
Affiliate	[1]	$ 152	$ 130	$ 454	$ 358
Third-party		130	20	366	52
Total Revenues		282	150	820	410
OPERATING INCOME
Segment Operating Income		128	67	372	183
Unallocated general and administrative expenses		(16)	(6)	(43)	(14)
Interest and financing costs, net		(37)	(28)	(112)	(63)
Equity in earnings of unconsolidated affiliates		2	0	6	0
Net Earnings		77	33	223	106
Segment Reporting Information, Additional Information
Capital Expenditures		92	63	235	137
Gathering
Revenues
Affiliate		18	27	71	75
Third-party		69	5	182	9
Total Revenues		87	32	253	84
OPERATING INCOME
Segment Operating Income		42	15	121	38
Segment Reporting Information, Additional Information
Capital Expenditures		72	40	177	92
Processing
Revenues
Affiliate		26	0	71	0
Third-party		45	0	134	0
Total Revenues		71	0	205	0
OPERATING INCOME
Segment Operating Income		29	0	77	0
Segment Reporting Information, Additional Information
Capital Expenditures		5	0	10	0
Terminalling and Transportation
Revenues
Affiliate		108	103	312	283
Third-party		16	15	50	43
Total Revenues		124	118	362	326
OPERATING INCOME
Segment Operating Income		57	52	174	145
Segment Reporting Information, Additional Information
Capital Expenditures		$ 15	$ 23	$ 48	$ 45

[1] Tesoro accounted for 54% and 55% of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

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Organization and Basis of Presentation (Notes)

9 Months Ended

Sep. 30, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation

ORGANIZATION AND BASIS OF PRESENTATION

Organization

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, 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. 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.

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. TLLP entered into an Agreement and Plan of Merger on April 6, 2015, with TLGP, QEPFS, TLLP Merger Sub LLC (“Merger Sub”), QEP Midstream Partners, LP (“QEPM”), and QEP Midstream Partners GP, LLC (“QEPM GP”). In July 2015, TLLP and QEPM completed the transaction, in which the Merger Sub merged with and into QEPM, with QEPM surviving the merger as a wholly-owned subsidiary of TLLP (the “Merger”). QEPM GP remained the general partner of QEPM following the Merger, and all outstanding common units representing limited partnership interests in QEPM other than QEPM Common Units held by QEPFS (the “QEPM Common Units”) were converted into 0.3088 common units representing limited partnership interests in TLLP (the “TLLP Common Units”). The Merger was completed on July 22, 2015 and TLLP issued approximately 7.1 million TLLP Common Units to QEPM unitholders. No fractional TLLP Common Units were issued in the Merger, and holders of QEPM Common Units other than QEPFS received cash in lieu of fractional TLLP Common Units.

Principles of Combination and Consolidation and Basis of Presentation

In 2014, we entered into transactions with Tesoro and TLGP, pursuant to which TLLP acquired from Tesoro 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 (collectively referred to as the “West Coast Logistics Assets Acquisition”). The West Coast Logistics Assets Acquisition was a transfer between entities under common control. As an entity under common control with Tesoro, we recorded the assets that we acquired 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 condensed combined consolidated financial statements and related notes of TLLP have been retrospectively adjusted to include the historical results of the assets acquired in the West Coast Logistics Assets Acquisition for all periods presented. We refer to the historical results of the West Coast Logistics Assets prior to their respective acquisition dates as our “Predecessor.”

The accompanying condensed combined consolidated financial statements and related notes present the results of operations and cash flows of our Predecessor at historical cost. The financial statements of our Predecessor 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 Predecessor had been operated as an unaffiliated entity. Our Predecessor did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment, with the exception of regulatory tariffs charged to Tesoro on the refined products pipeline included in the West Coast Logistics Assets Acquisition.

The interim condensed combined consolidated financial statements and notes thereto have been prepared by management without audit according to the rules and regulations of the Securities and Exchange Commission (“SEC”) and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of results for the periods presented. Such adjustments are of a normal recurring nature, unless otherwise disclosed.

Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) have been condensed or omitted pursuant to the SEC’s rules and regulations. However, management believes that the disclosures presented herein are adequate to present the information fairly. The accompanying interim condensed combined consolidated financial statements and notes should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2014.

We prepare our condensed combined consolidated financial statements in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the amounts of assets and liabilities and revenues and expenses reported as of and during the periods presented. 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. The results of operations of the Partnership, or our Predecessor, for any interim period are not necessarily indicative of results for the full year.

We believe the carrying value of our cash and cash equivalents, receivables, accounts payable and certain accrued liabilities approximates fair value. Our fair value assessment incorporates a variety of considerations, including:

• the short term duration of the instruments (approximately 1% of our trade payables and 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 trade receivables excludes amounts that are greater than 90 days related to legal disputes, primarily XTO Energy Inc.’s (“XTO”) legal dispute with QEPFS. See further discussion regarding the XTO litigation in Note 7.

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 borrowings under our amended revolving credit facility (the “Revolving Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were both approximately $2.6 billion as of September 30, 2015 and December 31, 2014. These carrying and fair values of our debt do not include any unamortized issuance costs associated with our total debt.

New Accounting Standards and Disclosures

Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”), which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017 given the FASB’s recent deferral of ASU 2014-09’s effective date. Entities may choose to early adopt ASU 2014-09 as of the original effective date. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the standard to determine the method of adoption and the impact of ASU 2014-09 on our financial statements and related disclosures.

Pushdown Accounting. In November 2014, the SEC released a Staff Accounting Bulletin 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 fair value of 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. We plan to apply pushdown accounting to applicable entities acquired as part of the Rockies Natural Gas Business Acquisition upon finalization of the purchase price allocation.

Consolidation.  In February 2015, the FASB issued ASU 2015-02, “Amendments to the Consolidation Analysis” (“ASU 2015-02”). This standard modifies existing consolidation guidance for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. ASU 2015-02 is effective for interim and annual periods beginning after December 15, 2015, and requires either a retrospective or a modified retrospective approach to adoption. Early adoption is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements, as well as the available transition methods.

Treatment of Predecessor in EPU calculation. In April 2015, the FASB issued ASU 2015-06 (“ASU 2015-06”), which requires a master limited partnership to allocate earnings or losses of transferred net assets for periods prior to asset purchases from an entity under common control entirely to the general partner when calculating earnings per unit (“EPU”). ASU 2015-06 is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. We elected to adopt this guidance beginning in the first quarter of 2015. Adoption of ASU 2015-06 did not impact the disclosed amounts of earnings per unit attributable to limited partners; however, the allocation of earnings presented in our EPU disclosure for the three and nine months ended September 30, 2014 has been modified to conform to the requirements of the final standard. There were no asset purchases from Tesoro during the three and nine months ended September 30, 2015.

Debt Issuance Costs. In April 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest” (“ASU 2015-03”), which will simplify the presentation of debt issuance costs. Under ASU 2015-03, debt issuance costs related to a recognized debt liability will be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability. As a result, our balance sheet will reflect a reclassification of unamortized debt issuance costs from other noncurrent assets to debt. ASU 2015-03 is effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. We adopted this standard in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. The adoption of this standard resulted in the reclassification of $49 million from other noncurrent assets to debt on the balance sheet at December 31, 2014. Unamortized debt issuance costs of $43 million are recorded as a reduction to debt on the balance sheet at September 30, 2015.

Business Combinations. In September 2015, the FASB issued ASU 2015-16, “Simplifying the Accounting for Measurement-Period Adjustments” (“ASU 2015-16”). The standard requires an acquirer to recognize the cumulative impact of adjustments to provisional purchase price amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The standard also requires an entity to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. ASU 2015-16 is effective for interim and annual periods beginning after beginning after December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. Early application is permitted for financial statements that have not been issued.

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Property, Plant and Equipment (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Property, Plant and Equipment
Gross Property, Plant and Equipment	$ 3,789	$ 3,551
Accumulated depreciation	(357)	(245)
Net Property, Plant and Equipment	3,432	3,306	[1]
Gathering
Property, Plant and Equipment
Gross Property, Plant and Equipment	1,695	1,507
Processing
Property, Plant and Equipment
Gross Property, Plant and Equipment	546	539
Terminalling and Transportation
Property, Plant and Equipment
Gross Property, Plant and Equipment	1,525	1,478
Other
Property, Plant and Equipment
Gross Property, Plant and Equipment	$ 23	$ 27

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Debt (Tables)

9 Months Ended

Sep. 30, 2015

Long-term Debt, Unclassified [Abstract]

Schedule of debt

Our debt balance at September 30, 2015 and December 31, 2014 was as follows (in millions):

	September 30, 2015			December 31, 2014
Total debt	$	2,608		$	2,588
Unamortized issuance costs (a) (b)	(39		)	(44		)
Current maturities	—			—
Debt, net of current maturities and unamortized issuance costs	$	2,569		$	2,544

_________

(a) Includes unamortized premium associated with our 5.875% Senior Notes due 2020 of $4 million and $5 million as of September 30, 2015 and December 31, 2014, respectively.

(b) We adopted ASU 2015-03 in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. See Note 1 for further discussion.

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Debt, Total (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2015	Dec. 31, 2014
Debt Instrument
Total Debt		$ 2,608	$ 2,588
Unamortized issuance costs	[1],[2]	(39)	(44)
Current maturities		0	0
Debt, net of current maturities and unamortized issuance costs		$ 2,569	2,544	[3]
5.875% Senior Notes due 2020
Debt Instrument
Debt instrument, interest rate		5.875%
Debt instrument, maturity date		Oct. 01, 2020
Debt Instrument, unamortized premium		$ 4	$ 5

[1] Includes unamortized premium associated with our 5.875% Senior Notes due 2020 of $4 million and $5 million as of September 30, 2015 and December 31, 2014, respectively.

[2] We adopted ASU 2015-03 in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. See Note 1 for further discussion.

[3] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Segment Disclosures (Tables)

9 Months Ended

Sep. 30, 2015

Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]

Schedule of segment reporting information, by segment

Segment information related to continuing operations is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Revenues
Gathering:
Affiliate	$	18		$	27		$	71		$	75
Third-party	69			5			182			9
Total Gathering	87			32			253			84
Processing
Affiliate	26			—			71			—
Third-party	45			—			134			—
Total Processing	71			—			205			—
Terminalling and Transportation:
Affiliate	108			103			312			283
Third-party	16			15			50			43
Total Terminalling and Transportation	124			118			362			326
Total Segment Revenues	$	282		$	150		$	820		$	410
Segment Operating Income
Gathering	$	42		$	15		$	121		$	38
Processing	29			—			77			—
Terminalling and Transportation	57			52			174			145
Total Segment Operating Income	128			67			372			183
Unallocated general and administrative expenses	(16		)	(6		)	(43		)	(14		)
Interest and financing costs, net	(37		)	(28		)	(112		)	(63		)
Equity in earnings of unconsolidated affiliates	2			—			6			—
Net Earnings	$	77		$	33		$	223		$	106
Capital Expenditures
Gathering	$	72		$	40		$	177		$	92
Processing	5			—			10			—
Terminalling and Transportation	15			23			48			45
Total Capital Expenditures	$	92		$	63		$	235		$	137

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Acquisitions (Notes)

9 Months Ended

Sep. 30, 2015

Business Combinations [Abstract]

Acquisitions

ACQUISITIONS

Rockies Natural Gas Business Acquisition

On December 2, 2014, the Partnership closed the acquisition with QEP Resources, Inc. (“QEP Resources”), in which we agreed to purchase all of the limited liability company interests of QEPFS for approximately $2.5 billion in cash. 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 Williston Basin located in North Dakota (the “Bakken Region”). At the acquisition date, QEPFS held an approximate 56% limited partner interest in QEPM and 100% of the limited liability company interests of QEPM GP, which itself held a 2% general partner interest and all of the incentive distribution rights (“IDRs”) in QEPM. Pursuant to the Merger effected on July 22, 2015, we acquired all remaining limited partner interest in QEPM through the issuance of TLLP common units. There was no impact to the purchase price allocation as a result of the Merger. Refer to Note 1 for further information.

The acquired assets include natural gas and crude oil gathering and transmission pipelines within the Rockies and Bakken Regions, 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.

Finalization of the purchase price allocation is pending and adjustments can be made through the end of our measurement period, which is not to exceed one year from the acquisition date. During the nine months ended September 30, 2015, the original purchase price was increased by $6 million for the settlement of acquisition date net working capital with QEP Resources. We recorded $148 million of goodwill in connection with the Rockies Natural Gas Business Acquisition, of which $13 million was included in our Gathering segment, and $135 million was included in our Processing segment. Acquired intangibles other than goodwill 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. 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 expenses on our condensed statement of combined consolidated operations. The gross carrying value of our finite life intangibles was $976 million and the accumulated amortization was $24 million as of September 30, 2015. During the three and nine months ended September 30, 2015, we incurred $7 million and $21 million, respectively, of amortization expense related to these intangibles.

The table below reflects the preliminary acquisition date purchase price allocation as of September 30, 2015 (in millions):

Cash	$	32
Receivables	120
Prepayments and other	8
Property, plant and equipment	1,735
Intangibles	976
Goodwill	148
Investment in unconsolidated affiliates	57
Other noncurrent assets	23
Accounts payable	(67		)
Other current liabilities	(51		)
Other noncurrent liabilities	(33		)
Noncontrolling interest	(432		)
Total purchase price	$	2,516

If the Rockies Natural Gas Business Acquisition had occurred on January 1, 2014, our pro forma revenues would have been $241 million and $690 million for the three and nine months ended September 30, 2014, respectively. Our pro forma net earnings would have been $25 million and $81 million for the three and nine months ended September 30, 2014, respectively.

West Coast Logistics Assets Acquisition

On July 1, 2014, we acquired the first portion of the West Coast Logistics Assets and we acquired the second portion of the assets on September 30, 2014, upon receiving the required regulatory approval. The operations of the West Coast Logistics Assets are included in our Terminalling and Transportation segment. These transactions were transfers between entities under common control. See our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the West Coast Logistics Assets Acquisition and the commercial agreements executed in connection with this acquisition.

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Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
CURRENT ASSETS
Cash and cash equivalents	$ 11	$ 19	[1]
Receivables, net
Trade	132	122	[1]
Affiliate	80	69	[1]
Other	0	18	[1]
Prepayments and other	8	7	[1]
Total Current Assets	231	235	[1]
Net Property, Plant and Equipment	3,432	3,306	[1]
Acquired intangibles, net	952	973	[1]
Goodwill	157	164	[1]
Investment in Unconsolidated Affiliates	56	57	[1]
Other Noncurrent Assets	23	30	[1]
Total Assets	4,851	4,765	[1]
Accounts payable
Trade	85	126	[1]
Affiliate	52	53	[1]
Accrued interest and financing costs	65	28	[1]
Other current liabilities	64	79	[1]
Total Current Liabilities	266	286	[1]
Other Noncurrent Liabilities	49	45	[1]
Debt, Net of Unamortized Issuance Costs	$ 2,569	$ 2,544	[1]
Commitments and Contingencies (Note 7)
EQUITY
Common unitholders; 88,633,988 units issued and outstanding (80,125,930 in 2014)	$ 1,887	$ 1,474
General partner; 1,631,448 units issued and outstanding (1,631,448 in 2014)	(4)	(19)
Noncontrolling interest	84	435	[1]
Total Equity	1,967	1,890
Total Liabilities and Equity	$ 4,851	$ 4,765	[1]

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Net Earnings Per Unit (Policies)

9 Months Ended

Sep. 30, 2015

Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax [Abstract]

Net Earnings per unit, policy

We use the two-class method when calculating the net earnings per unit applicable to limited partners, because we have more than one participating security. At September 30, 2015, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the limited and general partners in accordance with our partnership agreement. We base our calculation of net earnings per unit on the weighted average number of common and subordinated limited partner units outstanding during the period.

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Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 26, 2015
Entity Registrant Name	TESORO LOGISTICS LP
Entity Central Index Key	0001507615
Document Type	10-Q
Document Period End Date	Sep. 30, 2015
Amendment Flag	false
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Common
Entity Common Stock, Units Outstanding		88,633,988
General Partner
Entity Common Stock, Units Outstanding		1,631,448

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Acquisitions Acquisitions (Tables)

9 Months Ended

Sep. 30, 2015

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The table below reflects the preliminary acquisition date purchase price allocation as of September 30, 2015 (in millions):

Cash	$	32
Receivables	120
Prepayments and other	8
Property, plant and equipment	1,735
Intangibles	976
Goodwill	148
Investment in unconsolidated affiliates	57
Other noncurrent assets	23
Accounts payable	(67		)
Other current liabilities	(51		)
Other noncurrent liabilities	(33		)
Noncontrolling interest	(432		)
Total purchase price	$	2,516

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Condensed Consolidated Balance Sheets (Unaudited), (Parenthetical) - shares	Sep. 30, 2015	Dec. 31, 2014
EQUITY
Common units issued (units)	88,633,988	80,125,930
General partner units issued (units)	1,631,448	1,631,448
Common units outstanding (units)	88,633,988	80,125,930
General partner units outstanding (units)	1,631,448	1,631,448

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Commitments and Contingencies (Notes)

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Tesoro Indemnification

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 TLLP initial public offering (“Initial Offering”) and subsequent acquisitions from Tesoro, excluding certain Los Angeles assets acquired from Tesoro in 2013. Under the Carson Assets Indemnity Agreement (the “Carson Assets Indemnity Agreement”), Tesoro retained responsibility for remediation of known environmental liabilities due to the use or operation of certain Los Angeles assets prior to the acquisition dates, and has indemnified the Partnership for any losses incurred by the Partnership arising out of those remediation obligations. See Note 11 of our Annual Report on Form 10-K for the year ended December 31, 2014, for additional information regarding the terms and conditions of the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

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 accrues 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. We have accrued liabilities for these expenses and believe these accruals are adequate based on current information and projections that can be reasonably estimated. Our environmental liabilities are estimates using internal and third-party assessments and available information to date. It is possible that these estimates will change as more information becomes available. Our accruals for these environmental expenditures totaled $15 million and $32 million at September 30, 2015 and December 31, 2014, respectively.

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 to restore the site for agricultural use. We spent $17 million during the nine months ended September 30, 2015 on remediation related to the Crude Oil Pipeline Release. Our condensed consolidated balance sheet included $8 million and $25 million in accrued environmental liabilities related to the Crude Oil Pipeline Release at September 30, 2015 and December 31, 2014, respectively.This incident was covered by our pollution legal liability insurance policy, subject to a $1 million deductible and a $25 million loss limit. Pursuant to this policy, there were no insurance recovery receivables related to the Crude Oil Pipeline Release at September 30, 2015, and $18 million at December 31, 2014. As of September 30, 2015, the total estimated remediation costs were $42 million, which exceeded our pollution liability legal insurance policy and we are continuously seeking to improve remediation methods and associated costs.

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 Pipe Line Company and Northwest Terminalling Company (collectively, “Chevron”) detected and responded to the release of diesel fuel (the “Diesel Pipeline Release”) that occurred near Willard, Utah on the northwest products system (the “Northwest Products System”). As a result of this release, a Corrective Action Order (the “CAO”) was issued on March 22, 2013 by PHMSA. Chevron retained the financial and operational responsibility to remediate the site of the Diesel Pipeline Release, including the payment of any monetary fines and penalties assessed by any government authority arising from this incident, prior to and subsequent to the date of acquisition until June 19, 2015. 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. On March 6, 2015, PHMSA issued a closure letter indicating that we have complied with all the terms of the CAO and that no further action is required. We have recognized $4 million and $6 million in as environmental remediation liabilities at September 30, 2015 and December 31, 2014, respectively, representing our best estimate of liabilities remaining for all assets acquired from Chevron.

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. TLLP has agreed to indemnify QEP Field Services Company 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, the assets and agreement discussed above were 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 $18 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 Energy Inc. (“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. XTO has also withheld payments for amounts unrelated to the allocation of charges they have challenged. While we cannot currently estimate the final amount or timing of the resolution of this matter, we believe the outcome will not have a material impact on our liquidity, financial position, or results of operations.

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Debt (Notes)

9 Months Ended

Sep. 30, 2015

Long-term Debt, Unclassified [Abstract]

Debt

DEBT

Our debt balance at September 30, 2015 and December 31, 2014 was as follows (in millions):

	September 30, 2015			December 31, 2014
Total debt	$	2,608		$	2,588
Unamortized issuance costs (a) (b)	(39		)	(44		)
Current maturities	—			—
Debt, net of current maturities and unamortized issuance costs	$	2,569		$	2,544

_________

(a) Includes unamortized premium associated with our 5.875% Senior Notes due 2020 of $4 million and $5 million as of September 30, 2015 and December 31, 2014, respectively.

(b) We adopted ASU 2015-03 in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. See Note 1 for further discussion.

Revolving Credit Facility

As of September 30, 2015, our Revolving Credit Facility provided for total loan availability of $900 million. 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. Borrowings are available under the Revolving Credit Facility up to the total loan availability of the 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 Services L.L.C., and secured by substantially all of our assets. We had $280 millionof borrowings outstanding under the Revolving Credit Facility, resulting in a total unused loan availability of $620 million or 69% of the borrowing capacity as of September 30, 2015. The weighted average interest rate for borrowings under our Revolving Credit Facility was 2.69% at September 30, 2015. The Revolving Credit Facility is scheduled to mature on December 2, 2019.

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Equity (Tables)

9 Months Ended

Sep. 30, 2015

Equity [Abstract]

Schedule of partners' capital

The table below summarizes changes in the number of units outstanding from December 31, 2014 through September 30, 2015 (in million units):

	Partnership
	Common	General Partner	Total
Balance at December 31, 2014	80.1	1.6	81.7
Issuance of units under ATM Program	1.4	—	1.4
Issuance of units to QEPM unitholders (a)	7.1	—	7.1
Balance at September 30, 2015	88.6	1.6	90.2

_____________

(a) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

The summarized changes in the carrying amount of our equity are as follows (in millions):

	Partnership
	Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2014	$	1,474		$	(19	)	$	435		$	1,890
Equity offering under ATM Program, net of issuance costs	66			5			—			71
Distributions (a)	(173		)	(48		)	(20		)	(241		)
Net earnings	153			51			19			223
Contributions (b)	14			7			—			21
QEPM Merger (c)	350			—			(350		)	—
Other	3			—			—			3
Balance at September 30, 2015	$	1,887		$	(4	)	$	84		$	1,967

_____________

(a) Represents cash distributions declared and paid during the nine months ended September 30, 2015 relating to the fourth quarter of 2014 through the second quarter of 2015.

(b) Includes Tesoro and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

(c) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

Schedule of quarterly distributions

The table below summarizes the quarterly distributions related to our quarterly financial results:

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2014	$	0.6675	$	70	February 13, 2015	February 2, 2015
March 31, 2015	0.6950		70		May 15, 2015	May 4, 2015
June 30, 2015	0.7225		81		August 14, 2015	August 3, 2015
September 30, 2015 (a)	0.7500		86		November 13, 2015	November 2, 2015

_____________

(a) This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

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Related-Party Transactions (Tables)

9 Months Ended

Sep. 30, 2015

Related Party Transactions [Abstract]

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):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Revenues (a)	$	152	$	130	$	454	$	358
Operating and maintenance expenses	28		18		77		56
Imbalance settlement gains and reimbursements from    Tesoro (b)	12		17		31		32
General and administrative expenses	16		11		51		28

_______________

(a) Tesoro accounted for 54% and 55%of our total revenues for the three and nine months ended September 30, 2015, respectively, and 86% and 87% of our total revenues for the three and nine months ended September 30, 2014, respectively.

(b) Includes imbalance settlement gains of$2 million and $9 million for the three months ended September 30, 2015 and 2014, respectively, and $6 million and $14 millionfor the nine months ended September 30, 2015 and 2014, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $10 million and $8 million for the three months ended September 30, 2015 and 2014, respectively, and $25 million and $18 million for the nine months ended September 30, 2015 and 2014, respectively.

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Condensed Consolidating Financial Information (Notes)

9 Months Ended

Sep. 30, 2015

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. QEPFS, our wholly-owned subsidiary acquired on December 2, 2014, and certain of its subsidiaries were elected guarantors of these obligations in January 2015. As of September 30, 2015, TLLP and certain subsidiary guarantors have fully and unconditionally guaranteed our registered 2020 Senior Notes and 2021 Senior Notes. 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 condensed consolidated financial statements and notes thereto. The December 31, 2014 balance sheet has been adjusted to conform to the guarantor structure as of September 30, 2015, and now includes QEPM and GRP within the guarantor subsidiaries column as a result of the Merger. 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 wholly-owned and are jointly and severally liable for TLLP’s outstanding senior notes. The separate condensed consolidating financial information is presented using the equity method of accounting for investments in subsidiaries. Intercompany transactions between subsidiaries are presented gross and eliminated in the consolidating adjustments column. Additionally, certain fair value adjustments resulting from the purchase price allocation for the Rockies Natural Gas Business Acquisition were not pushed down to previously non-wholly owned subsidiaries that are now included as guarantor subsidiaries as a result of the Merger as well as non-guarantor subsidiaries; rather, the fair value adjustments are included within the consolidating adjustments column.

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 its guarantors 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 the three and nine months ended September 30, 2014.

Condensed Consolidating Statement of Operations

For the Three Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	153		$	7		$	(8	)	$	152
Third-party	—			129			1			—			130
Total Revenues	—			282			8			(8		)	282
Costs and Expenses
Operating and maintenance expenses	—			115			—			(7		)	108
Imbalance settlement gains and reimbursements	—			(10		)	—			—			(10		)
General and administrative expenses	9			19			—			—			28
Depreciation and amortization expenses	—			36			3			5			44
Total Costs and Expenses	9			160			3			(2		)	170
Operating Income (Loss)	(9		)	122			5			(6		)	112
Interest and financing costs, net	—			(34		)	—			(3		)	(37		)
Equity in earnings of unconsolidated affiliates	—			2			—			—			2
Equity in earnings of subsidiaries	83			4			—			(87		)	—
Net Earnings	$	74		$	94		$	5		$	(96	)	$	77
Net earnings attributable to noncontrolling interest	—			(2		)	(1		)	—			(3		)
Net earnings attributable to partners	$	74		$	92		$	4		$	(96	)	$	74

Condensed Consolidating Statement of Operations

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Revenues
Affiliate	$	—		$	454		$	20		$	(20	)	$	454
Third-party	—			365			4			(3		)	366
Total Revenues	—			819			24			(23		)	820
Costs and Expenses
Operating and maintenance expenses	—			326			1			(20		)	307
Imbalance settlement gains and reimbursements	—			(29		)	—			—			(29		)
General and administrative expenses	21			60			—			—			81
Depreciation and amortization expenses	—			107			9			16			132
Loss on asset disposals and impairments	—			5			—			(5		)	—
Total Costs and Expenses	21			469			10			(9		)	491
Operating Income (Loss)	(21		)	350			14			(14		)	329
Interest and financing costs, net	—			(103		)	—			(9		)	(112		)
Equity in earnings of unconsolidated affiliates	—			7			—			(1		)	6
Equity in earnings of subsidiaries	225			11			—			(236		)	—
Net Earnings	$	204		$	265		$	14		$	(260	)	$	223
Net earnings attributable to noncontrolling interest	—			(16		)	(3		)	—			(19		)
Net earnings attributable to partners	$	204		$	249		$	11		$	(260	)	$	204

Condensed Consolidating Balance Sheet as of September 30, 2015

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	7	$	—	$	4	$	—		$	11
Receivables, net
Trade	—		131		1		—			132
Affiliate	2		81		2		(5		)	80
Prepayments and other	5		5		—		(2		)	8
Total Current Assets	14		217		7		(7		)	231
Net property, plant and equipment	—		2,778		179		475			3,432
Acquired intangibles, net	—		577		—		375			952
Goodwill	—		63		—		94			157
Investment in unconsolidated affiliates	—		42		—		14			56
Investments in subsidiaries	4,814		142		—		(4,956		)	—
Long-term intercompany receivable	—		184		—		(184		)	—
Other noncurrent assets	1		22		—		—			23
Total Assets	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	2	$	83	$	—	$	—		$	85
Affiliate	4		53		—		(5		)	52
Accrued interest and financing costs	65		—		—		—			65
Other current liabilities	21		44		1		(2		)	64
Total Current Liabilities	92		180		1		(7		)	266
Long-term intercompany payable	292		—		2		(294		)	—
Other noncurrent liabilities	—		57		1		(9		)	49
Debt, net of unamortized issuance costs	2,561		8		—		—			2,569
Equity - TLLP	1,884		3,780		142		(3,923		)	1,883
Equity - Noncontrolling interest	—		—		40		44			84
Total Liabilities and Equity	$	4,829	$	4,025	$	186	$	(4,189	)	$	4,851

Condensed Consolidating Balance Sheet as of December 31, 2014 (a)

(In millions)

	Parent		Guarantor Subsidiaries		Non-Guarantors		Consolidating Adjustments			Consolidated
ASSETS
Current Assets
Cash and cash equivalents	$	—	$	17	$	2	$	—		$	19
Receivables, net
Trade	—		121		1		—			122
Affiliate	3		66		—		—			69
Other	—		18		—		—			18
Prepayments and other	3		4		—		—			7
Total Current Assets	6		226		3		—			235
Net property, plant and equipment	1		2,639		188		478			3,306
Acquired intangibles, net	—		590		—		383			973
Goodwill	—		48		—		116			164
Investment in unconsolidated affiliates	—		43		—		14			57
Investments in subsidiaries	4,233		152		—		(4,385		)	—
Long-term intercompany receivable	—		196		5		(201		)	—
Other noncurrent assets	—		30		—		—			30
Total Assets	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	6	$	120	$	—	$	—		$	126
Affiliate	3		50		—		—			53
Accrued interest and financing costs	28		—		—		—			28
Other current liabilities	21		60		—		(2		)	79
Total Current Liabilities	58		230		—		(2		)	286
Long-term intercompany payable	191		5		—		(196		)	—
Other noncurrent liabilities	—		54		1		(10		)	45
Debt, net of unamortized issuance costs	2,536		8		—		—			2,544
Equity - TLLP	1,455		3,598		152		(3,750		)	1,455
Equity - Noncontrolling interest	—		29		43		363			435
Total Liabilities and Equity	$	4,240	$	3,924	$	196	$	(3,595	)	$	4,765

_____________

(a) Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

Condensed Consolidating Statement of Cash Flows

For the Nine Months EndedSeptember 30, 2015

(In millions)

	Parent			Guarantor Subsidiaries			Non-Guarantors			Consolidating Adjustments			Consolidated
Cash Flows From (Used In) Operating Activities:
Net cash from (used in) operating activities	$	19		$	355		$	21		$	(31	)	$	364
Cash Flows From (Used In) Investing Activities:
Capital expenditures	—			(234		)	—			—			(234		)
Acquisitions	—			(6		)	—			—			(6		)
Investments in subsidiaries	(6		)	—			—			6			—
Net cash used in investing activities	(6		)	(240		)	—			6			(240		)
Cash Flows From (Used In) Financing Activities:
Proceeds from issuance of common units, net of issuance costs	71			—			—			—			71
Quarterly distributions to unitholders	(173		)	—			—			—			(173		)
Quarterly distributions to general partner	(49		)	—			(20		)	21			(48		)
Distributions to noncontrolling interest	—			(15		)	(5		)	—			(20		)
Distributions to subsidiaries	—			—			—			—			—
Borrowings under revolving credit agreement	346			—			—			—			346
Repayments under revolving credit agreement	(326		)	—			—			—			(326		)
Contributions	—			6			—			(6		)	—
Intercompany borrowings (payments)	107			(123		)	6			10			—
Capital contributions by affiliate	18			—			—			—			18
Net cash from (used in) financing activities	(6		)	(132		)	(19		)	25			(132		)
Increase (Decrease) in Cash and Cash Equivalents	7			(17		)	2			—			(8		)
Cash and Cash Equivalents, Beginning of Period	—			17			2			—			19
Cash and Cash Equivalents, End of Period	$	7		$	—		$	4		$	—		$	11

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Equity (Notes)

9 Months Ended

Sep. 30, 2015

Equity [Abstract]

Equity

EQUITY

We had 60,452,240 common public units outstanding as of September 30, 2015. 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 September 30, 2015, which together constitutes a 33% ownership interest in us.

ATM Programs. On June 25, 2014, we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission 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 “2014 ATM Program”). The 2014 ATM Program expired during the second quarter of 2015. During the nine months ended September 30, 2015, we issued an aggregate of 819,513 common units, under our 2014 ATM Program, generating net proceeds of approximately $45 million. There were no common units issued during the three months ended September 30, 2015. The net proceeds from sales under the 2014 ATM Program were used for general partnership purposes, which included debt repayment, acquisitions, capital expenditures and additions to working capital.

On August 21, 2015, we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission on August 6, 2015, authorizing the continuous issuance of up to an aggregate of $750 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 “2015 ATM Program”). During the three and nine months ended September 30, 2015, we issued an aggregate of 537,014 common units under our 2015 ATM Program, generating net proceeds of approximately $26 million. The net proceeds from sales under the 2015 ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

The table below summarizes changes in the number of units outstanding from December 31, 2014 through September 30, 2015 (in million units):

	Partnership
	Common	General Partner	Total
Balance at December 31, 2014	80.1	1.6	81.7
Issuance of units under ATM Program	1.4	—	1.4
Issuance of units to QEPM unitholders (a)	7.1	—	7.1
Balance at September 30, 2015	88.6	1.6	90.2

_____________

(a) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

The summarized changes in the carrying amount of our equity are as follows (in millions):

	Partnership
	Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2014	$	1,474		$	(19	)	$	435		$	1,890
Equity offering under ATM Program, net of issuance costs	66			5			—			71
Distributions (a)	(173		)	(48		)	(20		)	(241		)
Net earnings	153			51			19			223
Contributions (b)	14			7			—			21
QEPM Merger (c)	350			—			(350		)	—
Other	3			—			—			3
Balance at September 30, 2015	$	1,887		$	(4	)	$	84		$	1,967

_____________

(a) Represents cash distributions declared and paid during the nine months ended September 30, 2015 relating to the fourth quarter of 2014 through the second quarter of 2015.

(b) Includes Tesoro and TLGP contributions to the Partnership primarily related to reimbursements for capital spending pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement.

(c) On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

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 connection with the Rockies Natural Gas Business Acquisition, our general partner has waived its right to $10 million of general partner distributions with respect to IDRs during 2015 (pro rata on a quarterly basis). The table below summarizes the quarterly distributions related to our quarterly financial results:

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2014	$	0.6675	$	70	February 13, 2015	February 2, 2015
March 31, 2015	0.6950		70		May 15, 2015	May 4, 2015
June 30, 2015	0.7225		81		August 14, 2015	August 3, 2015
September 30, 2015 (a)	0.7500		86		November 13, 2015	November 2, 2015

_____________

(a) This distribution was declared on October 22, 2015 and will be paid on the date of distribution.

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Segment Disclosures (Notes)

9 Months Ended

Sep. 30, 2015

Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]

Segment Disclosures

SEGMENT DISCLOSURES

Our revenues are derived from three operating segments: Gathering, Processing, Terminalling and Transportation. 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 Green River Processing, LLC (“GRP”), which owns one fractionation facility and two gas processing complexes. Our Terminalling and Transportation segment consists of:

• 24 crude oil and refined products terminals and storage facilities in the western and midwestern U.S.;

• four marine terminals in California;

• 130 miles of pipelines, which transport products and crude oil from Tesoro’s refineries to nearby facilities in Salt Lake City and Los Angeles;

• 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 rail-car unloading facility in Washington;

• a petroleum coke handling and storage facility in Los Angeles; and

• a regulated common carrier refined products pipeline system connecting Tesoro’s Kenai refinery to terminals in Anchorage, Alaska.

Our revenues are generated from 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 natural gas liquids. The commercial agreements with Tesoro are described in greater detail in Note 3 to our Annual Report on Form 10-K for the year ended December 31, 2014. We do not have any foreign operations.

Our operating segments are strategic business units that offer different services in various geographical locations. We evaluate the performance of each segment based on its respective operating income. Certain general and administrative expenses, interest and financing costs and equity in earnings of unconsolidated affiliates 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 and other assets that are not associated with a specific operating segment.

Segment information related to continuing operations is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Revenues
Gathering:
Affiliate	$	18		$	27		$	71		$	75
Third-party	69			5			182			9
Total Gathering	87			32			253			84
Processing
Affiliate	26			—			71			—
Third-party	45			—			134			—
Total Processing	71			—			205			—
Terminalling and Transportation:
Affiliate	108			103			312			283
Third-party	16			15			50			43
Total Terminalling and Transportation	124			118			362			326
Total Segment Revenues	$	282		$	150		$	820		$	410
Segment Operating Income
Gathering	$	42		$	15		$	121		$	38
Processing	29			—			77			—
Terminalling and Transportation	57			52			174			145
Total Segment Operating Income	128			67			372			183
Unallocated general and administrative expenses	(16		)	(6		)	(43		)	(14		)
Interest and financing costs, net	(37		)	(28		)	(112		)	(63		)
Equity in earnings of unconsolidated affiliates	2			—			6			—
Net Earnings	$	77		$	33		$	223		$	106
Capital Expenditures
Gathering	$	72		$	40		$	177		$	92
Processing	5			—			10			—
Terminalling and Transportation	15			23			48			45
Total Capital Expenditures	$	92		$	63		$	235		$	137

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Organization and Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of accounting, policy

We prepare our condensed combined consolidated financial statements in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the amounts of assets and liabilities and revenues and expenses reported as of and during the periods presented.

New accounting pronouncement, policy

New Accounting Standards and Disclosures

Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”), which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017 given the FASB’s recent deferral of ASU 2014-09’s effective date. Entities may choose to early adopt ASU 2014-09 as of the original effective date. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the standard to determine the method of adoption and the impact of ASU 2014-09 on our financial statements and related disclosures.

Pushdown Accounting. In November 2014, the SEC released a Staff Accounting Bulletin 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 fair value of 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. We plan to apply pushdown accounting to applicable entities acquired as part of the Rockies Natural Gas Business Acquisition upon finalization of the purchase price allocation.

Consolidation.  In February 2015, the FASB issued ASU 2015-02, “Amendments to the Consolidation Analysis” (“ASU 2015-02”). This standard modifies existing consolidation guidance for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. ASU 2015-02 is effective for interim and annual periods beginning after December 15, 2015, and requires either a retrospective or a modified retrospective approach to adoption. Early adoption is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements, as well as the available transition methods.

Treatment of Predecessor in EPU calculation. In April 2015, the FASB issued ASU 2015-06 (“ASU 2015-06”), which requires a master limited partnership to allocate earnings or losses of transferred net assets for periods prior to asset purchases from an entity under common control entirely to the general partner when calculating earnings per unit (“EPU”). ASU 2015-06 is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. We elected to adopt this guidance beginning in the first quarter of 2015. Adoption of ASU 2015-06 did not impact the disclosed amounts of earnings per unit attributable to limited partners; however, the allocation of earnings presented in our EPU disclosure for the three and nine months ended September 30, 2014 has been modified to conform to the requirements of the final standard. There were no asset purchases from Tesoro during the three and nine months ended September 30, 2015.

Debt Issuance Costs. In April 2015, the FASB issued ASU 2015-03, “Interest - Imputation of Interest” (“ASU 2015-03”), which will simplify the presentation of debt issuance costs. Under ASU 2015-03, debt issuance costs related to a recognized debt liability will be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability. As a result, our balance sheet will reflect a reclassification of unamortized debt issuance costs from other noncurrent assets to debt. ASU 2015-03 is effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. We adopted this standard in the first quarter of 2015 and applied the changes retrospectively to prior periods presented. The adoption of this standard resulted in the reclassification of $49 million from other noncurrent assets to debt on the balance sheet at December 31, 2014. Unamortized debt issuance costs of $43 million are recorded as a reduction to debt on the balance sheet at September 30, 2015.

Business Combinations. In September 2015, the FASB issued ASU 2015-16, “Simplifying the Accounting for Measurement-Period Adjustments” (“ASU 2015-16”). The standard requires an acquirer to recognize the cumulative impact of adjustments to provisional purchase price amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The standard also requires an entity to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. ASU 2015-16 is effective for interim and annual periods beginning after beginning after December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. Early application is permitted for financial statements that have not been issued.

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Net Earnings Per Unit (Details) shares in Millions, $ in Millions			3 Months Ended		9 Months Ended
		May. 16, 2014	Sep. 30, 2015 USD ($) $ / shares shares	Sep. 30, 2014 USD ($) $ / shares shares	Sep. 30, 2015 USD ($) $ / shares shares	Sep. 30, 2014 USD ($) $ / shares shares
Net Earnings Per Unit
Net earnings			$ 77.0	$ 33.0	$ 223.0	$ 106.0
Net earnings attributable to noncontrolling interest			(3.0)	0.0	(19.0)	0.0
Special allocations of net earnings (“Special Allocations”)	[1]		0.0	7.0	0.0	7.0
Net earnings (Loss) Attributable to Parent	[2]		74.0	40.0	204.0	113.0
Allocation of distributions less (greater) than earnings			$ (12.0)	$ (26.0)	$ (33.0)	$ (34.0)
Weighted average limited partner units outstanding:
Common units - basic | shares			86.6	55.9	82.5	47.4
Common unit equivalents | shares			0.1	0.1	0.1	0.1
Common units - diluted | shares			86.7	56.0	82.6	47.5
Subordinated units - basic and diluted | shares	[3]		0.0	0.0	0.0	7.5
Net Earnings per Limited Partner Unit
Common - basic | $ / shares			$ 0.62	$ 0.33	$ 1.85	$ 1.50
Common - diluted | $ / shares			0.62	0.33	1.85	1.50
Subordinated - basic and diluted | $ / shares			$ 0.00	$ 0.00	$ 0.00	$ 1.28
Footnote
Net earnings (Loss) Attributable To Predecessors			$ 0.0	$ 0.0	$ 0.0	$ 4.0
Maximum percentage distribution to general partner			50.00%	50.00%	50.00%	50.00%
Minimum distribution level for IDRs (dollars per unit) | $ / shares			0.388125	0.388125	0.388125	0.388125
Subordinated units effective conversion date		May 16, 2014
General Partner
Net Earnings Per Unit
Net earnings					$ 51.0
General partner's distributions			$ 1.0	$ 1.0	4.0	$ 3.0
General partner's IDRs	[4]		19.0	13.0	47.0	26.0
Allocation of distributions less (greater) than earnings	[2]		0.0	0.0	0.0	(4.0)
Total partner's earnings			20.0	14.0	51.0	25.0
Limited Partner, common units
Net Earnings Per Unit
Net earnings					153.0
Special allocations of net earnings (“Special Allocations”)			0.0	7.0	0.0	7.0
Limited partners' distributions			66.0	52.0	186.0	104.0
Allocation of distributions less (greater) than earnings			(12.0)	(26.0)	(33.0)	(26.0)
Total partner's earnings			54.0	19.0	153.0	71.0
Limited Partner, subordinated units
Net Earnings Per Unit
Limited partners' distributions	[3]		0.0	0.0	0.0	14.0
Allocation of distributions less (greater) than earnings	[3]		0.0	0.0	0.0	(4.0)
Total partner's earnings	[3]		0.0	$ 0.0	0.0	$ 10.0
Rockies Natural Gas Business Acquisition
Footnote
General partner distribution amount forfeited			$ 2.5		$ 7.5

[1] 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 TLLP common unitholders for the premium paid in connection with the redemption of senior notes during the three and nine months ended September 30, 2014.

[2] In April 2015, the FASB issued ASU 2015-06 concerning historical earnings per unit for master limited partnership drop down transactions. We have revised the historical allocation of general partner earnings to include the Predecessor losses TLLP incurred of $4 million during the nine months ended September 30, 2014. There were no earnings or losses for the three months ended September 30, 2014. See Note 1 for additional information on the new guidance.

[3] On May 16, 2014, the 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 earnings were allocated to the subordinated units through May 15, 2014.

[4] IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $2.5 million and $7.5 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP in connection with the Rockies Natural Gas Business Acquisition. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2014, for further discussion related to IDRs.

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2015

Property, Plant and Equipment [Abstract]

Property, plant and equipment

Property, plant and equipment, at cost, is as follows (in millions):

	September 30, 2015			December 31, 2014
Gathering	$	1,695		$	1,507
Processing	546			539
Terminalling and Transportation	1,525			1,478
Other	23			27
Gross Property, Plant and Equipment	3,789			3,551
Accumulated depreciation	(357		)	(245		)
Net Property, Plant and Equipment	$	3,432		$	3,306

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Organization and Basis of Presentation, Acquisition and Merger Agreement (Details) shares in Millions, $ in Billions	Jul. 22, 2015 shares	Apr. 06, 2015	Dec. 02, 2014 USD ($)	Sep. 30, 2014 facility	Jul. 01, 2014 terminals tanks facility
Acquisition
Limited Partner Common Units, Conversion Ratio	0.3088
Effective date of Merger Completion	Jul. 22, 2015
Units issued under Merger agreement | shares	7.1
Rockies Natural Gas Business Acquisition
Acquisition
Effective date of acquisition			Dec. 02, 2014
Purchase price | $			$ 2.5
Merger Agreement
Acquisition
Merger agreement date		Apr. 06, 2015
Phase One | West Coast Logistics Assets Acquisition
Acquisition
Effective date of acquisition					Jul. 01, 2014
Phase Two | West Coast Logistics Assets Acquisition
Acquisition
Effective date of acquisition				Sep. 30, 2014
Truck Terminal | West Coast Logistics Assets Acquisition
Acquisition
Number of assets (assets) | terminals					3
Storage Tank | West Coast Logistics Assets Acquisition
Acquisition
Number of assets (assets) | tanks					10
Rail Loading And unloading Facility | West Coast Logistics Assets Acquisition
Acquisition
Number of assets (assets)					2
Refined Products Pipeline | Phase Two | West Coast Logistics Assets Acquisition
Acquisition
Number of assets (assets)				1

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Condensed Consolidating Financial Information Statement of Cash Flows (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2015		Sep. 30, 2014
Cash Flows from (used in) Operating Activities
Net cash from (used in) operating activities		$ 364		$ 154
Cash Flows from (used in) Investing Activities
Capital expenditures		(234)		(116)
Acquisitions		(6)		0
Investment in subsidiaries		0
Net cash used in investing activities		(240)		(106)
Cash Flows from (used in) Financing Activities
Proceeds from issuance of common units, net of issuance costs		71
Quarterly distributions to unitholders		(173)
Quarterly distributions to general partner		(48)		(21)
Distributions to noncontrolling interest		(20)		0
Distributions to subsidiaries		0
Borrowings under revolving credit agreement		346		295
Repayments under revolving credit agreement		(326)		(52)
Contributions		0
Intercompany borrowings (payments)		0
Capital contributions by affiliate		18
Net cash used in financing activities		(132)		(67)
Increase (Decrease) in Cash and Cash Equivalents		(8)		(19)
Cash and Cash Equivalents, Beginning of Period		19	[1]	23
Cash and Cash Equivalents, End of Period		11		$ 4
Parent
Cash Flows from (used in) Operating Activities
Net cash from (used in) operating activities		19
Cash Flows from (used in) Investing Activities
Capital expenditures		0
Acquisitions		0
Investment in subsidiaries		(6)
Net cash used in investing activities		(6)
Cash Flows from (used in) Financing Activities
Proceeds from issuance of common units, net of issuance costs		71
Quarterly distributions to unitholders		(173)
Quarterly distributions to general partner		(49)
Distributions to noncontrolling interest		0
Distributions to subsidiaries		0
Borrowings under revolving credit agreement		346
Repayments under revolving credit agreement		(326)
Contributions		0
Intercompany borrowings (payments)		107
Capital contributions by affiliate		18
Net cash used in financing activities		(6)
Increase (Decrease) in Cash and Cash Equivalents		7
Cash and Cash Equivalents, Beginning of Period	[1]	0
Cash and Cash Equivalents, End of Period		7
Guarantor Subsidiaries
Cash Flows from (used in) Operating Activities
Net cash from (used in) operating activities		355
Cash Flows from (used in) Investing Activities
Capital expenditures		(234)
Acquisitions		(6)
Investment in subsidiaries		0
Net cash used in investing activities		(240)
Cash Flows from (used in) Financing Activities
Proceeds from issuance of common units, net of issuance costs		0
Quarterly distributions to unitholders		0
Quarterly distributions to general partner		0
Distributions to noncontrolling interest		(15)
Distributions to subsidiaries		0
Borrowings under revolving credit agreement		0
Repayments under revolving credit agreement		0
Contributions		6
Intercompany borrowings (payments)		(123)
Capital contributions by affiliate		0
Net cash used in financing activities		(132)
Increase (Decrease) in Cash and Cash Equivalents		(17)
Cash and Cash Equivalents, Beginning of Period	[1]	17
Cash and Cash Equivalents, End of Period		0
Non-Guarantors
Cash Flows from (used in) Operating Activities
Net cash from (used in) operating activities		21
Cash Flows from (used in) Investing Activities
Capital expenditures		0
Acquisitions		0
Investment in subsidiaries		0
Net cash used in investing activities		0
Cash Flows from (used in) Financing Activities
Proceeds from issuance of common units, net of issuance costs		0
Quarterly distributions to unitholders		0
Quarterly distributions to general partner		(20)
Distributions to noncontrolling interest		(5)
Distributions to subsidiaries		0
Borrowings under revolving credit agreement		0
Repayments under revolving credit agreement		0
Contributions		0
Intercompany borrowings (payments)		6
Capital contributions by affiliate		0
Net cash used in financing activities		(19)
Increase (Decrease) in Cash and Cash Equivalents		2
Cash and Cash Equivalents, Beginning of Period	[1]	2
Cash and Cash Equivalents, End of Period		4
Consolidating Adjustments
Cash Flows from (used in) Operating Activities
Net cash from (used in) operating activities		(31)
Cash Flows from (used in) Investing Activities
Capital expenditures		0
Acquisitions		0
Investment in subsidiaries		6
Net cash used in investing activities		6
Cash Flows from (used in) Financing Activities
Proceeds from issuance of common units, net of issuance costs		0
Quarterly distributions to unitholders		0
Quarterly distributions to general partner		21
Distributions to noncontrolling interest		0
Distributions to subsidiaries		0
Borrowings under revolving credit agreement		0
Repayments under revolving credit agreement		0
Contributions		(6)
Intercompany borrowings (payments)		10
Capital contributions by affiliate		0
Net cash used in financing activities		25
Increase (Decrease) in Cash and Cash Equivalents		0
Cash and Cash Equivalents, Beginning of Period	[1]	0
Cash and Cash Equivalents, End of Period		$ 0

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Equity, Units Rollforward (Details) - shares shares in Millions			9 Months Ended
		Jul. 22, 2015	Sep. 30, 2015
Changes in Units Outstanding
Balance at December 31, 2014			81.7
Issuance of units		7.1
Balance at September 30, 2015			90.2
Effective date of Merger Completion		Jul. 22, 2015
Common
Changes in Units Outstanding
Balance at December 31, 2014			80.1
Balance at September 30, 2015			88.6
General Partner
Changes in Units Outstanding
Balance at December 31, 2014			1.6
Balance at September 30, 2015			1.6
2014 ATM Program
Changes in Units Outstanding
Issuance of units			1.4
2014 ATM Program | Common
Changes in Units Outstanding
Issuance of units			1.4
2014 ATM Program | General Partner
Changes in Units Outstanding
Issuance of units			0.0
QEP Midstream Partners, LP
Changes in Units Outstanding
Issuance of units	[1]		7.1
QEP Midstream Partners, LP | Common
Changes in Units Outstanding
Issuance of units	[1]		7.1
QEP Midstream Partners, LP | General Partner
Changes in Units Outstanding
Issuance of units	[1]		0.0

[1] On July 22, 2015, common units were issued to QEPM unitholders upon completion of the Merger discussed in Note 1.

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Condensed Statements of Combined Consolidated Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015		Sep. 30, 2014
Cash Flows from (used in) Operating Activities
Net earnings	$ 223		$ 106
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	132		51
Other non-cash operating activities	12		2
Changes in current assets and current liabilities	(1)		(8)
Changes in non-current assets and liabilities	(2)		3
Net cash from operating activities	364		154
Cash Flows from (used in) Investing Activities
Capital expenditures	(234)		(116)
Acquisitions	(6)		0
Proceeds from sale of assets	0		10
Net cash used in investing activities	(240)		(106)
Cash Flows from (used in) Financing Activities
Proceeds from issuance of units, net of issuance costs	71		159
Quarterly distributions to unitholders	(173)		(97)
Quarterly distributions to general partner	(48)		(21)
Distributions to noncontrolling interest	(20)		0
Distributions in connection with acquisitions	0		(243)
Borrowings under revolving credit agreement	346		295
Repayments under revolving credit agreement	(326)		(52)
Repayments of senior notes	0		(130)
Capital contributions by affiliate	18		20
Other financing activities	0		2
Net cash used in financing activities	(132)		(67)
Decrease in Cash and Cash Equivalents	(8)		(19)
Cash and Cash Equivalents, Beginning of Period	19	[1]	23
Cash and Cash Equivalents, End of Period	$ 11		$ 4

[1] Presentation of the condensed consolidating balance sheet as of December 31, 2014 has been adjusted to conform to the current period presentation.

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Property, Plant and Equipment (Notes)

9 Months Ended

Sep. 30, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment, at cost, is as follows (in millions):

	September 30, 2015			December 31, 2014
Gathering	$	1,695		$	1,507
Processing	546			539
Terminalling and Transportation	1,525			1,478
Other	23			27
Gross Property, Plant and Equipment	3,789			3,551
Accumulated depreciation	(357		)	(245		)
Net Property, Plant and Equipment	$	3,432		$	3,306

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Organization and Basis of Presentation, Fair Value (Details) - USD ($) $ in Billions	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Percent of trade payables outstanding	1.00%
Percent of trade receivables outstanding	1.00%
Debt, carrying value	$ 2.6	$ 2.6
Debt, fair value	$ 2.6	$ 2.6
Minimum
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Fair Value Assumptions, Expected Term	90 days

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Commitments and Contingencies (Details) - USD ($) $ in Millions						9 Months Ended	21 Months Ended
	Mar. 06, 2015	Jan. 30, 2014	Mar. 22, 2013	Mar. 18, 2013	May. 01, 2012	Sep. 30, 2015	Sep. 30, 2015	Dec. 31, 2014	Dec. 02, 2014
Changes in Environmental Liabilities
Accruals for environmental expenditures						$ 15	$ 15	$ 32
Tioga Crude Oil Pipeline Release
Changes in Environmental Liabilities
Accruals for environmental expenditures						8	8	25
Expenditures						(17)
Environmental liability insurance deductible						1	1
Environmental liabilities insurance coverage limit						25
Insurance settlements receivable						0	0	18
Total remediation costs						(42)
Chevron Corrective Action Order
Changes in Environmental Liabilities
Diesel fuel release, period of occurrence				March 18, 2013
PHMSA | Chevron Corrective Action Order
Changes in Environmental Liabilities
Regulatory action issuance date			Mar. 22, 2013
Regulatory action closure date	Mar. 06, 2015
Northwest Products System
Changes in Environmental Liabilities
Accruals for environmental expenditures						$ 4	4	$ 6
Questar Gas Company v. QEP Field Services Company
Changes in Environmental Liabilities
Complaint filing date					May 1, 2012
Disputed amount netted from gathering fees							$ 18
Liability for estimated damages									$ 21
XTO Energy Inc. v. QEP Field Services Company
Changes in Environmental Liabilities
Complaint filing date		January 30, 2014

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Net Earnings Per Unit (Tables)

9 Months Ended

Sep. 30, 2015

Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax [Abstract]

Schedule of calculation of net earnings per unit

The calculation of net earnings per unit is as follows (in millions, except per unit amounts):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Net earnings	$	77		$	33		$	223		$	106
Net earnings attributable to noncontrolling interest	(3		)	—			(19		)	—
Special allocations of net earnings (“Special Allocations”) (a)	—			7			—			7
Net earnings, excluding noncontrolling interest (b)	74			40			204			113
General partner’s distributions	(1		)	(1		)	(4		)	(3		)
General partner’s IDRs (c)	(19		)	(13		)	(47		)	(26		)
Limited partners’ distributions on common units	(66		)	(52		)	(186		)	(104		)
Limited partners’ distributions on subordinated units (d)	—			—			—			(14		)
Distributions greater than earnings	$	(12	)	$	(26	)	$	(33	)	$	(34	)
General partner’s earnings:
Distributions	$	1		$	1		$	4		$	3
General partner’s IDRs (c)	19			13			47			26
Allocation of distributions greater than earnings (b)	—			—			—			(4		)
Total general partner’s earnings	$	20		$	14		$	51		$	25
Limited partners’ earnings on common units:
Distributions	$	66		$	52		$	186		$	104
Special Allocations	—			(7		)	—			(7		)
Allocation of distributions greater than earnings	(12		)	(26		)	(33		)	(26		)
Total limited partners’ earnings on common units	$	54		$	19		$	153		$	71
Limited partners’ earnings on subordinated units (d):
Distributions	$	—		$	—		$	—		$	14
Allocation of distributions greater than earnings	—			—			—			(4		)
Total limited partners’ earnings on subordinated units	$	—		$	—		$	—		$	10
Weighted average limited partner units outstanding
Common units - basic	86.6			55.9			82.5			47.4
Common unit equivalents	0.1			0.1			0.1			0.1
Common units - diluted	86.7			56.0			82.6			47.5
Subordinated units - basic and diluted (d)	—			—			—			7.5
Net earnings per limited partner unit:
Common - basic	$	0.62		$	0.33		$	1.85		$	1.50
Common - diluted	$	0.62		$	0.33		$	1.85		$	1.50
Subordinated - basic and diluted	$	—		$	—		$	—		$	1.28

_______________

(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 TLLP common unitholders for the premium paid in connection with the redemption of senior notes during the three and nine months ended September 30, 2014.

(b) In April 2015, the FASB issued ASU 2015-06 concerning historical earnings per unit for master limited partnership drop down transactions. We have revised the historical allocation of general partner earnings to include the Predecessor losses TLLP incurred of $4 million during the nine months ended September 30, 2014. There were no earnings or losses for the three months ended September 30, 2014. See Note 1 for additional information on the new guidance.

(c) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.388125 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $2.5 millionand $7.5 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP in connection with the Rockies Natural Gas Business Acquisition. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2014, for further discussion related to IDRs.

(d) On May 16, 2014, the 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 earnings were allocated to the subordinated units through May 15, 2014.