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, 2016

or

o 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.  Yesþ No o

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).  YesþNoo

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	o
Non-accelerated filer	o (Do not check if a smaller reporting company)	Smaller reporting company	o

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

There were 102,096,039 common units and 2,083,330 general partner units of the registrant outstanding at October 26, 2016.

TABLE OF CONTENTS

TESORO LOGISTICS LP

QUARTERLY REPORT ON FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2016

PART I. FINANCIAL INFORMATION	Page
Item 1. Financial Statements (Unaudited)
Condensed Statements of Combined Consolidated Operations - Three and Nine Months Ended September 30, 2016 and 2015	3
Condensed Consolidated Balance Sheets - September 30, 2016 and December 31, 2015	4
Condensed Statements of Combined Consolidated Cash Flows - Nine Months Ended September 30, 2016 and 2015	5
Notes to Condensed Combined Consolidated Financial Statements	6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	18
Item 3. Quantitative and Qualitative Disclosures About Market Risk	33
Item 4. Controls and Procedures	34
PART II. OTHER INFORMATION
Item 1. Legal Proceedings	35
Item 1A. Risk Factors	35
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	35
Item 6. Exhibits	35
SIGNATURES	37

2 | Tesoro Logistics LP

FINANCIAL STATEMENTS

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,
	2016 (a)			2015 (a)			2016 (a)			2015 (a)
	(In millions, except per unit amounts)
Revenues
Affiliate	$	184		$	152		$	521		$	454
Third-party	124			130			380			366
Total Revenues	308			282			901			820
Costs and Expenses
Operating expenses	110			113			332			323
Imbalance settlement gains and reimbursements	(6		)	(10		)	(19		)	(29		)
General and administrative expenses	24			28			70			81
Depreciation and amortization expenses	45			45			134			133
Loss on asset disposals and impairments	2			—			3			—
Operating Income	133			106			381			312
Interest and financing costs, net	(49		)	(37		)	(138		)	(112		)
Equity in earnings of equity method investments	3			2			10			6
Other income, net	—			—			6			—
Net Earnings	$	87		$	71		$	259		$	206
Loss attributable to Predecessors	$	1		$	6		$	4		$	17
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Net Earnings Attributable to Partners	88			74			263			204
General partner’s interest in net earnings, including incentive distribution rights	(40		)	(20		)	(108		)	(51		)
Limited Partners’ Interest in Net Earnings	$	48		$	54		$	155		$	153
Net Earnings per Limited Partner Unit
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85
Weighted Average Limited Partner Units Outstanding
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6
Cash Distributions Paid Per Unit	$	0.8420		$	0.7225		$	2.4320		$	2.0850

(a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

The accompanying notes are an integral part of these condensed combined consolidated financial statements.

September 30, 2016 | 3

FINANCIAL STATEMENTS

TESORO LOGISTICS LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2016			December 31, 2015 (a)
	(In millions, except unit amounts)
ASSETS
Current Assets
Cash and cash equivalents	$	497		$	16
Receivables, net of allowance for doubtful accounts
Trade	123			139
Affiliate	92			85
Prepayments and other current assets	31			12
Total Current Assets	743			252
Property, Plant and Equipment, Net	3,129			3,467
Acquired Intangibles, Net	955			976
Goodwill	117			130
Equity Method Investments	342			58
Other Noncurrent Assets, Net	33			26
Total Assets	$	5,319		$	4,909
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable
Trade	$	56		$	84
Affiliate	47			48
Accrued interest and financing costs	84			31
Other current liabilities	39			59
Total Current Liabilities	226			222
Debt, Net of Unamortized Issuance Costs	3,382			2,844
Other Noncurrent Liabilities	48			49
Total Liabilities	3,656			3,115
Commitments and Contingencies (Note 6)
Equity
Equity of Predecessors	—			16
Common unitholders; 102,096,039 units issued and outstanding (93,478,326 in 2015)	1,729			1,707
General partner; 2,083,330 units issued and outstanding (1,900,515 in 2015)	(66		)	(13		)
Noncontrolling interest	—			84
Total Equity	1,663			1,794
Total Liabilities and Equity	$	5,319		$	4,909

(a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

The accompanying notes are an integral part of these condensed combined consolidated financial statements.

4 | Tesoro Logistics LP

FINANCIAL STATEMENTS

TESORO LOGISITICS LP

CONDENSED STATEMENTS OF COMBINED CONSOLIDATED CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2016 (a)			2015 (a)
	(In millions)
Cash Flows From (Used In) Operating Activities:
Net earnings	$	259		$	206
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	134			133
Other non-cash operating activities	27			12
Changes in current assets and current liabilities	9			(1		)
Changes in noncurrent assets and noncurrent liabilities	(4		)	(2		)
Net cash from operating activities	425			348
Cash Flows Used In Investing Activities:
Capital expenditures	(132		)	(237		)
Acquisitions, net of cash	(30		)	—
Other investing activities	(4		)	(6		)
Net cash used in investing activities	(166		)	(243		)
Cash Flows From (Used In) Financing Activities:
Borrowings under revolving credit agreements	761			346
Repayments under revolving credit agreements	(666		)	(326		)
Proceeds from debt offering	701			—
Repayment of term loan facility	(250		)	—
Proceeds from issuance of units, net of issuance costs	364			71
Quarterly distributions to unitholders	(234		)	(173		)
Quarterly distributions to general partner	(95		)	(48		)
Distributions to noncontrolling interest	—			(20		)
Distributions in connection with acquisitions	(400		)	—
Financing costs	(17		)	—
Contributions from general partner	4			—
Sponsor contributions of equity to the Predecessors	34			19
Capital contributions by affiliate	21			18
Other financing activities	(1		)	—
Net cash from (used in) financing activities	222			(113		)
Increase (Decrease) in Cash and Cash Equivalents	481			(8		)
Cash and Cash Equivalents, Beginning of Period	16			19
Cash and Cash Equivalents, End of Period	$	497		$	11

(a) Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

The accompanying notes are an integral part of these condensed combined consolidated financial statements.

September 30, 2016 | 5

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.

PRINCIPLES OF COMBINATION AND CONSOLIDATION AND BASIS OF PRESENTATION

Acquired assets from Tesoro, and the associated liabilities and results of operations are collectively referred to as the “Predecessors.” See Note 2 for further discussion of acquisitions from Tesoro. The accompanying condensed combined consolidated financial statements and related notes present the financial position, results of operations and cash flows of our Predecessors at historical cost. The financial statements of our Predecessors have been prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as a stand-alone business. Our Predecessors did not record revenue for transactions with Tesoro and the expenses recognized were not material in the Terminalling and Transportation segment. Tesoro retained any current assets and current liabilities related to the Alaska Storage and Terminalling Assets as of the dates of the 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, 2015.

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 Predecessors, for any interim period are not necessarily indicative of results for the full year.

CONDENSED CONSOLIDATING FINANCIAL INFORMATION. The parent company of the Partnership’s operations, Tesoro Logistics LP, has no independent assets or operations. The Partnership’s operations are conducted by its 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 are no significant restrictions on the ability of the Partnership or any guarantor to obtain funds from its subsidiaries by dividend or loan. None of the assets of the Partnership or a guarantor represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.

As of September 30, 2016, Tesoro Alaska Terminals LLC, which the Partnership acquired from Tesoro as discussed further in Note 2, had not been designated as a guarantor subsidiary. No consolidating financial statements have been presented as the assets, equity and results of operations of this entity were minor in accordance with Rule 3-10(h)(6) of Regulation S-X under the Securities Act as of and for the periods ended September 30, 2016. Subsequent to the deconsolidation of Rendezvous Gas Services, L.L.C. (“RGS”) as of January 1, 2016, we are not required to provide condensed consolidating financial information pursuant to Rule 3-10 of Regulation S-X as we only have a minor consolidated non-guarantor subsidiary. For further discussion on the deconsolidation of RGS, see discussion below and in Note 4.

6 | Tesoro Logistics LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

FAIR VALUE INFORMATION

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 (less than one percent of our trade payables and approximately one percent of our trade 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 the XTO Energy Inc.’s (“XTO”) legal dispute with QEP Field Services, LLC (“QEPFS”). See further discussion regarding the XTO litigation in Note 6.

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 secured revolving credit facility (the “Revolving Credit Facility”) and our secured dropdown credit facility (“Dropdown Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were approximately $3.4 billion and $3.6 billion as of September 30, 2016, respectively. The carrying value and fair value of our debt were approximately $2.9 billion and $2.8 billion at December 31, 2015, respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against 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”), and has since amended the standard with ASU 2015-14, “Deferral of the Effective Date,” ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU 2016-10, “Identifying Performance Obligations and Licensing,” and ASU 2016-12, “Narrow-Scope Improvements and Practical Expedients.” These standards provide 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. Early adoption as of January 1, 2017 is permitted; however, we do not intend to adopt early. The standard allows for either full retrospective adoption or modified retrospective adoption. We are currently evaluating the impact of the standard on our financial statements and related disclosures. Based on our initial evaluation, the adoption of the standard is not expected to have a material impact on the amount or timing of revenue recognized.

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. We adopted this guidance using the modified retrospective approach as of January 1, 2016 and performed the required reassessments outlined by the guidance. For further information on the results of the reassessments, refer to Note 4, Investments - Equity Method and Joint Ventures.

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 December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. We adopted this guidance as of January 1, 2016, with no impact to our financial statements.

LEASES.In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”), which improves transparency and comparability among organizations by requiring lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires 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.

September 30, 2016 | 7

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

SHARE-BASED COMPENSATION. In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”), which simplifies several aspects of the accounting for employee share-based payment transactions including accounting for income taxes, cash flow presentation of tax impacts, forfeitures, and liability versus equity accounting due to statutory tax withholding requirements. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. As of January 1, 2016, we early adopted ASU 2016-09 and with respect to the guidance on forfeitures, we have elected to continue to estimate forfeitures on the date of grant to account for the estimated number of awards for which the requisite service period will not be rendered. The adoption of ASU 2016-09 had no impact on our financial statements.

STATEMENT OF CASH FLOWS. In August 2016, the FASB issued ASU 2016-15, “Clarification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”), which eliminates the diversity in practice related to the classification of certain cash receipts and payments in the statement of cash flows, by adding or clarifying guidance on eight specific cash flow issues. ASU 2016-15 is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. The amendments in this update should be applied retrospectively to all periods presented, unless deemed impracticable, in which case, prospective application is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements.

NOTE 2 – RELATED-PARTY TRANSACTIONS

ACQUISITIONS

ALASKA STORAGE AND TERMINALLING ASSETS PURCHASE.  Effective July 1, 2016, the Partnership entered into an agreement to purchase certain terminalling and storage assets owned by Tesoro for total consideration of $444 million and was completed in two phases. On July 1, 2016, the Partnership completed the acquisition of the first phase consisting of tankage with a shell capacity of approximately 3.5 million barrels, related equipment and ancillary facilities used for the operations at Tesoro’s Kenai Refinery. The second phase was completed on September 16, 2016 and consisted of refined product terminals in Anchorage and Fairbanks (together, the “Alaska Storage and Terminalling Assets”). Consideration paid for the first phase was $266 million, comprised of approximately $240 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $26 million. Consideration paid for the second phase was $178 million, comprised of approximately $160 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $18 million.

AFFILIATE AGREEMENTS

The Partnership has various long-term, fee-based commercial agreements with Tesoro, under which we provide pipeline transportation, trucking, terminal distribution and storage services to Tesoro, and Tesoro typically commits to fixed fees or to provide us with minimum monthly throughput volumes of crude oil and refined products. For the natural gas liquids 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.

In addition, we have agreements for the provision of various general and administrative services by Tesoro. Under our partnership agreement, we are required to reimburse TLGP and its affiliates for all costs and expenses that they incur on our behalf for managing and controlling our business and operations. Except to the extent specified under our amended omnibus agreement (the “Amended Omnibus Agreement”) or our secondment agreement (the “Secondment Agreement”), TLGP determines the amount of these expenses. The Amended Omnibus Agreement and the Secondment Agreement were amended and restated in connection with the Alaska Storage and Terminalling Assets purchase. Under the terms of the Amended Omnibus Agreement as of September 30, 2016, we are required to pay Tesoro an annual corporate services fee of $10 million for the provision of various centralized corporate services, including executive management, legal, accounting, treasury, human resources, health, safety and environmental, information technology, certain insurance coverage, administration and other corporate services. Under the terms of our Secondment Agreement as of September 30, 2016, we pay Tesoro a net annual service fee of $2 millionfor services performed by field-level employees at the majority of our facilities. Additionally, pursuant to the Amended Omnibus Agreement and Secondment Agreement, we reimburse Tesoro for any direct costs actually incurred by Tesoro in providing other operational services with respect to certain of our other assets and operations.

8 | Tesoro Logistics LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

SUMMARY OF AFFILIATE TRANSACTIONS

SUMMARY OF REVENUE AND EXPENSE TRANSACTIONS WITH TESORO (in millions)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues (a)	$	184	$	152	$	521	$	454
Operating expenses	40		33		113		93
Imbalance settlement gains and reimbursements from Tesoro (b)	5		12		17		31
General and administrative expenses	18		16		51		51

(a) Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

(b) Includes imbalance settlement gains of $2 million and for both the three months ended September 30, 2016 and 2015, and $5 million and $6 million for the nine months ended September 30, 2016 and 2015, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $3 million and $10 million for the three months ended September 30, 2016 and 2015, respectively, and $12 million and $25 million for the nine months ended September 30, 2016 and 2015, respectively.

PREDECESSOR TRANSACTIONS. Related-party transactions of our Predecessors were settled through equity. Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment.

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. During the nine months ended September 30, 2016, we paid quarterly cash distributions of $175 million to Tesoro and TLGP, including incentive distribution rights (“IDRs”). On October 18, 2016, we declared a quarterly cash distribution of $0.875 per unit, which will be paid on November 14, 2016. The distribution will include payments of $71 million to Tesoro and TLGP, including IDRs.

NOTE 3 – PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT BY SEGMENT, AT COST (in millions)

	September 30, 2016			December 31, 2015
Gathering (a)	$	1,379		$	1,700
Processing	573			565
Terminalling and Transportation (b)	1,690			1,629
Property, Plant and Equipment, at Cost	3,642			3,894
Accumulated depreciation (a) (b)	(513		)	(427		)
Property, Plant and Equipment, Net	$	3,129		$	3,467

(a) We recognized a decrease of $363 million to net property, plant and equipment as of January 1, 2016 as a result of the deconsolidation of RGS. See Note 4 for further discussion of the deconsolidation of RGS.

(b) Property, plant and equipment transferred to the Partnership in the Alaska Storage and Terminalling Assets acquisition was recorded at historical costs. TLLP recorded property, plant and equipment of $77 million and $47 million as of September 30, 2016 and December 31, 2015, respectively, and accumulated depreciation of $30 million for both September 30, 2016 and December 31, 2015.

September 30, 2016 | 9

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

NOTE 4 – INVESTMENTS - EQUITY METHOD AND JOINT VENTURES

For each of the following investments, we have the ability to exercise significant influence over each of these investments through our participation in the management committees, which make all significant decisions. However, since we have equal or proportionate influence over each committee as a joint interest partner and all significant decisions require consent of the other investor(s) without regard to our economic interest, we have determined that these entities should not be consolidated and apply the equity method of accounting with respect to our investments in each entity.

• RGS. We have a 78% interest in RGS, which owns and operates the infrastructure that transports gas from certain fields to several re-delivery points in southwestern Wyoming, including natural gas processing facilities that are owned by us or a third party. Prior to 2016, we consolidated RGS, however, upon our reassessment performed in conjunction with the adoption of ASU 2015-02 as of January 1, 2016, we determined RGS represents a variable interest entity to us for which we are not the primary beneficiary. Under the limited liability company agreement, we do not have voting rights commensurate with our economic interest due to veto rights available to our partner in RGS. Certain business decisions, including, but not limited to, decisions with respect to significant expenditures or contractual commitments, annual budgets, material financings, dispositions of assets or amending the members’ gas servicing agreements, require unanimous approval of the members. For amounts previously consolidated in our financial statements as of and for the year ended December 31, 2015, refer to the amounts shown in the Non-Guarantor column in the condensed consolidating financial information presented in Note 16 in our annual report on Form 10-K referenced herein.

• THREE RIVERS GATHERING, LLC (“TRG”). We own a 50% interest in TRG which operates natural gas gathering assets within the southeastern Uinta Basin and is primarily supported by long-term, fee-based gas gathering agreements with minimum volume commitments.

• UINTAH BASIN FIELD SERVICES, L.L.C. (“UBFS”). We own a 38% interest in UBFS which owns and operates the natural gas gathering infrastructure located in the southeastern Uinta Basin and is supported by long-term, fee-based gas gathering agreements that contain firm throughput commitments, which generate fees whether or not the capacity is used, and is operated by us.

EQUITY METHOD INVESTMENTS (in millions)

	RGS			TRG			UBFS			Total
Balance at December 31, 2015	$	—		$	42		$	16		$	58
Effect of deconsolidation (a)	295			—			—			295
Equity in earnings	6			2			2			10
Distributions received	(16		)	(3		)	(2		)	(21		)
Balance at September 30, 2016	$	285		$	41		$	16		$	342

(a) We recognized an increase of $295 million to equity method investments as of January 1, 2016 as a result of the deconsolidation of RGS in addition to a cumulative effect reduction to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods. The carrying amount of our investment in RGS exceeded the underlying equity in net assets by $137 million at September 30, 2016.

NOTE 5 – DEBT

DEBT BALANCE, NET OF UNAMORTIZED ISSUANCE COSTS (in millions)

	September 30, 2016			December 31, 2015
Total debt	$	3,428		$	2,883
Unamortized issuance costs (a)	(46		)	(39		)
Debt, Net of Unamortized Issuance Costs	$	3,382		$	2,844

(a) Includes unamortized premiums of $4 million associated with our senior notes at both September 30, 2016 and December 31, 2015.

10 | Tesoro Logistics LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

REVOLVING CREDIT FACILITY AND DROPDOWN CREDIT FACILITY

AVAILABLE CAPACITY UNDER CREDIT FACILITIES (in millions)

	Total Capacity		Amount Borrowed as of September 30, 2016		Outstanding Letters of Credit		Available Capacity		Expiration
TLLP Revolving Credit Facility	$	600	$	—	$	—	$	600	January 29, 2021
TLLP Dropdown Credit Facility	1,000		400		—		600		January 29, 2021
Total Credit Facilities	$	1,600	$	400	$	—	$	1,200

We amended our existing secured Revolving Credit Facility on January 29, 2016, decreasing the aggregate available facility limit from $900 million to $600 million and revised terms related to pricing and financial covenants. As a result of this amendment, an immaterial amount of unamortized debt issuance costs were expensed. In addition, we syndicated a $1.0 billion secured Dropdown Credit Facility on January 29, 2016. The primary use of proceeds under this facility will be to fund asset acquisitions. The terms, covenants and restrictions under this facility are substantially the same as with our amended secured Revolving Credit Facility. The total aggregate available facility limits for the secured Revolving Credit Facility and secured Dropdown Credit Facility totaled$1.6 billion at September 30, 2016. We are allowed to request the loan availability for both the secured Revolving Credit Facility and the secured Dropdown Credit Facility be increased up to an aggregate of $2.1 billion, subject to receiving increased commitments from the lenders.

As of September 30, 2016, our secured Revolving Credit Facility provided for total loan availability of $600 million. Borrowings are available under the secured Revolving Credit Facility up to the total loan availability of the facility. Our secured Revolving Credit Facility is non-recourse to Tesoro, except for TLGP, and is guaranteed by all of our consolidated subsidiaries, and secured by substantially all of our assets. We hadno borrowings outstanding under the secured Revolving Credit Facility, resulting in the full loan availability of the borrowing capacity as of September 30, 2016.

As of September 30, 2016, our secured Dropdown Credit Facility provided for total loan availability of $1.0 billion. We had $400 million borrowings outstanding under the secured Dropdown Credit Facility, resulting in unused loan availability of $600 million or 60% the borrowing capacity as of September 30, 2016. The weighted average interest rate for borrowings under our secured Dropdown Credit Facility was 2.54% at September 30, 2016.

The secured Revolving Credit Facility and the secured Dropdown Credit Facility ratably share collateral comprised primarily of our property, plant, and equipment and both facilities mature on January 29, 2021. In addition, upon an upgrade of our corporate family rating to investment grade from either Moody's Investors Service or S&P Global Ratings, certain covenants and restrictions under each facility will automatically be eliminated or improved.

SENIOR NOTES ISSUANCE

On May 9, 2016, we completed a registered offering of $250 million aggregate principal amount of 6.125% Senior Notes due 2021 (“2021 Notes”) and $450 million aggregate principal amount of 6.375% Senior Notes due 2024 (“2024 Notes”). We used the proceeds of the offering of the 2021 notes to repay amounts outstanding under our Dropdown Credit Facility and the proceeds of the offering of the 2024 notes to repay amounts outstanding under our Revolving Credit Facility and for general partnership purposes.

The 2021 Notes were issued under the same indenture governing the existing $550 million of the 6.125% Senior Notes due 2021 issued in August 2013 and have the same terms as those senior notes. The 2021 Notes have no sinking fund requirements. The 2021 Notes may be redeemed at premiums equal to 4.594% through October 15, 2017; 3.063% from October 15, 2017 through October 15, 2018; 1.531% from October 15, 2018 through October 15, 2019; and at par thereafter, plus accrued and unpaid interest. The 2021 Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

The 2024 Notes have no sinking fund requirements. We may redeem some or all of the 2024 Notes, prior to May 1, 2019, at a make-whole price plus accrued and unpaid interest, if any. On or after May 1, 2019, the 2024 Notes may be redeemed at premiums equal to  4.781% through May 1, 2020; 3.188% from May 1, 2020 through May 1, 2021; 1.594% from May 1, 2021

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NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

through May 1, 2022; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 106.375% face value with proceeds from certain equity issuances through May 1, 2019. The 2024 Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

DEBT REPAYMENTS

On February 3, 2016, we paid the full amount of the Unsecured Term Loan Facility, including accrued interest, with proceeds drawn from the secured Dropdown Credit Facility. All commitments under the Unsecured Term Loan Facility were terminated effective with the repayment and an immaterial amount of unamortized debt issuance costs were expensed.

SENIOR NOTES EXCHANGE

On February 26, 2016, the Partnership commenced an offer to exchange (the “Exchange”) its existing unregistered 5.50% Senior Notes due 2019 (“2019 Notes”) and 6.25% Senior Notes due 2022 (“2022 Notes”) (together, “Unregistered Notes”) for an equal principal amount of 5.50% Senior Notes due 2019 and 6.25% Senior Notes due 2022 (the “Exchange Notes”), respectively, that were registered under the Securities Act of 1933, as amended. On April 14, 2016, the Exchange was completed for all of the 2019 Notes and substantially all of the 2022 Notes. The terms of the Exchange Notes are identical in all material respects (including principal amount, interest rate, maturity and redemption rights) to the Unregistered Notes for which they were exchanged, except that the Exchange Notes generally are not subject to transfer restrictions. The Exchange fulfills all of the requirements of the registration rights agreements for the Unregistered Notes.

NOTE 6 – COMMITMENTS AND CONTINGENCIES

TESORO INDEMNIFICATION

Under the Amended Omnibus Agreement, Tesoro indemnifies us for certain matters, including known 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, 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. Environmental matters discovered subsequent to the Initial Offering and subsequent acquisitions are also indemnified to the extent they are identified prior to five years from the acquisition date. The indemnification under the Initial Offering for unknown environmental matters expired on April 26, 2016. See Note 3 of our Annual Report on Form 10-K for the year ended December 31, 2015, 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 contingencies cannot always be predicted accurately, but we will accrue liabilities for these matters if the amount is probable and can be reasonably estimated. Contingencies arising after the closing of the Initial Offering from conditions existing before the Initial Offering, and the subsequent acquisitions from Tesoro that have been identified after the closing of each transaction, will be recorded in accordance with the indemnification terms set forth in the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement, as noted above. Any contingencies arising from events after the Initial Offering, and the subsequent acquisitions from Tesoro, will be our responsibility. Other than described in this Note 6, we do not have any other material outstanding lawsuits, administrative proceedings or governmental investigations.

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NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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 liabilities for these environmental expenditures totaled $18 million and $33 million at September 30, 2016 and December 31, 2015, 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. 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, we have received all insurance recoveries related to the Crude Oil Pipeline Release as of December 31, 2015. The estimated remediation costs of $66 million exceeded our policy loss limit by $41 million. We had remaining liabilities totaling $13 million and $27 million at September 30, 2016 and December 31, 2015, respectively.

LEGAL

QUESTAR GAS COMPANY V. QEP FIELD SERVICES COMPANY. Prior to the acquisition of all of the limited liability company interests of QEPFS, 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 agreed to indemnify QEP Field Services Company for this claim under the acquisition agreement for QEPFS. Under the 1993 Agreement, certain of TLLP’s systems provide gathering services to QGC charging an annual gathering rate, which is based on the cost of service calculation. QGC disputed the annual calculation of the gathering rate, which has been calculated in the same manner since 1998, without objection by QGC. As a result of the rulings through the date of our acquisition of QEPFS, TLLP assumed a $21 million liability for estimated damages. On March 22, 2016, the parties in this dispute entered into a settlement and release agreement resolving all remaining issues and associated counter claims in exchange for TLLP’s payment of $15 million. We recognized a gain of $6 million in other income, net on our condensed statement of consolidated operations for the nine months ended September 30, 2016 as a result of the settlement.

XTO ENERGY INC. V. QEP FIELD SERVICES COMPANY.XTO filed a complaint on January 30, 2014, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, unjust enrichment and an accounting and declaratory judgment related to a 2010 gas processing agreement (the “XTO Agreement”). TLLP processes XTO’s natural gas on a firm basis under the XTO Agreement. The XTO Agreement requires TLLP to transport, fractionate and market XTO’s natural gas liquids derived from XTO’s processed gas. XTO is seeking monetary damages related to TLLP’s 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. On March 29, 2016, the parties entered into a settlement and release agreement related to payments withheld by XTO unrelated to the allocation of charges they are challenging. Under the settlement and release agreement, XTO agreed to pay all historical undisputed charges by April 15, 2016 less the allocated charges they are challenging, $29 million at September 30, 2016, and to thereafter tender all similar undisputed charges timely. On April 15, 2016, XTO remitted a $21 million settlement payment related to all undisputed amounts. While we cannot currently estimate the final amount or timing of the resolution of this matter and the disputed amounts, we believe the outcome will not have a material impact on our liquidity, financial position or results of operations.

NOTE 7 – EQUITY AND NET EARNINGS PER UNIT

We had 68,901,930 common public units outstanding as of September 30, 2016. Additionally, Tesoro owned 33,194,109 of our common units and 2,083,330 of our general partner units (the 2.0% general partner interest) as of September 30, 2016, which together constitutes a 34% ownership interest.

UNIT ISSUANCE.We closed a registered public offering of 6,325,000 common units representing limited partner interests, including the over-allotment option exercised by the underwriter for the purchase of an additional 825,000 common units, at a public offering price of $47.13 per unit on June 10, 2016. The net proceeds of $293 million are expected to be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

September 30, 2016 | 13

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

ATM PROGRAM.On August 24, 2015, we filed a prospectus supplement to our shelf registration statement filed with the SEC 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 “ATM Program”). During the three and nine months ended September 30, 2016, we issued an aggregate of 655,940 and 1,492,637 common units, respectively, under our ATM Program, generating proceeds of approximately $31 million and $72 million, respectively, before issuance costs. The net proceeds from sales under the ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

CHANGE IN THE CARRYING AMOUNT OF OUR EQUITY (in millions)

				Partnership
	Equity of Predecessors (a)			Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2015	$	16		$	1,707		$	(13	)	$	84		$	1,794
Sponsor contributions of equity to the Predecessors	34			—			—			—			34
Loss attributable to the Predecessors	(4		)	—			—			—			(4		)
Allocation of net assets acquired by the unitholders (b)	(46		)	40			6			—			—
Equity offering under ATM Program, net of issuance costs	—			71			—			—			71
Proceeds from issuance of units, net of issuance costs	—			293			—			—			293
Effect of deconsolidation of RGS (c)	—			(2		)	—			(84		)	(86		)
Quarterly distributions to unitholders and general partner(d)	—			(234		)	(95		)	—			(329		)
Distributions to unitholders and general partner related to acquisitions (b)	—			(321		)	(79		)	—			(400		)
Net earnings attributable to partners	—			154			109			—			263
Contributions (e)	—			17			2			—			19
Other	—			4			4			—			8
Balance at September 30, 2016	$	—		$	1,729		$	(66	)	$	—		$	1,663

(a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

(b) Distributions to unitholders and general partner include $400 million in cash payments for the Alaska Storage and Terminalling Assets acquisition from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesoro’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net decrease of $354 million in our equity balance during the nine months ended September 30, 2016.

(c) As a result of the reassessment performed, we deconsolidated RGS causing the derecognition of noncontrolling interest and an opening equity impact totaling $86 million. The cumulative effect to opening equity of$2 million related to the difference in earnings under the equity method of accounting in prior periods.

(d) Represents cash distributions declared and paid during the nine months ended September 30, 2016 relating to the fourth quarter of 2015 through the second quarter of 2016.

(e) 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.

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, 2016, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the common 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 limited partner units outstanding during the period.

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NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

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. Distributions less than or greater than earnings are allocated in accordance with our partnership agreement.

NET EARNINGS PER UNIT (in millions, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Net earnings	$	87		$	71		$	259		$	206
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Special allocations of net earnings (“Special Allocations”) (a)	2			—			2			—
Net earnings, excluding noncontrolling interest and including Special Allocations	89			68			261			187
General partner’s distributions	(3		)	(1		)	(7		)	(4		)
General partner’s IDRs (b)	(39		)	(19		)	(105		)	(47		)
Limited partners’ distributions on common units	(89		)	(66		)	(250		)	(186		)
Distributions greater than earnings	$	(42	)	$	(18	)	$	(101	)	$	(50	)
General partner’s earnings:
Distributions	$	3		$	1		$	7		$	4
General partner’s IDRs (b)	39			19			105			47
Allocation of distributions greater than earnings (c)	(2		)	(6		)	(6		)	(17		)
Total general partner’s earnings	$	40		$	14		$	106		$	34
Limited partners’ earnings on common units:
Distributions	$	89		$	66		$	250		$	186
Special Allocations (a)	(2		)	—			(2		)	—
Allocation of distributions greater than earnings	(40		)	(12		)	(95		)	(33		)
Total limited partners’ earnings on common units	$	47		$	54		$	153		$	153
Weighted average limited partner units outstanding:
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6
Net earnings per limited partner unit:
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85

(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 common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the Alaska Storage and Terminalling Assets acquisition during the three and nine months ended September 30, 2016.

(b) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $3 million and $8 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2015, for further discussion related to IDRs.

(c) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $1 million and$4 million for the three and nine months ended September 30, 2016, respectively, and $6 million and$17 million for the three and nine months ended September 30, 2015, respectively.

September 30, 2016 | 15

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

QUARTERLY DISTRIBUTIONS

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2015	$	0.780	$	98	February 12, 2016	February 2, 2016
March 31, 2016	0.810		108		May 13, 2016	May 2, 2016
June 30, 2016	0.842		123		August 12, 2016	August 2, 2016
September 30, 2016 (a)	0.875		131		November 14, 2016	November 4, 2016

(a) This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

NOTE 8 – OPERATING SEGMENTS

Our revenues are derived from three operating segments: Gathering, Processing and Terminalling and Transportation. Our Gathering segment consists of crude oil and natural gas gathering systems in the Bakken Shale/Williston Basin area of North Dakota and Montana and the Green River Basin, Uinta Basin and Vermillion Basin in the states of Utah, Colorado and Wyoming. Our Processing segment consists of four gas processing complexes and one fractionation facility. Our Terminalling and Transportation segment consists of crude oil and refined products terminals and marine terminals, storage facilities for crude oil, refined products and petroleum coke handling, rail-car unloading facilities and pipelines, which transport products and crude oil.

Our revenues are generated from third-party contracts and from commercial agreements we have entered into with Tesoro, under which customers pay 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, 2015. 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 are excluded from segment operating income as they are not directly attributable to a specific operating segment.

16 | Tesoro Logistics LP

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

SEGMENT INFORMATION (in millions)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Revenues
Gathering:
Affiliate	$	21		$	18		$	61		$	71
Third-party	61			69			194			182
Total Gathering	82			87			255			253
Processing:
Affiliate	23			26			74			71
Third-party	46			45			134			134
Total Processing	69			71			208			205
Terminalling and Transportation:
Affiliate	140			108			386			312
Third-party	17			16			52			50
Total Terminalling and Transportation	157			124			438			362
Total Segment Revenues	$	308		$	282		$	901		$	820
Segment Operating Income
Gathering	$	31		$	42		$	107		$	121
Processing	29			29			85			77
Terminalling and Transportation	85			51			226			157
Total Segment Operating Income	145			122			418			355
Unallocated general and administrative expenses	(12		)	(16		)	(37		)	(43		)
Interest and financing costs, net	(49		)	(37		)	(138		)	(112		)
Equity in earnings of equity method investments	3			2			10			6
Other income, net	—			—			6			—
Net Earnings	$	87		$	71		$	259		$	206
Capital Expenditures
Gathering	$	21		$	72		$	67		$	177
Processing	2			5			15			10
Terminalling and Transportation	19			16			43			50
Total Capital Expenditures	$	42		$	93		$	125		$	237

September 30, 2016 | 17

MANAGEMENT’S DISCUSSION AND ANALYSIS

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. Unless the context otherwise requires, references in this report to “Tesoro” refer collectively to Tesoro Corporation and any of its subsidiaries, other than TLLP, its subsidiaries and its general partner. Unless the context otherwise requires, references in this report to “Predecessors” refer collectively to the acquired assets from Tesoro, and those assets, liabilities and results of operations.

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, 2015.

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 a network of crude oil, refined products and natural gas pipelines. We also own and operate crude oil and refined products truck terminals, marine terminals and dedicated storage facilities. In addition, we own and operate natural gas processing and fractionation complexes. We are a fee-based, growth oriented Delaware limited partnership formed by Tesoro Corporation and are headquartered in San Antonio, Texas. 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, 2016, approximately 60% and 58%, respectively, of our total revenues were derived from Tesoro under various long-term, fee-based commercial agreements, the majority of which include minimum volume commitments.

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 direct 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.

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.

We have been implementing our strategy and goals discussed above, allowing us to increase our distributions by 17% over the last year.

18 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

Relative to these goals, in 2016, we intend to continue implementing this strategy and have completed or announced plans to:

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

◦ further expanding crude oil storage and transportation 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

◦ pursuing strategic assets across the Western U.S. including potential acquisitions from Tesoro.

• expand and optimize our natural gas gathering and processing assets located in the Green River Basin, Uinta Basin and Vermillion Basin in the states of Utah, Colorado and Wyoming (the “Rockies Region”) including:

◦ increasing compression on our systems in the Green River and Vermillion basins to enhance natural gas volumes recovered from existing wells and support potential new drilling activity; and

◦ expanding our gathering footprint and increase compression capabilities in the Uinta basin to increase volumes on our gathering systems and through our processing assets.

• grow our terminalling and transportation business across the Western U.S. through:

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

◦ optimizing Tesoro volumes and growing third-party throughput at our terminalling and transportation assets; and

◦ pursuing strategic assets in the Western U.S. such as our acquisition of Tesoro's terminalling assets and storage assets in Alaska.

ACQUISITIONS

ALASKA STORAGE AND TERMINALLING ASSETS PURCHASE.  Effective July 1, 2016, the Partnership entered into an agreement to purchase certain terminalling and storage assets owned by Tesoro for total consideration of $444 million and was completed in two phases. On July 1, 2016, the Partnership completed the acquisition of the first phase consisting of tankage with a shell capacity of approximately 3.5 million barrels and ancillary facilities used for the operations at Tesoro’s Kenai Refinery. The second phase was completed on September 16, 2016 and consisted of refined product terminals in Anchorage and Fairbanks (together, the “Alaska Storage and Terminalling Assets”). Consideration paid for the first phase was $266 million, comprised of approximately $240 million in cash, financed with borrowings under our secured dropdown credit facility (“Dropdown Credit Facility”), and the issuance of equity to Tesoro with a fair value of $26 million. Consideration paid for the second phase was $178 million, comprised of approximately $160 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $18 million.

CURRENT MARKET CONDITIONS

During the third quarter, the spot prices of the commodities that we handle were relatively stable, including crude oil, natural gas liquids and refined products, while natural gas increased. U.S. crude stocks declined over the quarter, although globally, inventories remained high. The U.S. rig count increased in the third quarter after consecutive periods of declines. Additionally, improved drilling techniques and better well management have increased production per well and many producers have a back-log of uncompleted wells, which are available for completion. These factors could positively impact overall U.S. production volumes, however, regional impacts may differ.

Low retail prices, seasonal trends and healthy economic conditions over the third quarter continued to support increased demand for refined products. We continue to see a limited impact to our business from the lifting of the crude export ban and expect minimal impact on our business in the short term. We continue to monitor the impact of these changes in market prices and fundamentals on our business in the western U.S. We believe our diversified portfolio, which is underpinned by long-term contracts, many of which are supported by minimum volume commitments, adequately supports our goals and objectives outlined above.

September 30, 2016 | 19

MANAGEMENT’S DISCUSSION AND ANALYSIS

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 for all periods presented. The financial statements of our Predecessors were prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. 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 future performance.

NON-GAAP MEASURES

As a supplement to our financial information presented in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”), our management uses certain “non-GAAP” measures to analyze our results of operations, assess internal performance against budgeted and forecasted amounts and evaluate future impacts to our financial performance as a result of capital investments, acquisitions, divestitures and other strategic projects.

During the second quarter of 2016, management revised its internal and external use of non-GAAP measures to eliminate any adjustments to U.S. GAAP net earnings and earnings before interest, income taxes, and depreciation and amortization expenses (“EBITDA”) for items previously considered “special items” and loss attributable to our Predecessors. We believe our revised presentation of net earnings and EBITDA and descriptions of significant activities impacting U.S. GAAP net earnings are sufficient to convey our financial performance to the users of our financial statements.

Additionally, we revised our definition of Distributable Cash Flow to include the reconciliation of this non-GAAP measure to be from U.S. GAAP net cash from operating activities rather than net earnings. We believe this method of reconciliation is more appropriate based on our determination that Distributable Cash Flow provides a measure by which users of our financial statements can assess our ability to generate cash and thus additional liquidity.

Following these changes, our non-GAAP measures include the following:

• Financial non-GAAP measure of EBITDA, as defined above; and

• Liquidity non-GAAP measures:

◦ Distributable Cash Flow is derived from net cash flow from operating activities plus or minus changes in working capital, amounts spent on maintenance capital net of reimbursements and other adjustments not expected to settle in cash; and

◦ Pro Forma Distributable Cash Flow is Distributable Cash Flow plus or minus adjustments for the acquisition of noncontrolling interest in connection with the merger of QEP Midstream Partners, LP (“QEPM”) into TLLP completed in July 2015.

We present the performance and liquidity measures defined above because we believe these measures help us analyze our results of operations and liquidity in conjunction with our U.S. GAAP results. Investors, analysts, lenders and ratings agencies may use these measures to help analyze our results of operations and liquidity in conjunction with our U.S. GAAP results, including but not limited to the following:

• 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.

In addition, these measures are used by management to assess internal performance. We believe these measures, when supplemental to information presented under U.S. GAAP, may provide meaningful information to the users of our financial statements. Each of the performance and liquidity measures should not be used in isolation from their comparable U.S. GAAP measure and thus should not be considered as alternatives to any U.S. GAAP measure. Non-GAAP measures have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings, operating income and net cash from operating activities.

20 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

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 Million British thermal units (“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).

ITEMS IMPACTING COMPARABILITY

Our financial results may not be comparable for the reasons described below. Our Predecessors did not record revenues with Tesoro and our Predecessors recorded 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, 2015 for further discussion.

On November 12, 2015, the Partnership purchased crude oil and refined product storage and pipeline assets in Los Angeles, California (the "LA Storage and Handling Assets") owned by subsidiaries of Tesoro Corporation for a total consideration of $500 million. The Partnership acquired 97 crude oil, feedstock, and refined product storage tanks with combined capacity of 6.6 million barrels and a 50% interest in a 16-mile pipeline that transports jet fuel from Tesoro’s Los Angeles refinery to the Los Angeles International Airport. The acquisition price of $500 million included cash of approximately $250 million and the issuance of common and general partner units to Tesoro, valued at approximately $250 million.

On July 1 and September 16, 2016, the Partnership purchased the Alaska Storage and Terminalling Assets owned by Tesoro for total consideration of $444 million. The storage assets include tankage with a shell capacity of approximately 3.5 million barrels and ancillary facilities used for the operations at Tesoro’s Kenai Refinery. The refined product terminals are located in Anchorage and Fairbanks.

We have a 78% interest in Rendezvous Gas Services, L.L.C. (“RGS”), which owns and operates the infrastructure that transports gas from certain fields to several re-delivery points in southwestern Wyoming, including natural gas processing facilities that are owned by us or a third party. Prior to 2016, we consolidated RGS; however, upon performing the required reassessments in conjunction with our adoption of ASU 2015-02 as of January 1, 2016, we determined RGS represents a variable interest entity to us for which we are not the primary beneficiary resulting in the deconsolidation of RGS and the reporting of RGS as an equity method investment. We recognized an increase of $295 million to equity method investments as of January 1, 2016 as a result of the deconsolidation in addition to a cumulative effect reduction to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods.

The following table and discussion is a summary of our results of operations for the three and nine months ended September 30, 2016 and 2015, including a reconciliation of EBITDA to net earnings and Distributable Cash Flow to cash flow from operating activities (in millions, except per unit amounts).

September 30, 2016 | 21

MANAGEMENT’S DISCUSSION AND ANALYSIS

CONSOLIDATED RESULTS

SUMMARY (In millions, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016 (a)			2015 (a)			2016 (a)			2015 (a)
Revenues
Gathering	$	82		$	87		$	255		$	253
Processing	69			71			208			205
Terminalling and Transportation (b)	157			124			438			362
Total Revenues	308			282			901			820
Costs and Expenses
Operating expenses (c)	104			103			313			294
General and administrative expenses	24			28			70			81
Depreciation and amortization expenses	45			45			134			133
Loss on asset disposals and impairments	2			—			3			—
Operating Income	133			106			381			312
Interest and financing costs, net	(49		)	(37		)	(138		)	(112		)
Equity in earnings of equity method investments	3			2			10			6
Other income, net	—			—			6			—
Net Earnings	$	87		$	71		$	259		$	206
Loss attributable to Predecessors	$	1		$	6		$	4		$	17
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Net Earnings Attributable to Partners	88			74			263			204
General partner’s interest in net earnings, including incentive distribution rights	(40		)	(20		)	(108		)	(51		)
Limited Partners’ Interest in Net Earnings	$	48		$	54		$	155		$	153
Net Earnings per Limited Partner Unit
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85
Weighted Average Limited Partner Units Outstanding
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6

(a) Adjusted to include the historical results of the Predecessors.

(b) Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment for assets acquired in the acquisitions from Tesoro prior to the effective date of each acquisition.

(c) Operating expenses include net imbalance settlement gains of $2 millionfor the three months ended September 30, 2016, and $5 million and $4 million for the nine months ended September 30, 2016 and 2015, respectively. There were no net imbalance settlement gains or losses for the three months ended September 30, 2015. Also includes reimbursements from Tesoro primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement of $3 million and $10 million for the three months ended September 30, 2016 and 2015, respectively, and $12 million and $25 million for the nine months ended September 30, 2016 and 2015, respectively.

22 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016 (a)			2015 (a)			2016 (a)			2015 (a)
Reconciliation of Net Earnings to EBITDA:
Net earnings	$	87		$	71		$	259		$	206
Depreciation and amortization expenses	45			45			134			133
Interest and financing costs, net of capitalized interest	49			37			138			112
EBITDA	$	181		$	153		$	531		$	451
Reconciliation of Net Cash from Operating Activities to Distributable Cash Flow and Pro Forma Distributable Cash Flow:
Net cash from operating activities (b)	$	176		$	137		$	425		$	348
Changes in assets and liabilities	(37		)	(18		)	(5		)	3
Predecessors impact	1			4			3			17
Maintenance capital expenditures (c)	(20		)	(12		)	(44		)	(37		)
Reimbursement for maintenance capital expenditures (c)	6			1			20			4
Net earnings attributable to noncontrolling interest (d)	—			(1		)	—			(17		)
Other adjustments for noncontrolling interest (d)	—			—			—			(20		)
Adjustments for equity method investments (e)	4			—			1			(1		)
Other (f)	3			4			1			19
Distributable Cash Flow	133			115			401			316
Pro forma adjustment for acquisition of noncontrolling interest (g)	—			—			—			36
Pro Forma Distributable Cash Flow	$	133		$	115		$	401		$	352

(a) Adjusted to include the historical results of the Predecessors.

(b) During the second quarter of 2016, we revised our reconciliation of distributable cash flow and pro forma distributable cash flow by reconciling the liquidity measure from net cash from operating activities. There were no impacts to previously reported amounts as a result of this methodology change.

(c) We adjust our reconciliation of distributable cash flows for maintenance capital expenditures, tank restoration costs and expenditures required to ensure the safety, reliability, integrity and regulatory compliance of our assets with an offset for any reimbursements received for such expenditures.

(d) Prior to 2016 for noncontrolling interests associated with QEPM and RGS, we excluded $2 million of undistributed earnings along with other adjustments to reflect gross cash available for distribution net of noncontrolling interest impacts.

(e) We adjust net cash from operating activities to reflect cash distributions received from equity method investments attributed to the period reported for the purposes of calculating distributable cash flow.

(f) Other includes items that had a non-cash impact on our operations and should not be considered in distributable cash flow. Non-cash items for the nine months ended September 30, 2016 and 2015 include primarily the exclusion of the non-cash gain of$6 million recognized relating the settlement of the Questar Gas Company litigation as discussed in Note 6 to our condensed combined consolidated financial statements and the inclusion of $13 million for acquired deficiency revenue billings to customers in 2015.

(g) Reflects the adjustment to include the noncontrolling interest in QEPM as controlling interest based on the pro forma assumption that the merger of QEPM with TLLP occurred on January 1, 2015.

THREE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS THREE MONTHS ENDED SEPTEMBER 30, 2015

OVERVIEW.Our net earnings for the three months ended September 30, 2016 (“2016 Quarter”) increased$16 million to $87 million from $71 million for the three months ended September 30, 2015 (“2015 Quarter”) primarily driven by increases in revenue partially offset by an increase to interest and financing costs, net.

REVENUES.The increase in revenue of $26 million, or 9%, to $308 million was driven primarily by the LA Storage and Handling Assets purchased from Tesoro in November 2015 and the Alaska Storage and Terminalling Assets purchased in July 2016 partially offset by declines in natural gas production leading to reduced volumes on our gathering system.

September 30, 2016 | 23

MANAGEMENT’S DISCUSSION AND ANALYSIS

GENERAL AND ADMINISTRATIVE EXPENSES.General and administrative expenses decreased$4 million to $24 million in the 2016 Quarter compared to the 2015 Quarter primarily due to higher costs in 2015 due to integration efforts in connection with the acquisition of all of the limited liability company interests of QEP Field Services, LLC (“QEPFS”).

INTEREST AND FINANCING COSTS, NET.Net interest and financing costs increased$12 million in the 2016 Quarter compared to the 2015 Quarter, primarily related to the issuance of new senior notes during the second quarter of 2016 and borrowings on the Dropdown Credit Facility related to the acquisitions of the LA Storage and Handling Assets and the Alaska Storage and Terminalling Assets.

NINE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS NINE MONTHS ENDED SEPTEMBER 30, 2015

OVERVIEW. Our net earnings for the nine months endedSeptember 30, 2016 (“2016 Period”) increased$53 million to $259 million from $206 million for the nine months ended September 30, 2015 (“2015 Period”) primarily driven by increases in revenue partially offset by an increase to interest and financing costs, net.

REVENUES. Revenues for the 2016 Period increased$81 million to $901 million from $820 million for the 2015 Period primarily driven by the LA Storage and Handling Assets purchased from Tesoro in November 2015 and the Alaska Storage and Terminalling Assets purchased in July 2016. In addition, revenue increases were driven by higher pipeline transportation demand, organic growth and asset optimization.

OPERATING EXPENSES. Operating expenses for the 2016 Period increased$19 million to $313 million from $294 million for the 2015 Period primarily due to the reporting of gross operating expense related to our transactions with RGS for the 2016 Period that were eliminated in the 2015 Period in consolidation.

GENERAL AND ADMINISTRATIVE EXPENSES.General and administrative expenses decreased$11 million to $70 million in the 2016 Period compared to the 2015 Period primarily due to higher costs in 2015 due to integration efforts in connection with the QEPFS acquisition.

INTEREST AND FINANCING COSTS, NET. Net interest and financing costs increased$26 million to $138 million from $112 million for the 2015 Period primarily related to the issuance of new senior notes during the 2016 Period, and borrowings on the Dropdown Credit Facility related to the acquisition of the LA Storage and Handling Assets and Alaska Storage and Terminalling Assets and the write-off of unamortized debt issuance costs in connection with debt transactions as discussed in the “Capital Resources and Liquidity” section.

OTHER INCOME, NET.The 2016 Period included a settlement gain of $6 million related to the legal settlement in the second quarter of 2016.

SEGMENT RESULTS OF OPERATIONS

GATHERING SEGMENT

Our Gathering segment consists of crude oil, natural gas and produced water gathering systems in the Bakken Region and the Rockies Region. Our High Plains System, located in the Bakken Region, gathers and transports crude oil from various production locations in this area for transportation to Tesoro’s North Dakota refinery and other destinations in the Bakken Region, including export rail terminals and pipelines. Our natural gas gathering systems include the gathering systems of our equity method investments.

24 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

GATHERING SEGMENT OPERATING RESULTS (in millions, except volumes, revenue per barrel and revenue per MMBtu amounts)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues
Gas gathering revenues	$	39	$	46	$	122	$	128
Crude oil gathering pipeline revenues	33		31		100		88
Crude oil trucking revenues	9		10		27		37
Other revenues	1		—		6		—
Total Revenues	82		87		255		253
Costs and Expenses
Operating expenses (a)	30		27		92		74
General and administrative expenses	3		2		8		8
Depreciation and amortization expenses	16		16		45		50
Loss on asset disposals and impairments	2		—		3		—
Gathering Segment Operating Income	$	31	$	42	$	107	$	121
Volumes
Gas gathering throughput (thousands of MMBtu/d) (b)	887		1,115		881		1,069
Average gas gathering revenue per MMBtu (b)	$	0.48	$	0.45	$	0.51	$	0.44
Crude oil gathering pipeline throughput (Mbpd)	206		199		210		182
Average crude oil gathering pipeline revenue per barrel	$	1.71	$	1.71	$	1.73	$	1.77
Crude oil trucking volume (Mbpd)	32		34		30		42
Average crude oil trucking revenue per barrel	$	3.25	$	3.14	$	3.26	$	3.24

(a) Operating expenses include an imbalance settlement gains of $1 million and loss of $1 million for the three months ended September 30, 2016 and 2015, respectively, and gains of $2 millionand $1 million for the nine months ended September 30, 2016 and 2015, respectively.

(b) Prior to the deconsolidation of RGS as of January 1, 2016, fees paid by us to RGS were eliminated upon consolidation and third-party transactions, including revenue and throughput volumes, were included in our results of operations. Third-party volumes associated with RGS, included in gas gathering volume for the three and nine months ended September 30, 2015 were 142 thousand and 145 thousand MMBtu/d, respectively, and reduced our average gas gathering revenue per MMBtu by $0.05 for both periods.

THREE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS THREE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. The decrease in gas gathering throughput volumes of 228 thousand MMBtu per day (“MMBtu/d”), or 20% in the 2016 Quarter as compared to the 2015 Quarter was primarily driven by the exclusion of volumes associated with RGS following our deconsolidation of RGS in 2016 as well as declines in natural gas production leading to reduced volumes on our gathering system. Third-party volumes associated with RGS, included in gas gathering volume for the three months ended September 30, 2015 were 142 thousand MMBtu/d. Average crude oil gathering pipeline throughput volumes increased7 Mbpd, or 4%, in the 2016 Quarter as a result of projects to expand the pipeline gathering system capabilities, which include additional origin and destination interconnections.

FINANCIAL RESULTS. Gathering revenues decreased$5 million, or 6%, to $82 million for the 2016 Quarter compared to $87 million in the 2015 Quarter primarily due to the decline in average gas gathering throughput partially offset by an increase in the average gas gathering rates. Partially offsetting the decrease in gas gathering and crude oil trucking were increases to crude oil gathering pipeline revenues as a result of higher crude oil pipeline throughput on our High Plains Pipeline.

Operating expenses increased$3 million, or 11%, to $30 million in the 2016 Quarter compared to $27 millionin the 2015 Quarter related to the reporting of gross operating expenses related to our transactions with RGS for the 2016 Quarter that were previously eliminated in the 2015 Quarter as well as an increase to our pipeline loss allowance in the 2016 Quarter. Operating expenses for the rest of the Gathering segment were relatively flat in the 2016 Quarter compared to the 2015 Quarter.

September 30, 2016 | 25

MANAGEMENT’S DISCUSSION AND ANALYSIS

NINE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS NINE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. Average crude oil gathering pipeline throughput volumes increased28 Mbpd, or 15%, in the 2016 Period as a result of projects to expand the pipeline gathering system and additional origin and destination interconnections. Crude oil trucking volumes decreased12 Mbpd, or 29%, during the 2016 Period as more volumes were gathered via pipeline on to our High Plains Pipeline. The decrease in gas gathering throughput volumes of 188 MMBtu/d, or 18%, in the 2016 Period as compared to the 2015 Period is driven by the exclusion of volumes associated with RGS following our deconsolidation of RGS in 2016 as well as declines in natural gas production leading to reduced volumes on our gathering system. Third-party volumes associated with RGS, included in gas gathering volume for the nine months ended September 30, 2015, were 145 thousand MMBtu/d.

FINANCIAL RESULTS. Gathering revenues remained flat for the 2016 Period compared to the 2015 Period. During the 2016 Period, Volumes on the High Plains Pipeline System increased from the 2015 Period, which were partially offset by decreases in crude oil trucking revenues. Additionally the 2016 Period includes a one-time recovery of fees related to right-of-way costs. The decrease in Gas gathering revenues in the 2016 Period as compared to the 2015 Period was primarily driven by the exclusion of volumes associated with RGS following our deconsolidation of RGS in 2016 partially offset by increases in the average gas gathering rate recognized.

Operating expenses increased$18 million, or 24%, to $92 million in the 2016 Period compared to$74 million in the 2015 Period primarily related to the reporting of gross operating expense related to our transactions with RGS for the 2016 Period that were previously eliminated in the 2015 Period. Operating expenses for the rest of the Gathering segment were relatively flat in the 2016 Period compared to the 2015 Period.

PROCESSING SEGMENT

PROCESSING SEGMENT OPERATING RESULTS (in millions, except MMBtu/d, Mbpd and revenue per MMBtu and fee per barrel)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues
NGLs processing revenues	$	23	$	26	$	74	$	71
Fee-based processing revenues	29		28		80		81
Other processing revenues	17		17		54		53
Total Revenues	69		71		208		205
Costs and Expenses
Operating expenses	29		31		89		91
General and administrative expenses	—		—		—		4
Depreciation and amortization expenses	11		11		34		33
Processing Segment Operating Income	$	29	$	29	$	85	$	77
Volumes
NGLs processing throughput (Mbpd)	6.7		7.8		7.4		7.5
Average keep-whole fee per barrel of NGLs	$	38.35	$	35.75	$	36.58	$	34.26
Fee-based processing throughput (thousands of MMBtu/d)	625		767		648		742
Average fee-based processing revenue per MMBtu	$	0.50	$	0.39	$	0.45	$	0.40

THREE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS THREE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. Fee-based processing volumes decreased142 thousand MMBtu/d, or 19%, to 625 thousand MMBtu/d in the 2016 Quarter as a result of lower natural gas production being delivered to our processing systems. Average NGLs processing volumes decreased by 1.1 Mbpd, or 14%, to 6.7 Mbpd in the 2016 Quarter.

FINANCIAL RESULTS. Processing revenues decreased$2 million, or 3%, to $69 million for the 2016 Quarter compared to $71 million in the 2015 Quarter. Improved optimization of our processing facilities along with annual rate escalations resulted in increased NGL processing revenues, offset by a decline in volumes in the 2016 Quarter compared to the 2015 Quarter.

26 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

NINE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS NINE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. Fee-based processing volumes decreased94 thousand MMBtu/d, or 13%, to 648 thousand MMBtu/d in the 2016 Period as a result of lower natural gas production being delivered to our processing systems. Average NGLs processing volumes were relatively flat in the 2016 Quarter compared to the 2015 Quarter.

FINANCIAL RESULTS. Processing revenues increased$3 million, or 1%, to $208 million for the 2016 Period compared to $205 millionin the 2015 Period primarily due to an increase in the average keep-whole processing fee per barrel of NGLs. Improved optimization of our processing facilities along with annual rate escalations resulted in increased NGL processing and fee-based processing rates, offset by a decline in fee-based processing volumes in the 2016 Period compared to the 2015 Period due to production declines.

TERMINALLING AND TRANSPORTATION SEGMENT

Our Terminalling and Transportation segment consists of regulated common carrier refined products pipeline systems and other pipelines, which transport products and crude oil from Tesoro’s refineries to nearby facilities, as well as crude oil and refined products terminals and storage facilities, a rail-car unloading facility and a petroleum coke handling and storage facility.

TERMINALLING AND TRANSPORTATION SEGMENT OPERATING RESULTS (in millions, except barrel and per barrel amounts)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues (a)
Terminalling revenues	$	125	$	93	$	345	$	275
Pipeline transportation revenues	32		31		93		87
Total Revenues	157		124		438		362
Costs and Expenses
Operating expenses (b)	45		45		132		129
General and administrative expenses	9		10		25		26
Depreciation and amortization expenses	18		18		55		50
Terminalling and Transportation Segment Operating Income	$	85	$	51	$	226	$	157
Volumes
Terminalling throughput (Mbpd)	1,023		964		998		932
Average terminalling revenue per barrel	$	1.33	$	1.05	$	1.27	$	1.08
Pipeline transportation throughput (Mbpd)	908		838		866		819
Average pipeline transportation revenue per barrel	$	0.38	$	0.40	$	0.39	$	0.39

(a) Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment prior to the effective date of the acquisitions of the LA Storage and Handling Assets and Alaska Storage and Terminalling Assets.

(b) Operating expenses include imbalance settlement gains of $1 million for both the three months ended September 30, 2016 and 2015, and $3 million for both the nine months ended September 30, 2016 and 2015.

THREE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS THREE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. Terminalling throughput volumes increased59 Mbpd, or 6%, and pipeline transportation throughput volumes increased70 Mbpd, or 8%, in the 2016 Quarter compared to the 2015 Quarter primarily due to the terminalling assets from the second phase of the Alaska Storage and Terminalling Assets acquisition and higher pipeline volumes in southern California as a result of higher customer demand in the 2016 Quarter and organic growth projects adding new capabilities to our system.

FINANCIAL RESULTS. Revenues increased$33 million, or 27%, to $157 million in the 2016 Quarter compared to$124 million in the 2015 Quarter primarily as a result of the commercial storage agreements executed with Tesoro in connection with the LA Storage and Handling Asset and Alaska Storage and Terminalling Assets acquisitions as well as increased pipeline transportation throughput volumes.

September 30, 2016 | 27

MANAGEMENT’S DISCUSSION AND ANALYSIS

NINE MONTHS ENDED SEPTEMBER 30, 2016 VERSUS NINE MONTHS ENDED SEPTEMBER 30, 2015

VOLUMES. Terminalling throughput volumes increased66 Mpbd, or 7% and pipeline transportation throughput volumes increased47 Mbpd, or 6%, in the 2016 Period compared to the 2015 Period primarily due to stronger customer demand, terminalling assets from the second phase of the Alaska Storage and Terminalling Assets acquisition and organic growth projects adding new capabilities to our system.

FINANCIAL RESULTS. Revenues increased$76 million, or 21%, to $438 million in the 2016 Period compared to $362 million in the 2015 Period primarily as a result of the commercial storage agreements executed with Tesoro in connection with the LA Storage and Handling Asset and Alaska Storage and Terminalling Assets acquisitions as well as increased throughput volumes.

CAPITAL RESOURCES AND LIQUIDITY

OVERVIEW

Our primary cash requirements relate to funding capital expenditures, acquisitions, 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 secured revolving credit facility (the “Revolving Credit Facility”), the Dropdown 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.

CAPITALIZATION

CAPITAL STRUCTURE (in millions)

Debt principal, including current maturities:	September 30, 2016			December 31, 2015
Credit Facilities	$	400		$	555
Senior Notes	3,020			2,320
Capital lease obligations	8			8
Total Debt	3,428			2,883
Unamortized Issuance Costs (a)	(46		)	(39		)
Debt, Net of Unamortized Issuance Costs	3,382			2,844
Total Equity	1,663			1,794
Total Capitalization	$	5,045		$	4,638

(a) Includes unamortized premiums of $4 million associated with our senior notes at both September 30, 2016 and December 31, 2015.

EQUITY OVERVIEW

Our partnership agreement authorizes us to issue an unlimited number of additional partnership securities on the terms and conditions determined by our general partner without the approval of the unitholders. Costs associated with the issuance of securities are allocated to all unitholders’ capital accounts based on their ownership interest at the time of issuance.

UNIT ISSUANCE. We closed a registered public offering of 6,325,000 common units representing limited partner interests, including the over-allotment option exercised by the underwriter for the purchase of an additional 825,000 common units, at a public offering price of $47.13 per unit on June 10, 2016. The net proceeds of $293 million are expected to be used for general partnership purposes, which may include future acquisitions, capital expenditures and additions to working capital.

ATM PROGRAM. On August 24, 2015,we filed a prospectus supplement to our shelf registration statement filed with the Securities and Exchange Commission (“SEC”) 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 “ATM Program”). During the three and nine months ended September 30, 2016, we issued an aggregate of 655,940 and 1,492,637 common units, respectively, under our ATM Program, generating proceeds of approximately $31 million and $72 million, respectively, before issuance costs. We paid fees of less than $1 million related to the issuance of units under this program for both the three and nine months ended September 30, 2016, respectively. The net proceeds from sales under the ATM Program will be used for

28 | Tesoro Logistics LP

MANAGEMENT’S DISCUSSION AND ANALYSIS

general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

DEBT OVERVIEW AND AVAILABLE LIQUIDITY

Our secured Revolving Credit Facility, secured Dropdown Credit Facility and 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, 2015. As discussed below, on May 9, 2016, we issued senior notes due in 2024 that have substantially the same covenants as the existing senior notes. We do not believe that these limitations will restrict our ability to pay distributions. Additionally, our secured Revolving Credit Facility and secured Dropdown Credit Facility contain 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, 2016.

AVAILABLE CAPACITY UNDER OUR CREDIT FACILITIES (in millions)

	Total Capacity		Amount Borrowed as of September 30, 2016		Available Capacity		Weighted Average Interest Rate		Expiration
Revolving Credit Facility	$	600	$	—	$	600	—	%	January 29, 2021
Dropdown Credit Facility	1,000		400		600		2.54	%	January 29, 2021
Total Credit Facilities	$	1,600	$	400	$	1,200

EXPENSES AND FEES OF OUR CREDIT FACILITIES

Credit Facility	30 day Eurodollar (LIBOR) Rate at September 30, 2016	Eurodollar Margin	Base Rate	Base Rate Margin	Commitment Fee (unused portion)
Revolving Credit Facility (a)	0.53%	2.00%	3.50%	1.00%	0.38%
Dropdown Credit Facility (a)	0.53%	2.01%	3.50%	1.01%	0.38%

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

SENIOR NOTES ISSUANCE. On May 9, 2016, we completed a registered offering of $250 million aggregate principal amount of 6.125% Senior Notes due 2021 (“2021 Notes”) and $450 million aggregate principal amount of 6.375% Senior Notes due 2024 (“2024 Notes”). We used the proceeds of the offering of the 2021 notes to repay amounts outstanding under our dropdown credit facility and the proceeds of the offering of the 2024 notes to repay amounts outstanding under our revolving credit facility and for general partnership purposes. See Note 5 in Part I, Item 1 of this Quarterly Report for additional information on the 2021 Notes and 2024 Notes.

DEBT REPAYMENTS. On February 3, 2016, we paid the full amount of the Unsecured Term Loan Facility, including accrued interest, with proceeds drawn from the secured Dropdown Credit Facility. All commitments under the Unsecured Term Loan Facility were terminated effective with the repayment and an immaterial amount of unamortized debt issuance costs were expensed.

SENIOR NOTES EXCHANGE.On February 26, 2016, the Partnership commenced an offer to exchange (the “Exchange”) its existing unregistered 5.50% Senior Notes due 2019 (“2019 Notes”) and 6.25% Senior Notes due 2022 (“2022 Notes”) (together, “Unregistered Notes”) for an equal principal amount of 5.50% Senior Notes due 2019 and 6.25% Senior Notes due 2022 (the “Exchange Notes”), respectively, that were registered under the Securities Act of 1933, as amended. On April 14, 2016, the Exchange was completed for all of the 2019 Notes and substantially all of the 2022 Notes. The terms of the Exchange Notes are identical in all material respects (including principal amount, interest rate, maturity and redemption rights) to the Unregistered Notes for which they were exchanged, except that the Exchange Notes generally are not subject to transfer restrictions. The Exchange fulfills all of the requirements of the registration rights agreements for the Unregistered Notes.

September 30, 2016 | 29

MANAGEMENT’S DISCUSSION AND ANALYSIS

SOURCES AND USES OF CASH

COMPONENTS OF CASH FLOWS (in millions)

	Nine Months Ended September 30,
	2016			2015
Cash Flows From (Used In):
Operating Activities	$	425		$	348
Investing Activities	(166		)	(243		)
Financing Activities	222			(113		)
Increase (Decrease) in Cash and Cash Equivalents	$	481		$	(8	)

OPERATING ACTIVITIES.Net cash from operating activities increased$77 million to $425 million in the 2016 Period compared to $348 million for the 2015 Period. Theincrease in cash from operations was primarily driven by the increase in net earnings of $53 million from the 2015 Period to the 2016 Period and a $15 million impact of non-cash items.

INVESTING ACTIVITIES.Net cash used in investing activities for the 2016 Period decreased$77 million to $166 million compared to $243 million in the 2015 Period. The decrease in this outflow resulted from 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. Additionally, $30 million in acquisitions reflects assets acquired by Predecessors in connection with the Alaska Storage and Terminalling Assets transaction. See “Capital Expenditures” below for a discussion of the various maintenance and growth projects in the 2016 Period.

FINANCING ACTIVITIES.Net cash provided by financing activities for the 2016 Period was $222 million compared to a use of cash of $113 million for the 2015 Period. We received $701 million of proceeds from debt offerings and $364 million in net proceeds from issuances of units. Offsetting these proceeds were higher quarterly cash distributions totaling $329 million during the 2016 Period compared to quarterly cash distributions totaling $221 million paid in the 2015 Period. We paid down $95 million of net borrowings under our secured Revolving Credit Facility during the 2016 Period and paid off the Unsecured Term Loan Facility of $250 million.

Historically, the Predecessors’ sources of liquidity included cash generated from operations and funding from Tesoro. Cash receipts were deposited in Tesoro’s bank accounts and all cash disbursements were made from those accounts. The Sponsor contribution of $34 million and $19 million included in cash from financing activities for the 2016 Period and the 2015 Period, respectively, funded the cash portion of the net loss for the Predecessors.

CAPITAL EXPENDITURES

The Partnership’s operations are capital intensive, requiring investments to expand, upgrade or enhance existing operations and to maintain assets and ensure 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. Maintenance capital expenditures include expenditures required to maintain equipment reliability and integrity and to ensure regulatory compliance. Actual and estimated amounts described below include amounts representing capitalized interest and labor. Our capital expenditures are funded primarily with cash generated from operations, reimbursements for certain growth and maintenance capital expenditures, borrowings under our revolving credit facilities and issuances of additional debt and equity securities, as needed.

TLLP's expected 2016 net capital expenditures are currently forecast to total approximately $170 million, or $200 million offset by expected reimbursements of $30 million primarily for maintenance capital expenditures. Our revised capital spending estimate reflects changes in project outlooks based on lower producer activity, cost savings on projects and the latest estimates of timing on project spend. Cost estimates for projects currently in process or under development are subject to further review, analysis and permitting requirements, which may result in revisions to our current spend estimates. During the 2016 Period, we spent $88 million, net of $1 million in reimbursements from entities including Tesoro, on growth capital projects and $21 million, net of $15 million in reimbursements from entities including Tesoro, on maintenance capital projects.

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MANAGEMENT’S DISCUSSION AND ANALYSIS

MAJOR GROWTH CAPITAL PROJECTS COMPLETED, IN PROCESS OR UNDER DEVELOPMENT (in millions)

Major Projects	Total Project Expected Capital Expenditures		Actual 2016 Capital Expenditures
Gathering Segment:
Uinta Compression (a)	$	50	$	34
Bakken Area Storage Hub (b)	28		5
High Plains Pipeline Expansion (c)	20		7
Terminalling and Transportation Segment:
Los Angeles Refinery Interconnect Pipeline System (d)	150-200		—
Terminal Expansions (e)	30		12

(a) Projects to increase compression for our Uinta natural gas gathering systems and expand our gathering system in the Uinta basin. We expect incremental volumes through our processing system upon the completion of the project.

(b) The construction of the second phase of the Bakken Area Storage Hub provides storage tanks located in two strategic areas of the basin. With its completion during the first quarter of 2016, storage capacity has grown to over 1 million barrels. Amounts shown above for capital expenditures represent actual amounts spent on this completed project.

(c) Projects to expand crude oil gathering throughput capacity on the High Plains Pipeline in McKenzie County, North Dakota. The expansion project’s expected capital expenditures may be reduced as a result of Tesoro’s recent acquisition of Great Northern Midstream and associated BakkenLink pipeline.

(d) The pipeline interconnect project at the Los Angeles refinery is designed to provide direct connectivity between Tesoro’s refining sites. The proposed project is subject to final Board of Directors approval, project scoping, engineering and regulatory approval.

(e) Projects to increase the throughput capacity and service capabilities at our crude oil and refined products terminals.

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.

QUARTERLY DISTRIBUTIONS

Quarter Ended	Total Quarterly Distribution Per Unit		Total Quarterly Distribution Per Unit, Annualized		Total Cash Distribution including general partner incentive distribution rights (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2015	$	0.780	$	3.12	$	98	February 12, 2016	February 2, 2016
March 31, 2016	0.810		3.24		108		May 13, 2016	May 2, 2016
June 30, 2016	0.842		3.37		123		August 12, 2016	August 2, 2016
September 30, 2016 (a)	0.875		3.50		131		November 14, 2016	November 4, 2016

(a) This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

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

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MANAGEMENT’S DISCUSSION AND ANALYSIS

of operations. See Note 6 to our condensed combined consolidated financial statements for additional information regarding environmental regulation and Tesoro indemnification. See our discussion of the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement in Note 3 of our Annual Report on Form 10-K for the year ended December 31, 2015 for more information regarding the indemnification of certain environmental matters provided to us by Tesoro and discussion of other certain environmental obligations.

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.

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:

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

• a material decrease in the crude oil and natural gas produced in the Bakken Shale/Williston Basin area of North Dakota and Montana;

• a material decrease in the natural gas and crude oil produced in the Green River Basin, Uinta Basin and Vermillion Basin in the states of Utah, Colorado and Wyoming;

• the ability of our key customers, including Tesoro, to remain in compliance with the terms of their outstanding indebtedness;

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

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

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

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

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

• changes in our cash flow from operations;

• 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 those in our supply and distribution chains, including Tesoro and Tesoro’s customers, and the ability to replace such contracts and/or customers;

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

• a material decrease in profitability among our customers, including Tesoro;

• earthquakes or other natural disasters affecting operations;

• direct or indirect effects on our business resulting from actual or threatened terrorist or activist incidents, cyber-security breaches or acts of war;

• weather conditions affecting operations by us or our key customers, including Tesoro, or the areas in which the customers we serve operate;

• disruptions due to equipment interruption or failure at our facilities, Tesoro’s facilities or third-party facilities on which our key customers, including Tesoro, are dependent;

• changes in the expected value of and benefits derived from acquisitions;

• actions of customers and competitors;

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MANAGEMENT’S DISCUSSION AND ANALYSIS

• changes in our credit profile;

• 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, compliance costs or other factors beyond our control;

• delays in obtaining necessary approvals and permits;

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

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

• seasonal variations in demand for natural gas and 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; 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 revise or update any forward-looking statements as a result of new information, future events or otherwise.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

MARKET RISK

Market risk is the risk of financial 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 less than $0.1 million on an annual basis. This analysis may differ from actual results.

We process 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 we as the processor, in exchange, deliver to the producer natural gas with a British thermal unit content equivalent to the NGLs removed. We have entered into an agreement with Tesoro (“Keep-Whole Agreement”) to transfer the market risk associated with the purchase of natural gas. The Keep-Whole Amendment provides that the service fees payable for incremental volumes of NGLs above 315,000 gallons per day will be a mutually agreed upon fee. See Note 3 of our Annual Report on Form 10-K for the year ended December 31, 2015, for additional information on our Keep-Whole Agreement.

September 30, 2016 | 33

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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 and Dropdown 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 approximately $3.4 billion and $3.6 billion as of September 30, 2016, respectively. The carrying value and fair value of our debt were approximately $2.9 billion and $2.8 billion at December 31, 2015, respectively. 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 or Dropdown Credit Facility at September 30, 2016, would change annual interest expense by $1 million. As of September 30, 2016, we had $400 million of borrowings outstanding under our Dropdown Credit Facility. The were no borrowings outstanding under our Revolving Credit Facility as of September 30, 2016. Any change in interest rates would affect cash flows, but not the fair value of the debt we incur under our Revolving Credit Facility and Dropdown 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.

ITEM 4. 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. There have been no significant changes in our internal controls over financial reporting (as defined by applicable SEC rules) during the quarter ended September 30, 2016 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.

34 | Tesoro Logistics LP

LEGAL PROCEEDINGS, RISK FACTORS AND UNREGISTERED SHARES OF EQUITY SECURITIES

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. There were no new reportable matters that arose during the third quarter of 2016. In addition, no material developments occurred with respect to proceedings previously reported in our Annual Report on Form 10-K for the year ended December 31, 2015 or our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2016 or June 30, 2016. Although we cannot provide assurance, we believe that an adverse resolution of such proceedings would 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, 2015.

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

As described elsewhere in this Quarterly Report on Form 10-Q and in the Partnership’s Current Reports on Form 8-K filed with the Securities and Exchange Commission on July 7, 2016 and September 22, 2016, the Partnership issued equity to Tesoro Logistics GP, LLC, our general partner, as part of the consideration for the acquisition of the Alaska Storage and Terminalling Assets.

ITEM 6. EXHIBITS

(a) Exhibits

Exhibit Number	Description of Exhibit
2.1	Contribution, Conveyance and Assumption Agreement, dated as of July 1, 2016, among Tesoro Logistics LP, Tesoro Logistics GP, LLC, Tesoro Logistics Operations LLC, Tesoro Alaska Company LLC and Tesoro Corporation (incorporated by reference herein to Exhibit 2.1 to the Partnership’s Current Report on Form 8-K filed on July 7, 2016, File No. 1-35143).
*2.2	Revision to the Contribution, Conveyance and Assumption Agreement, dated as of July 27, 2016, among Tesoro Logistics LP, Tesoro Logistics GP, LLC, Tesoro Logistics Operations LLC, Tesoro Alaska Company LLC and Tesoro Corporation.
3.1	Corrected Amendment No. 3 to the Second Amended and Restated Limited Liability Company Agreement of Tesoro Logistics GP, LLC, dated as of July 1, 2016, between Tesoro Corporation, Tesoro Refining & Marketing Company LLC and Tesoro Alaska Company LLC (incorporated by reference herein to Exhibit 3.1 to the Partnership’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2016, File No. 1-35143).
3.2	Amendment No. 4 to the Second Amended and Restated Limited Liability Company Agreement of Tesoro Logistics LP, LLC, dated as of September 16, 2016, between Tesoro Logistics GP, LLC, Tesoro Corporation, Tesoro Refining & Marketing Company, LLC and Tesoro Alaska Company LLC (incorporated by reference herein to Exhibit 3.1 to the Partnership’s Current Report on Form 8-K filed on September 22, 2016, File No. 1-35143).
4.1	Fifth Supplemental Indenture, dated as of May 12, 2016, among Tesoro Logistics LP, Tesoro Logistics Finance Corp., the guarantors named therein and U.S. Bank National Association, as trustee, relating to the 2021 Notes (incorporated by reference herein to Exhibit 4.1 to the Partnership’s Current Report on Form 8-K filed on May 12, 2016, File No. 1-35143).
4.2	Indenture (including form of note), dated as of May 12, 2016, among Tesoro Logistics LP, Tesoro Logistics Finance Corp., the guarantors named therein and U.S. Bank National Association, as trustee, relating to the 2024 Notes (incorporated by reference herein to Exhibit 4.2 to the Partnership’s Current Report on Form 8-K filed on May 12, 2016, File No. 1-35143).
10.1	Ground Lease, dated as of July 1, 2016, between Tesoro Alaska Company LLC and Tesoro Logistics Operations LLC (incorporated by reference herein to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K filed on July 7, 2016, File No. 1-35143).
10.2	Second Amended and Restated Schedules to the Third Amended and Restated Omnibus Agreement, dated as of July 1, 2016, among Tesoro Logistics LP, Tesoro Logistics GP, LLC, Tesoro Corporation, Tesoro Refining & Marketing Company LLC, Tesoro Alaska Company LLC and Tesoro Companies, Inc. (incorporated by reference herein to Exhibit 10.2 to the Partnership’s Current Report on Form 8-K filed on July 7, 2016, File No. 1-35143).

September 30, 2016 | 35

EXHIBITS

Exhibit Number	Description of Exhibit
10.3	Kenai Storage Services Agreement, dated as of July 1, 2016, among Tesoro Alaska Company LLC, Tesoro Logistics Operations LLC, Tesoro Logistics GP, LLC and Tesoro Logistics LP (incorporated by reference herein to Exhibit 10.3 to the Partnership’s Current Report on Form 8-K filed on July 7, 2016, File No. 1-35143).
10.4	Amendment No.1 to the Second Amended and Restated Master Terminalling and Service Agreement, dated as of September 16, 2016, among Tesoro Refining & Marketing Company, LLC, Tesoro Alaska Company LLC, and Tesoro Logistics Operations LLC (incorporated by reference herein to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K filed on September 22, 2016, File No. 1-35143).
10.5	Alaska Terminalling Services Agreement, dated as of September 16, 2016, among Tesoro Alaska Company LLC, Tesoro Logistics Operations LLC, Tesoro Alaska Terminals, LLC, Tesoro Logistics GP, LLC, and Tesoro Logistics LP (incorporated by reference herein to Exhibit 10.2 to the Partnership’s Current Report on Form 8-K filed on September 22, 2016, File No. 1-35143).
10.6	Second Amended and Restated Representation and Services Agreement for Oil Spill Contingency Planning Response and Remediation, dated as of September 16, 2016, among Tesoro Companies, Inc., Tesoro Maritime Company, Tesoro Refining & Marketing Company LLC, Tesoro Alaska Company LLC, Kenai Pipe Line Company, Tesoro Alaska Pipeline Company LLC, Carson Cogeneration Company, Tesoro Great Plains Midstream LLC, Tesoro Great Plains Gathering & Marketing LLC, Bakkenlink Pipeline LLC, ND Land Holdings LLC, Tesoro Logistics Operations LLC, Tesoro High Plains Pipeline Company LLC, Tesoro Logistics Pipelines LLC, Tesoro Logistics Northwest Pipeline LLC, Tesoro SoCal Pipeline Company LLC, QEP Field Services, LLC, QEPM Gathering I, LLC, Green River Processing, LLC, Rendezvous Pipeline Company, LLC, and Tesoro Alaska Terminals, LLC (incorporated by reference herein to Exhibit 10.3 to the Partnership’s Current Report on Form 8-K filed on September 22, 2016, File No. 1-35143).
10.7	Third Amended and Restated Schedules to Third Amended and Restated Omnibus Agreement, dated as of September 16, 2016, among Tesoro Corporation, Tesoro Refining & Marketing Company LLC, Tesoro Companies, Inc., Tesoro Alaska Company LLC, Tesoro Logistics LP and Tesoro Logistics GP, LLP (incorporated by reference herein to Exhibit 10.4 to the Partnership’s Current Report on Form 8-K filed on September 22, 2016, 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

36 | Tesoro Logistics LP

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:	November 1, 2016	By:	/s/ GREGORY J. GOFF
			Gregory J. Goff
			Chief Executive Officer
			(Principal Executive Officer)
Date:	November 1, 2016	By:	/s/ STEVEN M. STERIN
			Steven M. Sterin
			Executive Vice President and Chief Financial Officer
			(Principal Financial Officer)

September 30, 2016 | 37

EX-2.2

TESORO LOGISTICS LP

July 27, 2016

Tesoro Logistics GP, LLC

Tesoro Logistics Operations LLC

Tesoro Alaska Company LLC

Tesoro Corporation

19100 Ridgewood Parkway

San Antonio, Texas 78259-1828

Re: Contribution, Conveyance and Assumption Agreement, dated as of July 1, 2016 (the “Contribution Agreement”), among Tesoro Logistics LP (the “Partnership”), Tesoro Logistics GP, LLC (the “General Partner”), Tesoro Logistics Operations LLC, Tesoro Alaska Company LLC and Tesoro Corporation                        

Ladies and Gentlemen:

Reference is hereby made to the Contribution Agreement. All capitalized terms used but not defined in this letter shall have the meanings ascribed to them in the Contribution Agreement.

The parties desire to revise the Contribution Agreement to clarify the reimbursement to be paid by the General Partner to the Partnership under Section 4.3 of the Contribution Agreement. Accordingly, the parties agree that Section 4.3 is hereby amended and restated in its entirety as follows:

Section 4.3    General Partner Reimbursement. Promptly after the First Closing, the General Partner shall reimburse the Partnership in an amount equal to $4,000,000.00 (the “Reimbursement”) to address inefficiencies of capital relating to approximately $100,000,000.00 of unused proceeds from the Partnership’s issuance of its 6.375% senior notes due 2024 (the “Available Offering Proceeds”) available to reduce Borrowings at the time of the First and Second Closings. The amount of the Reimbursement is equal to the amount of interest that the Partnership expects to incur on the Available Offering Proceeds for 7.5 months at a rate of 6.375%.

The parties agree that, other than as amended by this letter, the Contribution Agreement shall remain in full force and effect and unmodified.

July 27, 2016

Page 2 of 2

Sincerely,

TESORO LOGISTICS LP

By:    Tesoro Logistics GP, LLC,

its general partner

By:    /s/ PHILLIP M. ANDERSON

Phillip M. Anderson

President

AGREED AND ACCEPTED:

TESORO CORPORATION By: /s/ GREGORY J. GOFF        Gregory J. Goff        President and Chief Executive Officer	TESORO ALASKA COMPANY LLC By: /s/ GREGORY J. GOFF        Gregory J. Goff        President
TESORO LOGISTICS GP, LLC TESORO LOGISTICS OPERATIONS LLC By: /s/ PHILLIP M. ANDERSON        Phillip M. Anderson        President

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:	November 1, 2016	/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:	November 1, 2016	/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, 2016 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)

November 1, 2016

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, 2016 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)

November 1, 2016

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

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 26, 2016
Entity Registrant Name	TESORO LOGISTICS LP
Entity Central Index Key	0001507615
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2016
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		102,096,039
General Partner
Entity Common Stock, Units Outstanding		2,083,330

XML

Condensed Statements of Combined Consolidated Operations (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
Revenues
Affiliate	[1],[2]	$ 184	$ 152	$ 521		$ 454
Third-party	[1]	124	130	380		366
Total Revenues	[1]	308	282	901		820
Costs and Expenses
Operating expenses	[1]	110	113	332		323
Imbalance settlement gains and reimbursements	[1]	(6)	(10)	(19)		(29)
General and administrative expenses	[1]	24	28	70		81
Depreciation and amortization expenses	[1]	45	45	134		133
Loss on asset disposals and impairments	[1]	2	0	3		0
Operating Income	[1]	133	106	381		312
Interest and financing costs, net	[1]	(49)	(37)	(138)		(112)
Equity in earnings of equity method investments	[1]	3	2	10		6
Other income, net	[1]	0	0	6		0
Net Earnings	[1]	87	71	259	[3]	206	[3]
Loss attributable to Predecessors	[1]	1	6	4		17
Net earnings attributable to noncontrolling interest	[1]	0	(3)	0		(19)
Net Earnings Attributable to Partners	[1]	88	74	263		204
General partner’s interest in net earnings, including incentive distribution rights	[1]	(40)	(20)	(108)		(51)
Limited Partners’ Interest in Net Earnings	[1]	$ 48	$ 54	$ 155		$ 153
Net Earnings per Limited Partner Unit
Common - basic	[1]	$ 0.46	$ 0.62	$ 1.58		$ 1.85
Common - diluted	[1]	$ 0.46	$ 0.62	$ 1.58		$ 1.85
Weighted Average Limited Partner Units Outstanding
Common units - basic	[1]	101.4	86.6	96.7		82.5
Common units - diluted	[1]	101.4	86.7	96.8		82.6
Cash Distributions Paid Per Unit	[1]	$ 0.8420	$ 0.7225	$ 2.4320		$ 2.0850

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

[3] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	[1],[2]	$ 497	$ 16
Receivables, net of allowance for doubtful accounts
Trade	[1]	123	139
Affiliate	[1]	92	85
Prepayments and other current assets	[1]	31	12
Total Current Assets	[1]	743	252
Property, Plant and Equipment, Net	[1]	3,129	3,467
Acquired Intangibles, Net	[1]	955	976
Goodwill	[1]	117	130
Equity Method Investments	[1]	342	58
Other Noncurrent Assets, Net	[1]	33	26
Total Assets	[1]	5,319	4,909
Accounts payable
Trade	[1]	56	84
Affiliate	[1]	47	48
Accrued interest and financing costs	[1]	84	31
Other current liabilities	[1]	39	59
Total Current Liabilities	[1]	226	222
Debt, Net of Unamortized Issuance Costs	[1]	3,382	2,844
Other Noncurrent Liabilities	[1]	48	49
Total Liabilities	[1]	3,656	3,115
Commitments and Contingencies (Note 6)	[1]
Equity Of Predecessors	[1]	0	16
Equity
Common unitholders; 102,096,039 units issued and outstanding (93,478,326 in 2015)	[1]	1,729	1,707
General partner; 2,083,330 units issued and outstanding (1,900,515 in 2015)	[1]	(66)	(13)
Noncontrolling interest	[1]	0	84
Total Equity	[1]	1,663	1,794
Total Liabilities and Equity	[1]	$ 5,319	$ 4,909

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

XML

Condensed Consolidated Balance Sheets (Unaudited), (Parenthetical) - shares	Sep. 30, 2016	Jun. 10, 2016	Dec. 31, 2015
Equity
Common units issued (units)	102,096,039	6,325,000	93,478,326
General partner units issued (units)	2,083,330		1,900,515

XML

Condensed Statements of Combined Consolidated Cash Flows (Unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2016		Sep. 30, 2015
Cash Flows From (Used In) Operating Activities:
Net earnings	[1],[2]	$ 259		$ 206
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation and amortization expenses	[2]	134		133
Other non-cash operating activities	[2]	27		12
Changes in current assets and current liabilities	[2]	9		(1)
Changes in noncurrent assets and noncurrent liabilities	[2]	(4)		(2)
Net cash from operating activities	[2]	425		348
Cash Flows Used In Investing Activities:
Capital expenditures	[2]	(132)		(237)
Acquisitions	[2]	(30)		0
Other investing activities	[2]	(4)		(6)
Net cash used in investing activities	[2]	(166)		(243)
Cash Flows From (Used In) Financing Activities:
Borrowings under revolving credit agreements	[2]	761		346
Repayments under revolving credit agreements	[2]	(666)		(326)
Proceeds from debt offering	[2]	701		0
Repayment of term loan facility	[2]	(250)		0
Proceeds from issuance of units, net of issuance costs	[2]	364		71
Quarterly distributions to unitholders	[2]	(234)		(173)
Quarterly distributions to general partner	[2]	(95)		(48)
Distributions to noncontrolling interest	[2]	0		(20)
Distributions in connection with acquisitions	[2]	(400)		0
Financing costs	[2]	(17)		0
Contributions from general partner	[2]	4		0
Sponsor contributions of equity to the Predecessors	[2]	34		19
Capital contributions by affiliate	[2]	21		18
Other financing activities	[2]	(1)		0
Net cash from (used in) financing activities	[2]	222		(113)
Increase (Decrease) in Cash and Cash Equivalents	[2]	481		(8)
Cash and Cash Equivalents, Beginning of Period	[2]	16	[3]	19
Cash and Cash Equivalents, End of Period	[2]	$ 497	[3]	$ 11

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[3] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

XML

Organization and Basis of Presentation (Notes)

9 Months Ended

Sep. 30, 2016

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.

PRINCIPLES OF COMBINATION AND CONSOLIDATION AND BASIS OF PRESENTATION

Acquired assets from Tesoro, and the associated liabilities and results of operations are collectively referred to as the “Predecessors.” See Note 2 for further discussion of acquisitions from Tesoro. The accompanying condensed combined consolidated financial statements and related notes present the financial position, results of operations and cash flows of our Predecessors at historical cost. The financial statements of our Predecessors have been prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as a stand-alone business. Our Predecessors did not record revenue for transactions with Tesoro and the expenses recognized were not material in the Terminalling and Transportation segment. Tesoro retained any current assets and current liabilities related to the Alaska Storage and Terminalling Assets as of the dates of the 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, 2015.

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 Predecessors, for any interim period are not necessarily indicative of results for the full year.

CONDENSED CONSOLIDATING FINANCIAL INFORMATION. The parent company of the Partnership’s operations, Tesoro Logistics LP, has no independent assets or operations. The Partnership’s operations are conducted by its 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 are no significant restrictions on the ability of the Partnership or any guarantor to obtain funds from its subsidiaries by dividend or loan. None of the assets of the Partnership or a guarantor represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.

As of September 30, 2016, Tesoro Alaska Terminals LLC, which the Partnership acquired from Tesoro as discussed further in Note 2, had not been designated as a guarantor subsidiary. No consolidating financial statements have been presented as the assets, equity and results of operations of this entity were minor in accordance with Rule 3-10(h)(6) of Regulation S-X under the Securities Act as of and for the periods ended September 30, 2016. Subsequent to the deconsolidation of Rendezvous Gas Services, L.L.C. (“RGS”) as of January 1, 2016, we are not required to provide condensed consolidating financial information pursuant to Rule 3-10 of Regulation S-X as we only have a minor consolidated non-guarantor subsidiary. For further discussion on the deconsolidation of RGS, see discussion below and in Note 4.

FAIR VALUE INFORMATION

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 (less than one percent of our trade payables and approximately one percent of our trade 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 the XTO Energy Inc.’s (“XTO”) legal dispute with QEP Field Services, LLC (“QEPFS”). See further discussion regarding the XTO litigation in Note 6.

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 secured revolving credit facility (the “Revolving Credit Facility”) and our secured dropdown credit facility (“Dropdown Credit Facility”), which include a variable interest rate, approximate fair value. The carrying value and fair value of our debt were approximately $3.4 billion and $3.6 billion as of September 30, 2016, respectively. The carrying value and fair value of our debt were approximately $2.9 billion and $2.8 billion at December 31, 2015, respectively. These carrying and fair values of our debt do not consider the unamortized issuance costs, which are netted against 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”), and has since amended the standard with ASU 2015-14, “Deferral of the Effective Date,” ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU 2016-10, “Identifying Performance Obligations and Licensing,” and ASU 2016-12, “Narrow-Scope Improvements and Practical Expedients.” These standards provide 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. Early adoption as of January 1, 2017 is permitted; however, we do not intend to adopt early. The standard allows for either full retrospective adoption or modified retrospective adoption. We are currently evaluating the impact of the standard on our financial statements and related disclosures. Based on our initial evaluation, the adoption of the standard is not expected to have a material impact on the amount or timing of revenue recognized.

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. We adopted this guidance using the modified retrospective approach as of January 1, 2016 and performed the required reassessments outlined by the guidance. For further information on the results of the reassessments, refer to Note 4, Investments - Equity Method and Joint Ventures.

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 December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. We adopted this guidance as of January 1, 2016, with no impact to our financial statements.

LEASES.In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”), which improves transparency and comparability among organizations by requiring lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires 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.

SHARE-BASED COMPENSATION. In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”), which simplifies several aspects of the accounting for employee share-based payment transactions including accounting for income taxes, cash flow presentation of tax impacts, forfeitures, and liability versus equity accounting due to statutory tax withholding requirements. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. As of January 1, 2016, we early adopted ASU 2016-09 and with respect to the guidance on forfeitures, we have elected to continue to estimate forfeitures on the date of grant to account for the estimated number of awards for which the requisite service period will not be rendered. The adoption of ASU 2016-09 had no impact on our financial statements.

STATEMENT OF CASH FLOWS. In August 2016, the FASB issued ASU 2016-15, “Clarification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”), which eliminates the diversity in practice related to the classification of certain cash receipts and payments in the statement of cash flows, by adding or clarifying guidance on eight specific cash flow issues. ASU 2016-15 is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. The amendments in this update should be applied retrospectively to all periods presented, unless deemed impracticable, in which case, prospective application is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements.

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Related-Party Transactions Related-Party Transactions (Notes)

9 Months Ended

Sep. 30, 2016

Related Party Transactions [Abstract]

Related Party Transactions Disclosure

RELATED-PARTY TRANSACTIONS

ACQUISITIONS

ALASKA STORAGE AND TERMINALLING ASSETS PURCHASE.  Effective July 1, 2016, the Partnership entered into an agreement to purchase certain terminalling and storage assets owned by Tesoro for total consideration of $444 million and was completed in two phases. On July 1, 2016, the Partnership completed the acquisition of the first phase consisting of tankage with a shell capacity of approximately 3.5 million barrels, related equipment and ancillary facilities used for the operations at Tesoro’s Kenai Refinery. The second phase was completed on September 16, 2016 and consisted of refined product terminals in Anchorage and Fairbanks (together, the “Alaska Storage and Terminalling Assets”). Consideration paid for the first phase was $266 million, comprised of approximately $240 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $26 million. Consideration paid for the second phase was $178 million, comprised of approximately $160 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $18 million.

AFFILIATE AGREEMENTS

The Partnership has various long-term, fee-based commercial agreements with Tesoro, under which we provide pipeline transportation, trucking, terminal distribution and storage services to Tesoro, and Tesoro typically commits to fixed fees or to provide us with minimum monthly throughput volumes of crude oil and refined products. For the natural gas liquids 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.

In addition, we have agreements for the provision of various general and administrative services by Tesoro. Under our partnership agreement, we are required to reimburse TLGP and its affiliates for all costs and expenses that they incur on our behalf for managing and controlling our business and operations. Except to the extent specified under our amended omnibus agreement (the “Amended Omnibus Agreement”) or our secondment agreement (the “Secondment Agreement”), TLGP determines the amount of these expenses. The Amended Omnibus Agreement and the Secondment Agreement were amended and restated in connection with the Alaska Storage and Terminalling Assets purchase. Under the terms of the Amended Omnibus Agreement as of September 30, 2016, we are required to pay Tesoro an annual corporate services fee of $10 million for the provision of various centralized corporate services, including executive management, legal, accounting, treasury, human resources, health, safety and environmental, information technology, certain insurance coverage, administration and other corporate services. Under the terms of our Secondment Agreement as of September 30, 2016, we pay Tesoro a net annual service fee of $2 millionfor services performed by field-level employees at the majority of our facilities. Additionally, pursuant to the Amended Omnibus Agreement and Secondment Agreement, we reimburse Tesoro for any direct costs actually incurred by Tesoro in providing other operational services with respect to certain of our other assets and operations.

SUMMARY OF AFFILIATE TRANSACTIONS

SUMMARY OF REVENUE AND EXPENSE TRANSACTIONS WITH TESORO (in millions)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues (a)	$	184	$	152	$	521	$	454
Operating expenses	40		33		113		93
Imbalance settlement gains and reimbursements from Tesoro (b)	5		12		17		31
General and administrative expenses	18		16		51		51

(a) Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

(b) Includes imbalance settlement gains of $2 million and for both the three months ended September 30, 2016 and 2015, and $5 million and $6 million for the nine months ended September 30, 2016 and 2015, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $3 million and $10 million for the three months ended September 30, 2016 and 2015, respectively, and $12 million and $25 million for the nine months ended September 30, 2016 and 2015, respectively.

PREDECESSOR TRANSACTIONS. Related-party transactions of our Predecessors were settled through equity. Our Predecessors did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment.

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. During the nine months ended September 30, 2016, we paid quarterly cash distributions of $175 million to Tesoro and TLGP, including incentive distribution rights (“IDRs”). On October 18, 2016, we declared a quarterly cash distribution of $0.875 per unit, which will be paid on November 14, 2016. The distribution will include payments of $71 million to Tesoro and TLGP, including IDRs.

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Property, Plant and Equipment (Notes)

9 Months Ended

Sep. 30, 2016

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT BY SEGMENT, AT COST (in millions)

	September 30, 2016			December 31, 2015
Gathering (a)	$	1,379		$	1,700
Processing	573			565
Terminalling and Transportation (b)	1,690			1,629
Property, Plant and Equipment, at Cost	3,642			3,894
Accumulated depreciation (a) (b)	(513		)	(427		)
Property, Plant and Equipment, Net	$	3,129		$	3,467

(a) We recognized a decrease of $363 million to net property, plant and equipment as of January 1, 2016 as a result of the deconsolidation of RGS. See Note 4 for further discussion of the deconsolidation of RGS.

(b) Property, plant and equipment transferred to the Partnership in the Alaska Storage and Terminalling Assets acquisition was recorded at historical costs. TLLP recorded property, plant and equipment of $77 million and $47 million as of September 30, 2016 and December 31, 2015, respectively, and accumulated depreciation of $30 million for both September 30, 2016 and December 31, 2015.

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Investments - Equity Method and Joint Ventures Investments - Equity Method and Joint Ventures (Notes)

9 Months Ended

Sep. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments and Joint Ventures

INVESTMENTS - EQUITY METHOD AND JOINT VENTURES

For each of the following investments, we have the ability to exercise significant influence over each of these investments through our participation in the management committees, which make all significant decisions. However, since we have equal or proportionate influence over each committee as a joint interest partner and all significant decisions require consent of the other investor(s) without regard to our economic interest, we have determined that these entities should not be consolidated and apply the equity method of accounting with respect to our investments in each entity.

• RGS. We have a 78% interest in RGS, which owns and operates the infrastructure that transports gas from certain fields to several re-delivery points in southwestern Wyoming, including natural gas processing facilities that are owned by us or a third party. Prior to 2016, we consolidated RGS, however, upon our reassessment performed in conjunction with the adoption of ASU 2015-02 as of January 1, 2016, we determined RGS represents a variable interest entity to us for which we are not the primary beneficiary. Under the limited liability company agreement, we do not have voting rights commensurate with our economic interest due to veto rights available to our partner in RGS. Certain business decisions, including, but not limited to, decisions with respect to significant expenditures or contractual commitments, annual budgets, material financings, dispositions of assets or amending the members’ gas servicing agreements, require unanimous approval of the members. For amounts previously consolidated in our financial statements as of and for the year ended December 31, 2015, refer to the amounts shown in the Non-Guarantor column in the condensed consolidating financial information presented in Note 16 in our annual report on Form 10-K referenced herein.

• THREE RIVERS GATHERING, LLC (“TRG”). We own a 50% interest in TRG which operates natural gas gathering assets within the southeastern Uinta Basin and is primarily supported by long-term, fee-based gas gathering agreements with minimum volume commitments.

• UINTAH BASIN FIELD SERVICES, L.L.C. (“UBFS”). We own a 38% interest in UBFS which owns and operates the natural gas gathering infrastructure located in the southeastern Uinta Basin and is supported by long-term, fee-based gas gathering agreements that contain firm throughput commitments, which generate fees whether or not the capacity is used, and is operated by us.

EQUITY METHOD INVESTMENTS (in millions)

	RGS			TRG			UBFS			Total
Balance at December 31, 2015	$	—		$	42		$	16		$	58
Effect of deconsolidation (a)	295			—			—			295
Equity in earnings	6			2			2			10
Distributions received	(16		)	(3		)	(2		)	(21		)
Balance at September 30, 2016	$	285		$	41		$	16		$	342

(a) We recognized an increase of $295 million to equity method investments as of January 1, 2016 as a result of the deconsolidation of RGS in addition to a cumulative effect reduction to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods. The carrying amount of our investment in RGS exceeded the underlying equity in net assets by $137 million at September 30, 2016.

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Debt (Notes)

9 Months Ended

Sep. 30, 2016

Debt Disclosure [Abstract]

Debt

DEBT

DEBT BALANCE, NET OF UNAMORTIZED ISSUANCE COSTS (in millions)

	September 30, 2016			December 31, 2015
Total debt	$	3,428		$	2,883
Unamortized issuance costs (a)	(46		)	(39		)
Debt, Net of Unamortized Issuance Costs	$	3,382		$	2,844

(a) Includes unamortized premiums of $4 million associated with our senior notes at both September 30, 2016 and December 31, 2015.

REVOLVING CREDIT FACILITY AND DROPDOWN CREDIT FACILITY

AVAILABLE CAPACITY UNDER CREDIT FACILITIES (in millions)

	Total Capacity		Amount Borrowed as of September 30, 2016		Outstanding Letters of Credit		Available Capacity		Expiration
TLLP Revolving Credit Facility	$	600	$	—	$	—	$	600	January 29, 2021
TLLP Dropdown Credit Facility	1,000		400		—		600		January 29, 2021
Total Credit Facilities	$	1,600	$	400	$	—	$	1,200

We amended our existing secured Revolving Credit Facility on January 29, 2016, decreasing the aggregate available facility limit from $900 million to $600 million and revised terms related to pricing and financial covenants. As a result of this amendment, an immaterial amount of unamortized debt issuance costs were expensed. In addition, we syndicated a $1.0 billion secured Dropdown Credit Facility on January 29, 2016. The primary use of proceeds under this facility will be to fund asset acquisitions. The terms, covenants and restrictions under this facility are substantially the same as with our amended secured Revolving Credit Facility. The total aggregate available facility limits for the secured Revolving Credit Facility and secured Dropdown Credit Facility totaled$1.6 billion at September 30, 2016. We are allowed to request the loan availability for both the secured Revolving Credit Facility and the secured Dropdown Credit Facility be increased up to an aggregate of $2.1 billion, subject to receiving increased commitments from the lenders.

As of September 30, 2016, our secured Revolving Credit Facility provided for total loan availability of $600 million. Borrowings are available under the secured Revolving Credit Facility up to the total loan availability of the facility. Our secured Revolving Credit Facility is non-recourse to Tesoro, except for TLGP, and is guaranteed by all of our consolidated subsidiaries, and secured by substantially all of our assets. We hadno borrowings outstanding under the secured Revolving Credit Facility, resulting in the full loan availability of the borrowing capacity as of September 30, 2016.

As of September 30, 2016, our secured Dropdown Credit Facility provided for total loan availability of $1.0 billion. We had $400 million borrowings outstanding under the secured Dropdown Credit Facility, resulting in unused loan availability of $600 million or 60% the borrowing capacity as of September 30, 2016. The weighted average interest rate for borrowings under our secured Dropdown Credit Facility was 2.54% at September 30, 2016.

The secured Revolving Credit Facility and the secured Dropdown Credit Facility ratably share collateral comprised primarily of our property, plant, and equipment and both facilities mature on January 29, 2021. In addition, upon an upgrade of our corporate family rating to investment grade from either Moody's Investors Service or S&P Global Ratings, certain covenants and restrictions under each facility will automatically be eliminated or improved.

SENIOR NOTES ISSUANCE

On May 9, 2016, we completed a registered offering of $250 million aggregate principal amount of 6.125% Senior Notes due 2021 (“2021 Notes”) and $450 million aggregate principal amount of 6.375% Senior Notes due 2024 (“2024 Notes”). We used the proceeds of the offering of the 2021 notes to repay amounts outstanding under our Dropdown Credit Facility and the proceeds of the offering of the 2024 notes to repay amounts outstanding under our Revolving Credit Facility and for general partnership purposes.

The 2021 Notes were issued under the same indenture governing the existing $550 million of the 6.125% Senior Notes due 2021 issued in August 2013 and have the same terms as those senior notes. The 2021 Notes have no sinking fund requirements. The 2021 Notes may be redeemed at premiums equal to 4.594% through October 15, 2017; 3.063% from October 15, 2017 through October 15, 2018; 1.531% from October 15, 2018 through October 15, 2019; and at par thereafter, plus accrued and unpaid interest. The 2021 Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

The 2024 Notes have no sinking fund requirements. We may redeem some or all of the 2024 Notes, prior to May 1, 2019, at a make-whole price plus accrued and unpaid interest, if any. On or after May 1, 2019, the 2024 Notes may be redeemed at premiums equal to  4.781% through May 1, 2020; 3.188% from May 1, 2020 through May 1, 2021; 1.594% from May 1, 2021 through May 1, 2022; and at par thereafter, plus accrued and unpaid interest. We will have the right to redeem up to 35% of the aggregate principal amount at 106.375% face value with proceeds from certain equity issuances through May 1, 2019. The 2024 Notes are unsecured and guaranteed by all of our subsidiaries, except Tesoro Logistics Finance Corp., the co-issuer, and are non-recourse to Tesoro, except for TLGP, and contain customary terms, events of default and covenants for an issuance of non-investment grade securities.

DEBT REPAYMENTS

On February 3, 2016, we paid the full amount of the Unsecured Term Loan Facility, including accrued interest, with proceeds drawn from the secured Dropdown Credit Facility. All commitments under the Unsecured Term Loan Facility were terminated effective with the repayment and an immaterial amount of unamortized debt issuance costs were expensed.

SENIOR NOTES EXCHANGE

On February 26, 2016, the Partnership commenced an offer to exchange (the “Exchange”) its existing unregistered 5.50% Senior Notes due 2019 (“2019 Notes”) and 6.25% Senior Notes due 2022 (“2022 Notes”) (together, “Unregistered Notes”) for an equal principal amount of 5.50% Senior Notes due 2019 and 6.25% Senior Notes due 2022 (the “Exchange Notes”), respectively, that were registered under the Securities Act of 1933, as amended. On April 14, 2016, the Exchange was completed for all of the 2019 Notes and substantially all of the 2022 Notes. The terms of the Exchange Notes are identical in all material respects (including principal amount, interest rate, maturity and redemption rights) to the Unregistered Notes for which they were exchanged, except that the Exchange Notes generally are not subject to transfer restrictions. The Exchange fulfills all of the requirements of the registration rights agreements for the Unregistered Notes.

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Commitments and Contingencies (Notes)

9 Months Ended

Sep. 30, 2016

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 known 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, 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. Environmental matters discovered subsequent to the Initial Offering and subsequent acquisitions are also indemnified to the extent they are identified prior to five years from the acquisition date. The indemnification under the Initial Offering for unknown environmental matters expired on April 26, 2016. See Note 3 of our Annual Report on Form 10-K for the year ended December 31, 2015, 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 contingencies cannot always be predicted accurately, but we will accrue liabilities for these matters if the amount is probable and can be reasonably estimated. Contingencies arising after the closing of the Initial Offering from conditions existing before the Initial Offering, and the subsequent acquisitions from Tesoro that have been identified after the closing of each transaction, will be recorded in accordance with the indemnification terms set forth in the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement, as noted above. Any contingencies arising from events after the Initial Offering, and the subsequent acquisitions from Tesoro, will be our responsibility. Other than described in this Note 6, we do not have any other material outstanding lawsuits, administrative proceedings or governmental investigations.

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 liabilities for these environmental expenditures totaled $18 million and $33 million at September 30, 2016 and December 31, 2015, 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. 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, we have received all insurance recoveries related to the Crude Oil Pipeline Release as of December 31, 2015. The estimated remediation costs of $66 million exceeded our policy loss limit by $41 million. We had remaining liabilities totaling $13 million and $27 million at September 30, 2016 and December 31, 2015, respectively.

LEGAL

QUESTAR GAS COMPANY V. QEP FIELD SERVICES COMPANY. Prior to the acquisition of all of the limited liability company interests of QEPFS, 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 agreed to indemnify QEP Field Services Company for this claim under the acquisition agreement for QEPFS. Under the 1993 Agreement, certain of TLLP’s systems provide gathering services to QGC charging an annual gathering rate, which is based on the cost of service calculation. QGC disputed the annual calculation of the gathering rate, which has been calculated in the same manner since 1998, without objection by QGC. As a result of the rulings through the date of our acquisition of QEPFS, TLLP assumed a $21 million liability for estimated damages. On March 22, 2016, the parties in this dispute entered into a settlement and release agreement resolving all remaining issues and associated counter claims in exchange for TLLP’s payment of $15 million. We recognized a gain of $6 million in other income, net on our condensed statement of consolidated operations for the nine months ended September 30, 2016 as a result of the settlement.

XTO ENERGY INC. V. QEP FIELD SERVICES COMPANY.XTO filed a complaint on January 30, 2014, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, unjust enrichment and an accounting and declaratory judgment related to a 2010 gas processing agreement (the “XTO Agreement”). TLLP processes XTO’s natural gas on a firm basis under the XTO Agreement. The XTO Agreement requires TLLP to transport, fractionate and market XTO’s natural gas liquids derived from XTO’s processed gas. XTO is seeking monetary damages related to TLLP’s 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. On March 29, 2016, the parties entered into a settlement and release agreement related to payments withheld by XTO unrelated to the allocation of charges they are challenging. Under the settlement and release agreement, XTO agreed to pay all historical undisputed charges by April 15, 2016 less the allocated charges they are challenging, $29 million at September 30, 2016, and to thereafter tender all similar undisputed charges timely. On April 15, 2016, XTO remitted a $21 million settlement payment related to all undisputed amounts. While we cannot currently estimate the final amount or timing of the resolution of this matter and the disputed amounts, we believe the outcome will not have a material impact on our liquidity, financial position or results of operations.

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Equity (Notes)

9 Months Ended

Sep. 30, 2016

Equity [Abstract]

Equity

EQUITY AND NET EARNINGS PER UNIT

We had 68,901,930 common public units outstanding as of September 30, 2016. Additionally, Tesoro owned 33,194,109 of our common units and 2,083,330 of our general partner units (the 2.0% general partner interest) as of September 30, 2016, which together constitutes a 34% ownership interest.

UNIT ISSUANCE.We closed a registered public offering of 6,325,000 common units representing limited partner interests, including the over-allotment option exercised by the underwriter for the purchase of an additional 825,000 common units, at a public offering price of $47.13 per unit on June 10, 2016. The net proceeds of $293 million are expected to be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

ATM PROGRAM.On August 24, 2015, we filed a prospectus supplement to our shelf registration statement filed with the SEC 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 “ATM Program”). During the three and nine months ended September 30, 2016, we issued an aggregate of 655,940 and 1,492,637 common units, respectively, under our ATM Program, generating proceeds of approximately $31 million and $72 million, respectively, before issuance costs. The net proceeds from sales under the ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

CHANGE IN THE CARRYING AMOUNT OF OUR EQUITY (in millions)

				Partnership
	Equity of Predecessors (a)			Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2015	$	16		$	1,707		$	(13	)	$	84		$	1,794
Sponsor contributions of equity to the Predecessors	34			—			—			—			34
Loss attributable to the Predecessors	(4		)	—			—			—			(4		)
Allocation of net assets acquired by the unitholders (b)	(46		)	40			6			—			—
Equity offering under ATM Program, net of issuance costs	—			71			—			—			71
Proceeds from issuance of units, net of issuance costs	—			293			—			—			293
Effect of deconsolidation of RGS (c)	—			(2		)	—			(84		)	(86		)
Quarterly distributions to unitholders and general partner(d)	—			(234		)	(95		)	—			(329		)
Distributions to unitholders and general partner related to acquisitions (b)	—			(321		)	(79		)	—			(400		)
Net earnings attributable to partners	—			154			109			—			263
Contributions (e)	—			17			2			—			19
Other	—			4			4			—			8
Balance at September 30, 2016	$	—		$	1,729		$	(66	)	$	—		$	1,663

(a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

(b) Distributions to unitholders and general partner include $400 million in cash payments for the Alaska Storage and Terminalling Assets acquisition from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesoro’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net decrease of $354 million in our equity balance during the nine months ended September 30, 2016.

(c) As a result of the reassessment performed, we deconsolidated RGS causing the derecognition of noncontrolling interest and an opening equity impact totaling $86 million. The cumulative effect to opening equity of$2 million related to the difference in earnings under the equity method of accounting in prior periods.

(d) Represents cash distributions declared and paid during the nine months ended September 30, 2016 relating to the fourth quarter of 2015 through the second quarter of 2016.

(e) 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.

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, 2016, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the common 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 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. Distributions less than or greater than earnings are allocated in accordance with our partnership agreement.

NET EARNINGS PER UNIT (in millions, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Net earnings	$	87		$	71		$	259		$	206
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Special allocations of net earnings (“Special Allocations”) (a)	2			—			2			—
Net earnings, excluding noncontrolling interest and including Special Allocations	89			68			261			187
General partner’s distributions	(3		)	(1		)	(7		)	(4		)
General partner’s IDRs (b)	(39		)	(19		)	(105		)	(47		)
Limited partners’ distributions on common units	(89		)	(66		)	(250		)	(186		)
Distributions greater than earnings	$	(42	)	$	(18	)	$	(101	)	$	(50	)
General partner’s earnings:
Distributions	$	3		$	1		$	7		$	4
General partner’s IDRs (b)	39			19			105			47
Allocation of distributions greater than earnings (c)	(2		)	(6		)	(6		)	(17		)
Total general partner’s earnings	$	40		$	14		$	106		$	34
Limited partners’ earnings on common units:
Distributions	$	89		$	66		$	250		$	186
Special Allocations (a)	(2		)	—			(2		)	—
Allocation of distributions greater than earnings	(40		)	(12		)	(95		)	(33		)
Total limited partners’ earnings on common units	$	47		$	54		$	153		$	153
Weighted average limited partner units outstanding:
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6
Net earnings per limited partner unit:
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85

(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 common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the Alaska Storage and Terminalling Assets acquisition during the three and nine months ended September 30, 2016.

(b) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $3 million and $8 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2015, for further discussion related to IDRs.

(c) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $1 million and$4 million for the three and nine months ended September 30, 2016, respectively, and $6 million and$17 million for the three and nine months ended September 30, 2015, respectively.

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

QUARTERLY DISTRIBUTIONS

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2015	$	0.780	$	98	February 12, 2016	February 2, 2016
March 31, 2016	0.810		108		May 13, 2016	May 2, 2016
June 30, 2016	0.842		123		August 12, 2016	August 2, 2016
September 30, 2016 (a)	0.875		131		November 14, 2016	November 4, 2016

(a) This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

Earnings Per Share

EQUITY AND NET EARNINGS PER UNIT

We had 68,901,930 common public units outstanding as of September 30, 2016. Additionally, Tesoro owned 33,194,109 of our common units and 2,083,330 of our general partner units (the 2.0% general partner interest) as of September 30, 2016, which together constitutes a 34% ownership interest.

UNIT ISSUANCE.We closed a registered public offering of 6,325,000 common units representing limited partner interests, including the over-allotment option exercised by the underwriter for the purchase of an additional 825,000 common units, at a public offering price of $47.13 per unit on June 10, 2016. The net proceeds of $293 million are expected to be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

ATM PROGRAM.On August 24, 2015, we filed a prospectus supplement to our shelf registration statement filed with the SEC 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 “ATM Program”). During the three and nine months ended September 30, 2016, we issued an aggregate of 655,940 and 1,492,637 common units, respectively, under our ATM Program, generating proceeds of approximately $31 million and $72 million, respectively, before issuance costs. The net proceeds from sales under the ATM Program will be used for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital.

CHANGE IN THE CARRYING AMOUNT OF OUR EQUITY (in millions)

				Partnership
	Equity of Predecessors (a)			Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2015	$	16		$	1,707		$	(13	)	$	84		$	1,794
Sponsor contributions of equity to the Predecessors	34			—			—			—			34
Loss attributable to the Predecessors	(4		)	—			—			—			(4		)
Allocation of net assets acquired by the unitholders (b)	(46		)	40			6			—			—
Equity offering under ATM Program, net of issuance costs	—			71			—			—			71
Proceeds from issuance of units, net of issuance costs	—			293			—			—			293
Effect of deconsolidation of RGS (c)	—			(2		)	—			(84		)	(86		)
Quarterly distributions to unitholders and general partner(d)	—			(234		)	(95		)	—			(329		)
Distributions to unitholders and general partner related to acquisitions (b)	—			(321		)	(79		)	—			(400		)
Net earnings attributable to partners	—			154			109			—			263
Contributions (e)	—			17			2			—			19
Other	—			4			4			—			8
Balance at September 30, 2016	$	—		$	1,729		$	(66	)	$	—		$	1,663

(a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

(b) Distributions to unitholders and general partner include $400 million in cash payments for the Alaska Storage and Terminalling Assets acquisition from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesoro’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net decrease of $354 million in our equity balance during the nine months ended September 30, 2016.

(c) As a result of the reassessment performed, we deconsolidated RGS causing the derecognition of noncontrolling interest and an opening equity impact totaling $86 million. The cumulative effect to opening equity of$2 million related to the difference in earnings under the equity method of accounting in prior periods.

(d) Represents cash distributions declared and paid during the nine months ended September 30, 2016 relating to the fourth quarter of 2015 through the second quarter of 2016.

(e) 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.

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, 2016, our participating securities consist of common units, general partner units and IDRs. Net earnings earned by the Partnership are allocated between the common 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 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. Distributions less than or greater than earnings are allocated in accordance with our partnership agreement.

NET EARNINGS PER UNIT (in millions, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Net earnings	$	87		$	71		$	259		$	206
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Special allocations of net earnings (“Special Allocations”) (a)	2			—			2			—
Net earnings, excluding noncontrolling interest and including Special Allocations	89			68			261			187
General partner’s distributions	(3		)	(1		)	(7		)	(4		)
General partner’s IDRs (b)	(39		)	(19		)	(105		)	(47		)
Limited partners’ distributions on common units	(89		)	(66		)	(250		)	(186		)
Distributions greater than earnings	$	(42	)	$	(18	)	$	(101	)	$	(50	)
General partner’s earnings:
Distributions	$	3		$	1		$	7		$	4
General partner’s IDRs (b)	39			19			105			47
Allocation of distributions greater than earnings (c)	(2		)	(6		)	(6		)	(17		)
Total general partner’s earnings	$	40		$	14		$	106		$	34
Limited partners’ earnings on common units:
Distributions	$	89		$	66		$	250		$	186
Special Allocations (a)	(2		)	—			(2		)	—
Allocation of distributions greater than earnings	(40		)	(12		)	(95		)	(33		)
Total limited partners’ earnings on common units	$	47		$	54		$	153		$	153
Weighted average limited partner units outstanding:
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6
Net earnings per limited partner unit:
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85

(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 common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the Alaska Storage and Terminalling Assets acquisition during the three and nine months ended September 30, 2016.

(b) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $3 million and $8 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2015, for further discussion related to IDRs.

(c) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $1 million and$4 million for the three and nine months ended September 30, 2016, respectively, and $6 million and$17 million for the three and nine months ended September 30, 2015, respectively.

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

QUARTERLY DISTRIBUTIONS

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2015	$	0.780	$	98	February 12, 2016	February 2, 2016
March 31, 2016	0.810		108		May 13, 2016	May 2, 2016
June 30, 2016	0.842		123		August 12, 2016	August 2, 2016
September 30, 2016 (a)	0.875		131		November 14, 2016	November 4, 2016

(a) This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

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Operating Segments (Notes)

9 Months Ended

Sep. 30, 2016

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

Segment Disclosures

OPERATING SEGMENTS

Our revenues are derived from three operating segments: Gathering, Processing and Terminalling and Transportation. Our Gathering segment consists of crude oil and natural gas gathering systems in the Bakken Shale/Williston Basin area of North Dakota and Montana and the Green River Basin, Uinta Basin and Vermillion Basin in the states of Utah, Colorado and Wyoming. Our Processing segment consists of four gas processing complexes and one fractionation facility. Our Terminalling and Transportation segment consists of crude oil and refined products terminals and marine terminals, storage facilities for crude oil, refined products and petroleum coke handling, rail-car unloading facilities and pipelines, which transport products and crude oil.

Our revenues are generated from third-party contracts and from commercial agreements we have entered into with Tesoro, under which customers pay 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, 2015. 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 are excluded from segment operating income as they are not directly attributable to a specific operating segment.

SEGMENT INFORMATION (in millions)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Revenues
Gathering:
Affiliate	$	21		$	18		$	61		$	71
Third-party	61			69			194			182
Total Gathering	82			87			255			253
Processing:
Affiliate	23			26			74			71
Third-party	46			45			134			134
Total Processing	69			71			208			205
Terminalling and Transportation:
Affiliate	140			108			386			312
Third-party	17			16			52			50
Total Terminalling and Transportation	157			124			438			362
Total Segment Revenues	$	308		$	282		$	901		$	820
Segment Operating Income
Gathering	$	31		$	42		$	107		$	121
Processing	29			29			85			77
Terminalling and Transportation	85			51			226			157
Total Segment Operating Income	145			122			418			355
Unallocated general and administrative expenses	(12		)	(16		)	(37		)	(43		)
Interest and financing costs, net	(49		)	(37		)	(138		)	(112		)
Equity in earnings of equity method investments	3			2			10			6
Other income, net	—			—			6			—
Net Earnings	$	87		$	71		$	259		$	206
Capital Expenditures
Gathering	$	21		$	72		$	67		$	177
Processing	2			5			15			10
Terminalling and Transportation	19			16			43			50
Total Capital Expenditures	$	42		$	93		$	125		$	237

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Organization and Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2016

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”), and has since amended the standard with ASU 2015-14, “Deferral of the Effective Date,” ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU 2016-10, “Identifying Performance Obligations and Licensing,” and ASU 2016-12, “Narrow-Scope Improvements and Practical Expedients.” These standards provide 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. Early adoption as of January 1, 2017 is permitted; however, we do not intend to adopt early. The standard allows for either full retrospective adoption or modified retrospective adoption. We are currently evaluating the impact of the standard on our financial statements and related disclosures. Based on our initial evaluation, the adoption of the standard is not expected to have a material impact on the amount or timing of revenue recognized.

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. We adopted this guidance using the modified retrospective approach as of January 1, 2016 and performed the required reassessments outlined by the guidance. For further information on the results of the reassessments, refer to Note 4, Investments - Equity Method and Joint Ventures.

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 December 15, 2015 and must be applied prospectively to adjustments that occur after the effective date. We adopted this guidance as of January 1, 2016, with no impact to our financial statements.

LEASES.In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”), which improves transparency and comparability among organizations by requiring lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires 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.

SHARE-BASED COMPENSATION. In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”), which simplifies several aspects of the accounting for employee share-based payment transactions including accounting for income taxes, cash flow presentation of tax impacts, forfeitures, and liability versus equity accounting due to statutory tax withholding requirements. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. As of January 1, 2016, we early adopted ASU 2016-09 and with respect to the guidance on forfeitures, we have elected to continue to estimate forfeitures on the date of grant to account for the estimated number of awards for which the requisite service period will not be rendered. The adoption of ASU 2016-09 had no impact on our financial statements.

STATEMENT OF CASH FLOWS. In August 2016, the FASB issued ASU 2016-15, “Clarification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”), which eliminates the diversity in practice related to the classification of certain cash receipts and payments in the statement of cash flows, by adding or clarifying guidance on eight specific cash flow issues. ASU 2016-15 is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. The amendments in this update should be applied retrospectively to all periods presented, unless deemed impracticable, in which case, prospective application is permitted. At this time, we are evaluating the potential impact of this standard on our financial statements.

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Equity Earnings Per Unit (Policies)

9 Months Ended

Sep. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Share, Policy [Policy Text Block]

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.

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Related-Party Transactions Related-Party Transactions (Tables)

9 Months Ended

Sep. 30, 2016

Related Party Transaction

Schedule of Related Party Transactions

SUMMARY OF REVENUE AND EXPENSE TRANSACTIONS WITH TESORO (in millions)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
Revenues (a)	$	184	$	152	$	521	$	454
Operating expenses	40		33		113		93
Imbalance settlement gains and reimbursements from Tesoro (b)	5		12		17		31
General and administrative expenses	18		16		51		51

(a) Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

(b) Includes imbalance settlement gains of $2 million and for both the three months ended September 30, 2016 and 2015, and $5 million and $6 million for the nine months ended September 30, 2016 and 2015, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $3 million and $10 million for the three months ended September 30, 2016 and 2015, respectively, and $12 million and $25 million for the nine months ended September 30, 2016 and 2015, respectively.

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2016

Property, Plant and Equipment [Abstract]

Property, plant and equipment

PROPERTY, PLANT AND EQUIPMENT BY SEGMENT, AT COST (in millions)

	September 30, 2016			December 31, 2015
Gathering (a)	$	1,379		$	1,700
Processing	573			565
Terminalling and Transportation (b)	1,690			1,629
Property, Plant and Equipment, at Cost	3,642			3,894
Accumulated depreciation (a) (b)	(513		)	(427		)
Property, Plant and Equipment, Net	$	3,129		$	3,467

(a) We recognized a decrease of $363 million to net property, plant and equipment as of January 1, 2016 as a result of the deconsolidation of RGS. See Note 4 for further discussion of the deconsolidation of RGS.

(b) Property, plant and equipment transferred to the Partnership in the Alaska Storage and Terminalling Assets acquisition was recorded at historical costs. TLLP recorded property, plant and equipment of $77 million and $47 million as of September 30, 2016 and December 31, 2015, respectively, and accumulated depreciation of $30 million for both September 30, 2016 and December 31, 2015.

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Investments - Equity Method and Joint Ventures Investments - Equity Method and Joint Ventures(Tables)

9 Months Ended

Sep. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

EQUITY METHOD INVESTMENTS (in millions)

	RGS			TRG			UBFS			Total
Balance at December 31, 2015	$	—		$	42		$	16		$	58
Effect of deconsolidation (a)	295			—			—			295
Equity in earnings	6			2			2			10
Distributions received	(16		)	(3		)	(2		)	(21		)
Balance at September 30, 2016	$	285		$	41		$	16		$	342

(a) We recognized an increase of $295 million to equity method investments as of January 1, 2016 as a result of the deconsolidation of RGS in addition to a cumulative effect reduction to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods. The carrying amount of our investment in RGS exceeded the underlying equity in net assets by $137 million at September 30, 2016.

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Debt (Tables)

9 Months Ended

Sep. 30, 2016

Line of Credit Facility [Line Items]

Schedule of Line of Credit Facilities [Table Text Block]

AVAILABLE CAPACITY UNDER CREDIT FACILITIES (in millions)

	Total Capacity		Amount Borrowed as of September 30, 2016		Outstanding Letters of Credit		Available Capacity		Expiration
TLLP Revolving Credit Facility	$	600	$	—	$	—	$	600	January 29, 2021
TLLP Dropdown Credit Facility	1,000		400		—		600		January 29, 2021
Total Credit Facilities	$	1,600	$	400	$	—	$	1,200

Schedule of Debt

DEBT BALANCE, NET OF UNAMORTIZED ISSUANCE COSTS (in millions)

	September 30, 2016			December 31, 2015
Total debt	$	3,428		$	2,883
Unamortized issuance costs (a)	(46		)	(39		)
Debt, Net of Unamortized Issuance Costs	$	3,382		$	2,844

(a) Includes unamortized premiums of $4 million associated with our senior notes at both September 30, 2016 and December 31, 2015.

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Equity (Tables)

9 Months Ended

Sep. 30, 2016

Equity [Abstract]

Schedule of partners' capital

CHANGE IN THE CARRYING AMOUNT OF OUR EQUITY (in millions)

				Partnership
	Equity of Predecessors (a)			Common			General Partner			Noncontrolling Interest			Total
Balance at December 31, 2015	$	16		$	1,707		$	(13	)	$	84		$	1,794
Sponsor contributions of equity to the Predecessors	34			—			—			—			34
Loss attributable to the Predecessors	(4		)	—			—			—			(4		)
Allocation of net assets acquired by the unitholders (b)	(46		)	40			6			—			—
Equity offering under ATM Program, net of issuance costs	—			71			—			—			71
Proceeds from issuance of units, net of issuance costs	—			293			—			—			293
Effect of deconsolidation of RGS (c)	—			(2		)	—			(84		)	(86		)
Quarterly distributions to unitholders and general partner(d)	—			(234		)	(95		)	—			(329		)
Distributions to unitholders and general partner related to acquisitions (b)	—			(321		)	(79		)	—			(400		)
Net earnings attributable to partners	—			154			109			—			263
Contributions (e)	—			17			2			—			19
Other	—			4			4			—			8
Balance at September 30, 2016	$	—		$	1,729		$	(66	)	$	—		$	1,663

(a) Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

(b) Distributions to unitholders and general partner include $400 million in cash payments for the Alaska Storage and Terminalling Assets acquisition from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesoro’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net decrease of $354 million in our equity balance during the nine months ended September 30, 2016.

(c) As a result of the reassessment performed, we deconsolidated RGS causing the derecognition of noncontrolling interest and an opening equity impact totaling $86 million. The cumulative effect to opening equity of$2 million related to the difference in earnings under the equity method of accounting in prior periods.

(d) Represents cash distributions declared and paid during the nine months ended September 30, 2016 relating to the fourth quarter of 2015 through the second quarter of 2016.

(e) 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.

Schedule of quarterly distributions

QUARTERLY DISTRIBUTIONS

Quarter Ended	Quarterly Distribution Per Unit		Total Cash Distribution including general partner IDRs (in millions)		Date of Distribution	Unitholders Record Date
December 31, 2015	$	0.780	$	98	February 12, 2016	February 2, 2016
March 31, 2016	0.810		108		May 13, 2016	May 2, 2016
June 30, 2016	0.842		123		August 12, 2016	August 2, 2016
September 30, 2016 (a)	0.875		131		November 14, 2016	November 4, 2016

(a) This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

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Equity Net Earnings per Unit (Tables)

9 Months Ended

Sep. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

NET EARNINGS PER UNIT (in millions, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Net earnings	$	87		$	71		$	259		$	206
Net earnings attributable to noncontrolling interest	—			(3		)	—			(19		)
Special allocations of net earnings (“Special Allocations”) (a)	2			—			2			—
Net earnings, excluding noncontrolling interest and including Special Allocations	89			68			261			187
General partner’s distributions	(3		)	(1		)	(7		)	(4		)
General partner’s IDRs (b)	(39		)	(19		)	(105		)	(47		)
Limited partners’ distributions on common units	(89		)	(66		)	(250		)	(186		)
Distributions greater than earnings	$	(42	)	$	(18	)	$	(101	)	$	(50	)
General partner’s earnings:
Distributions	$	3		$	1		$	7		$	4
General partner’s IDRs (b)	39			19			105			47
Allocation of distributions greater than earnings (c)	(2		)	(6		)	(6		)	(17		)
Total general partner’s earnings	$	40		$	14		$	106		$	34
Limited partners’ earnings on common units:
Distributions	$	89		$	66		$	250		$	186
Special Allocations (a)	(2		)	—			(2		)	—
Allocation of distributions greater than earnings	(40		)	(12		)	(95		)	(33		)
Total limited partners’ earnings on common units	$	47		$	54		$	153		$	153
Weighted average limited partner units outstanding:
Common units - basic	101.4			86.6			96.7			82.5
Common units - diluted	101.4			86.7			96.8			82.6
Net earnings per limited partner unit:
Common - basic	$	0.46		$	0.62		$	1.58		$	1.85
Common - diluted	$	0.46		$	0.62		$	1.58		$	1.85

(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 common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the Alaska Storage and Terminalling Assets acquisition during the three and nine months ended September 30, 2016.

(b) IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $3 million and $8 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2015, for further discussion related to IDRs.

(c) We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $1 million and$4 million for the three and nine months ended September 30, 2016, respectively, and $6 million and$17 million for the three and nine months ended September 30, 2015, respectively.

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Operating Segments (Tables)

9 Months Ended

Sep. 30, 2016

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

Schedule of segment reporting information, by segment

SEGMENT INFORMATION (in millions)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Revenues
Gathering:
Affiliate	$	21		$	18		$	61		$	71
Third-party	61			69			194			182
Total Gathering	82			87			255			253
Processing:
Affiliate	23			26			74			71
Third-party	46			45			134			134
Total Processing	69			71			208			205
Terminalling and Transportation:
Affiliate	140			108			386			312
Third-party	17			16			52			50
Total Terminalling and Transportation	157			124			438			362
Total Segment Revenues	$	308		$	282		$	901		$	820
Segment Operating Income
Gathering	$	31		$	42		$	107		$	121
Processing	29			29			85			77
Terminalling and Transportation	85			51			226			157
Total Segment Operating Income	145			122			418			355
Unallocated general and administrative expenses	(12		)	(16		)	(37		)	(43		)
Interest and financing costs, net	(49		)	(37		)	(138		)	(112		)
Equity in earnings of equity method investments	3			2			10			6
Other income, net	—			—			6			—
Net Earnings	$	87		$	71		$	259		$	206
Capital Expenditures
Gathering	$	21		$	72		$	67		$	177
Processing	2			5			15			10
Terminalling and Transportation	19			16			43			50
Total Capital Expenditures	$	42		$	93		$	125		$	237

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Organization and Basis of Presentation, Fair Value (Details) - USD ($) $ in Billions	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Percent of trade receivables greater than 90 days outstanding outstanding	1.00%
Debt, carrying value	$ 3.4	$ 2.9
Debt, fair value	$ 3.6	$ 2.8
Maximum
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Percent of trade payables greater than 90 days outstanding	1.00%
Minimum
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Fair Value Assumptions, Expected Term	90 days

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Related-Party Transactions Related-Party Transactions, Alaska Logistics Assets (Details) - Alaska Logistics Assets bbl in Millions, $ in Millions	Sep. 16, 2016 USD ($)	Jul. 01, 2016 USD ($) bbl
Business Combination, Consideration Transferred		$ 444
Phase One
Business Combination, Consideration Transferred		$ 266
Capacity ratio | bbl		3.5
Payments to Acquire Businesses, Gross		$ 240
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned		$ 26
Phase Two
Business Combination, Consideration Transferred	$ 178
Payments to Acquire Businesses, Gross	160
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	$ 18

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Related-Party Transactions Related-Party Transactions, Summary of Transactions Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016 USD ($)
Omnibus Agreement
Payment for Administrative Fees	$ 10
Secondment and Logistics Services Agreement
Annual Service Fee	$ 2

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Related-Party Transactions Related-Party Transactions, Summary of Affiliate Transactions (Details) - USD ($) $ / shares in Units, $ in Millions				3 Months Ended					9 Months Ended
		Nov. 14, 2016	Oct. 18, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Concentration Risk, Percentage				60.00%				54.00%	58.00%	55.00%
Revenue from Related Parties	[1],[2]			$ 184				$ 152	$ 521	$ 454
Related Party Transaction, Expenses from Transactions with Related Party				40				33	113	93
Related Party Gain (Loss) On Settlement And Reimbursements	[3]			5				12	17	31
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party				18				16	51	51
Volume Gains (Losses) Value				2				2	5	6
Cost of Reimbursable Expense				$ 3				$ 10	12	$ 25
Distribution Made to Limited Partner, Cash Distributions Declared									$ 175
Distribution Made to Limited Partner, Distributions Declared, Per Unit					$ 0.842	$ 0.810	$ 0.780
Distribution Made to Limited Partner, Distribution Date					Aug. 12, 2016	May 13, 2016	Feb. 12, 2016
Subsequent Event
Distribution Made to Limited Partner, Cash Distributions Declared			$ 71
Distribution Made to Limited Partner, Declaration Date			Oct. 18, 2016
Distribution Made to Limited Partner, Distributions Declared, Per Unit	[4]		$ 0.875
Distribution Made to Limited Partner, Distribution Date	[4]	Nov. 14, 2016

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

[3] Includes imbalance settlement gains of $2 million and for both the three months ended September 30, 2016 and 2015, and $5 million and $6 million for the nine months ended September 30, 2016 and 2015, respectively. Also includes reimbursements from Tesoro pursuant predominantly to the Amended Omnibus Agreement and the Carson Assets Indemnity Agreement of $3 million and $10 million for the three months ended September 30, 2016 and 2015, respectively, and $12 million and $25 million for the nine months ended September 30, 2016 and 2015, respectively.

[4] This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

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Property, Plant and Equipment (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment
Property, Plant and Equipment, Transfers and Changes		$ 363
Property, Plant and Equipment, at Cost		3,642	$ 3,894
Accumulated depreciation (a) (b)	[1],[2]	(513)	(427)
Property, Plant and Equipment, Net	[3]	3,129	3,467
Gathering (a)
Property, Plant and Equipment
Property, Plant and Equipment, at Cost	[2]	1,379	1,700
Processing
Property, Plant and Equipment
Property, Plant and Equipment, at Cost		573	565
Terminalling and Transportation (b)
Property, Plant and Equipment
Property, Plant and Equipment, at Cost	[1]	1,690	1,629
Alaska Logistics Assets
Property, Plant and Equipment
Accumulated depreciation (a) (b)		(30)	(30)
Business combination, Property, Plant and Equipment recorded		$ 77	$ 47

[1] Property, plant and equipment transferred to the Partnership in the Alaska Storage and Terminalling Assets acquisition was recorded at historical costs. TLLP recorded property, plant and equipment of $77 million and $47 million as of September 30, 2016 and December 31, 2015, respectively, and accumulated depreciation of $30 million for both September 30, 2016 and December 31, 2015.

[2] We recognized a decrease of $363 million to net property, plant and equipment as of January 1, 2016 as a result of the deconsolidation of RGS. See Note 4 for further discussion of the deconsolidation of RGS.

[3] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

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Investments - Equity Method and Joint Ventures Investments - Equity Method and Joint Ventures (Details)	Sep. 30, 2016
Rendezvous Gas Services, L.L.C.
Equity Method Investment, Ownership Percentage	78.00%
Three Rivers Gathering, L.L.C.
Equity Method Investment, Ownership Percentage	50.00%
Uintah Basin Field Services, L.L.C.
Equity Method Investment, Ownership Percentage	38.00%

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Investments - Equity Method and Joint Ventures Investments - Equity Method and Joint Ventures table (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Schedule of Equity Method Investments
Balance at December 31, 2015				$ 58
Effect of deconsolidation (a)	[1]			295
Equity in earnings	[2]	$ 3	$ 2	10	$ 6
Distributions received				(21)
Balance at September 30, 2016		342		342
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity		137		137
Cumulative Effect on Retained Earnings, Net of Tax				2
Rendezvous Gas Services, L.L.C.
Schedule of Equity Method Investments
Balance at December 31, 2015				0
Effect of deconsolidation (a)	[1]			295
Equity in earnings				6
Distributions received				(16)
Balance at September 30, 2016		285		285
Three Rivers Gathering, L.L.C.
Schedule of Equity Method Investments
Balance at December 31, 2015				42
Effect of deconsolidation (a)	[1]			0
Equity in earnings				2
Distributions received				(3)
Balance at September 30, 2016		41		41
Uintah Basin Field Services, L.L.C.
Schedule of Equity Method Investments
Balance at December 31, 2015				16
Effect of deconsolidation (a)	[1]			0
Equity in earnings				2
Distributions received				(2)
Balance at September 30, 2016		$ 16		$ 16

[1] We recognized an increase of $295 million to equity method investments as of January 1, 2016 as a result of the deconsolidation of RGS in addition to a cumulative effect reduction to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods. The carrying amount of our investment in RGS exceeded the underlying equity in net assets by $137 million at September 30, 2016.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

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Debt, Total (Details) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Debt Instrument
Total debt		$ 3,428	$ 2,883
Unamortized issuance costs (a)	[1]	(46)	(39)
Debt, Net of Unamortized Issuance Costs	[2]	3,382	2,844
Senior Notes [Member]
Debt Instrument
Debt Instrument, Unamortized Premium		$ 4	$ 4

[1] Includes unamortized premiums of $4 million associated with our senior notes at both September 30, 2016 and December 31, 2015.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

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Debt, Revolving Credit Facility (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Jan. 29, 2016
Revolving Credit Facility
Total loan availability	$ 1,600
Maximum loan availability	2,100	$ 1,000
Borrowings under Revolving Credit Facility	400
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,200
Revolver maturity date	Jan. 29, 2021
Revolving credit facility
Revolving Credit Facility
Total loan availability	$ 600	$ 900
Borrowings under Revolving Credit Facility	0
Letters of Credit Outstanding, Amount	0
Line of Credit Facility, Remaining Borrowing Capacity	$ 600
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.
Dropdown Credit Facility
Revolving Credit Facility
Total loan availability	$ 1,000
Borrowings under Revolving Credit Facility	400
Letters of Credit Outstanding, Amount	0
Line of Credit Facility, Remaining Borrowing Capacity	$ 600
Line Of Credit Facility, Remaining Borrowing Capacity Percentage	60.00%
Weighted average interest rate	2.54%
Revolver maturity date	Jan. 29, 2021

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Debt Debt, Senior Notes (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	May 09, 2016
6.375% Senior Notes Due 2024 [Member] | Debt Instrument, Redemption, Period One [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	4.781%
6.375% Senior Notes Due 2024 [Member] | Debt Instrument, Redemption, Period Two [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	3.188%
6.375% Senior Notes Due 2024 [Member] | Debt Instrument, Redemption, Period Three [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	1.594%
6.125% Senior Notes due 2021 [Member] | Debt Instrument, Redemption, Period One [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	4.594%
6.125% Senior Notes due 2021 [Member] | Debt Instrument, Redemption, Period Two [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	3.063%
6.125% Senior Notes due 2021 [Member] | Debt Instrument, Redemption, Period Three [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	1.531%
6.125% Senior Notes due 2021 [Member]
Debt Instrument
Debt Instrument, Face Amount		$ 250
Existing Senior Notes	$ 550
6.375% Senior Notes Due 2024 [Member]
Debt Instrument
Debt Instrument, Face Amount		$ 450
6.375% Senior Notes Due 2024 [Member] | Debt Instrument, Redemption, Period One [Member]
Debt Instrument
Debt Instrument, Redemption Price, Percentage	106.375%
Debt Instrument, Redemption Price, Percentage of Principal Amount that can be redeemed	35.00%

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Commitments and Contingencies (Details) - USD ($) $ in Millions						9 Months Ended	12 Months Ended
	Apr. 15, 2016	Mar. 29, 2016	Mar. 22, 2016	Jan. 30, 2014	May 01, 2012	Sep. 30, 2016	Dec. 31, 2015	Dec. 02, 2014
Changes in Environmental Liabilities
Accruals for environmental expenditures						$ 18	$ 33
Tioga Crude Oil Pipeline Release
Changes in Environmental Liabilities
Accruals for environmental expenditures						13	27
Environmental liability insurance deductible						1
Environmental liabilities insurance coverage limit						25
Estimated Environmental Remediation Expense							66
Total remediation costs in excess of insurance							$ (41)
Questar Gas Company v. QEP Field Services Company
Changes in Environmental Liabilities
Loss Contingency, Settlement Agreement, Date			March 22, 2016
Payments for Legal Settlements						15
Complaint filing date					May 1, 2012
Liability for estimated damages								$ 21
Gain (Loss) Related to Litigation Settlement						$ 6
XTO Energy Inc. v. QEP Field Services Company
Changes in Environmental Liabilities
Loss Contingency, Settlement Agreement, Date		March 29, 2016
Litigation Settlement, Amount	$ 29
Complaint filing date				January 30, 2014
Proceeds from Legal Settlements	$ 21

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Equity Equity, Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2016	Jun. 10, 2016	Dec. 31, 2015
General partner units issued (units)	2,083,330		1,900,515
General partner's ownership interest	2.00%
Common units issued (units)	102,096,039	6,325,000	93,478,326
Common Stock, Call or Exercise Features	825000
Shares Issued, Price Per Share		$ 47.13
Proceeds from Issuance of Common Limited Partners Units	$ 293
Public common units
Limited Partners' Capital Account, Units Outstanding	68,901,930
Tesoro common units
Limited Partners' Capital Account, Units Outstanding	33,194,109
Common
Proceeds from Issuance of Common Limited Partners Units	$ 293
General Partner
Proceeds from Issuance of Common Limited Partners Units	$ 0
Tesoro
Tesoro's ownership interest	34.00%

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Equity Equity, ATM Program (Details) - USD ($) $ in Millions			3 Months Ended	9 Months Ended
	Aug. 24, 2015	Aug. 06, 2015	Sep. 30, 2016	Sep. 30, 2016
Equity offering, net of issuance costs				$ 71
2015 ATM Program
Supplemental prospectus, filing date	Aug. 24, 2015
Registration Filing Date		Aug. 06, 2015
Common Units Aggregate Value	$ 750
Issuance of units			655,940	1,492,637
Equity offering, net of issuance costs			$ 31	$ 72

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Equity, Equity Activity (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Changes in carrying amount of Equity
Balance at December 31, 2015	[1]			$ 1,794
Sponsor contributions of equity to the Predecessors				34
Loss attributable to the Predecessors	[2]	$ (1)	$ (6)	(4)	$ (17)
Allocation of net assets acquired by the unitholders (b)	[3]			0
Equity offering under ATM Program, net of issuance costs				71
Proceeds from issuance of units, net of issuance costs				293
Effect of deconsolidation of RGS (c)	[4]			(86)
Quarterly distributions to unitholders and general partner(d)	[5]			(329)
Distributions to unitholders and general partner related to acquisitions (b)	[3]			(400)
Net earnings attributable to partners	[2]	88	$ 74	263	$ 204
Contributions (e)	[6]			19
Other				8
Balance at September 30, 2016	[1]	1,663		1,663
Increase (Decrease) In Equity Balance Due To Acquisitions				354
Cumulative Effect on Retained Earnings, Net of Tax				2
Predecessor Equity [Member]
Changes in carrying amount of Equity
Balance at December 31, 2015	[7]			16
Sponsor contributions of equity to the Predecessors	[7]			34
Loss attributable to the Predecessors	[7]			4
Allocation of net assets acquired by the unitholders (b)	[3],[7]			(46)
Equity offering under ATM Program, net of issuance costs	[7]			0
Proceeds from issuance of units, net of issuance costs	[7]			0
Effect of deconsolidation of RGS (c)	[4],[7]			0
Quarterly distributions to unitholders and general partner(d)	[5],[7]			0
Distributions to unitholders and general partner related to acquisitions (b)	[3],[7]			0
Net earnings attributable to partners	[7]			0
Contributions (e)	[6],[7]			0
Other	[7]			0
Balance at September 30, 2016	[7]	0		0
Common
Changes in carrying amount of Equity
Balance at December 31, 2015				1,707
Sponsor contributions of equity to the Predecessors				0
Loss attributable to the Predecessors				0
Allocation of net assets acquired by the unitholders (b)	[3]			40
Equity offering under ATM Program, net of issuance costs				71
Proceeds from issuance of units, net of issuance costs				293
Effect of deconsolidation of RGS (c)	[4]			(2)
Quarterly distributions to unitholders and general partner(d)	[5]			(234)
Distributions to unitholders and general partner related to acquisitions (b)	[3]			(321)
Net earnings attributable to partners				154
Contributions (e)	[6]			17
Other				4
Balance at September 30, 2016		1,729		1,729
General Partner
Changes in carrying amount of Equity
Balance at December 31, 2015				(13)
Sponsor contributions of equity to the Predecessors				0
Loss attributable to the Predecessors				0
Allocation of net assets acquired by the unitholders (b)	[3]			6
Equity offering under ATM Program, net of issuance costs				0
Proceeds from issuance of units, net of issuance costs				0
Effect of deconsolidation of RGS (c)	[4]			0
Quarterly distributions to unitholders and general partner(d)	[5]			(95)
Distributions to unitholders and general partner related to acquisitions (b)	[3]			(79)
Net earnings attributable to partners				109
Contributions (e)	[6]			2
Other				4
Balance at September 30, 2016		(66)		(66)
Noncontrolling Interest
Changes in carrying amount of Equity
Balance at December 31, 2015				84
Sponsor contributions of equity to the Predecessors				0
Loss attributable to the Predecessors				0
Allocation of net assets acquired by the unitholders (b)	[3]			0
Equity offering under ATM Program, net of issuance costs				0
Proceeds from issuance of units, net of issuance costs				0
Effect of deconsolidation of RGS (c)	[4]			(84)
Quarterly distributions to unitholders and general partner(d)	[5]			0
Distributions to unitholders and general partner related to acquisitions (b)	[3]			0
Net earnings attributable to partners				0
Contributions (e)	[6]			0
Other				0
Balance at September 30, 2016		$ 0		$ 0

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[3] Distributions to unitholders and general partner include $400 million in cash payments for the Alaska Storage and Terminalling Assets acquisition from Tesoro. As an entity under common control with Tesoro, we record the assets that we acquire from Tesoro in our consolidated balance sheets at Tesoro’s historical book value instead of fair value, and any excess of cash paid over the historical book value of the assets acquired from Tesoro is recorded within equity. As a result of this accounting treatment, this transaction resulted in a net decrease of $354 million in our equity balance during the nine months ended September 30, 2016.

[4] As a result of the reassessment performed, we deconsolidated RGS causing the derecognition of noncontrolling interest and an opening equity impact totaling $86 million. The cumulative effect to opening equity of $2 million related to the difference in earnings under the equity method of accounting in prior periods.

[5] Represents cash distributions declared and paid during the nine months ended September 30, 2016 relating to the fourth quarter of 2015 through the second quarter of 2016.

[6] 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.

[7] Adjusted to include the historical results of the Predecessors. See Note 1 for further discussion.

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Equity Equity, Earnings Per Unit (Details) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016 USD ($) $ / shares shares	Sep. 30, 2015 USD ($) $ / shares shares	Sep. 30, 2016 USD ($) $ / shares shares		Sep. 30, 2015 USD ($) $ / shares shares
Incentive Distribution, Distribution Split Marginal Percentage				50.00%
Incentive Distribution, Minimum Distribution Level | $ / shares				0.3881
General Partner Distributions			$ 3			$ 8
Net earnings	[1]	$ 87	71	$ 259	[2]	206	[2]
Net earnings attributable to noncontrolling interest	[1]	0	(3)	0		(19)
Special Allocations Of Net Earnings	[3]	2	0	2		0
Net earnings, excluding noncontrolling interest and including Special Allocations		89	68	261		187
Distribution Made to Limited Partner, Cash Distributions Declared				175
Undistributed Earnings (Loss) Allocated to Participating Securities, Basic		$ (42)	$ (18)	$ (101)		$ (50)
Common units - basic | shares	[1]	101.4	86.6	96.7		82.5
Common units - diluted | shares	[1]	101.4	86.7	96.8		82.6
Common - basic | $ / shares	[1]	$ 0.46	$ 0.62	$ 1.58		$ 1.85
Common - diluted | $ / shares	[1]	$ 0.46	$ 0.62	$ 1.58		$ 1.85
General Partner
General Partner Distributions		$ 3	$ 1	$ 7		$ 4
Incentive Distribution, Subsequent Distribution Amount	[4]	39	19	105		47
Undistributed Earnings (Loss) Allocated to Participating Securities, Basic	[5]	(2)	(6)	(6)		(17)
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		40	14	106		34
Common
Special Allocations Of Net Earnings	[3]	(2)	0	(2)		0
Distribution Made to Limited Partner, Cash Distributions Declared		89	66	250		186
Undistributed Earnings (Loss) Allocated to Participating Securities, Basic		(40)	(12)	(95)		(33)
Participating Securities, Distributed and Undistributed Earnings (Loss), Basic		$ 47	$ 54	$ 153		$ 153

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[3] 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 common units held by TLGP for the interest incurred in connection with borrowings on the Dropdown Credit Facility in lieu of using cash on hand to fund the Alaska Storage and Terminalling Assets acquisition during the three and nine months ended September 30, 2016.

[4] IDRs entitle the general partner to receive increasing percentages, up to 50%, of quarterly distributions in excess of $0.3881 per unit per quarter. The amount above reflects earnings distributed to our general partner net of $3 million and $8 million of IDRs for the three and nine months ended September 30, 2015, respectively, waived by TLGP. See Note 12 of our Annual Report on Form 10-K for the year ended December 31, 2015, for further discussion related to IDRs.

[5] We have revised the historical allocation of general partner earnings to include the Predecessors’ losses of $1 million and $4 million for the three and nine months ended September 30, 2016, respectively, and $6 million and $17 million for the three and nine months ended September 30, 2015, respectively.

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Equity, Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Millions					3 Months Ended
		Nov. 14, 2016	Nov. 04, 2016	Oct. 18, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015
Distribution Made to Member or Limited Partner
Quarterly Distribution Per Unit					$ 0.842	$ 0.810	$ 0.780
Total Cash Distribution including general partner IDRs (in millions)					$ 123	$ 108	$ 98
Date of Distribution					Aug. 12, 2016	May 13, 2016	Feb. 12, 2016
Unitholders Record Date					Aug. 02, 2016	May 02, 2016	Feb. 02, 2016
Subsequent Event
Distribution Made to Member or Limited Partner
Quarterly Distribution Per Unit	[1]			$ 0.875
Total Cash Distribution including general partner IDRs (in millions)	[1]	$ 131
Date of Distribution	[1]	Nov. 14, 2016
Unitholders Record Date	[1]		Nov. 04, 2016
Distribution Made to Limited Partner, Declaration Date				Oct. 18, 2016

[1] This distribution was declared on October 18, 2016 and will be paid on the date of distribution.

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Operating Segments, Narrative Information (Details)	9 Months Ended
	Sep. 30, 2016 segments facility
Segment Reporting Information
Number of operating segments (segments) | segments	3
Processing | Gas Processing Complexes
Segment Reporting Information
Number of assets (assets)	4
Green River Processing, LLC | Fractionation Facility
Segment Reporting Information
Number of assets (assets)	1

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Operating Segments, Results (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
Revenues
Affiliate	[1],[2]	$ 184	$ 152	$ 521		$ 454
Third-party	[1]	124	130	380		366
Total Revenues	[1]	308	282	901		820
Segment Operating Income
Operating Income (Loss)	[1]	133	106	381		312
Segment Reporting, Operating Income (Loss)		145	122	418		355
Unallocated general and administrative expenses		(12)	(16)	(37)		(43)
Interest and financing costs, net	[1]	(49)	(37)	(138)		(112)
Equity in earnings of equity method investments	[1]	3	2	10		6
Other income, net	[1]	0	0	6		0
Net Earnings	[1]	87	71	259	[3]	206	[3]
Segment Reporting Information, Additional Information
Capital Expenditures		42	93	125		237
Gathering
Revenues
Affiliate		21	18	61		71
Third-party		61	69	194		182
Total Revenues		82	87	255		253
Segment Operating Income
Operating Income (Loss)		31	42	107		121
Segment Reporting Information, Additional Information
Capital Expenditures		21	72	67		177
Processing
Revenues
Affiliate		23	26	74		71
Third-party		46	45	134		134
Total Revenues		69	71	208		205
Segment Operating Income
Operating Income (Loss)		29	29	85		77
Segment Reporting Information, Additional Information
Capital Expenditures		2	5	15		10
Terminalling and Transportation (b)
Revenues
Affiliate		140	108	386		312
Third-party		17	16	52		50
Total Revenues		157	124	438		362
Segment Operating Income
Operating Income (Loss)		85	51	226		157
Segment Reporting Information, Additional Information
Capital Expenditures		$ 19	$ 16	$ 43		$ 50

[1] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.

[2] Tesoro accounted for 60% and 54% of our total revenues for the three months ended September 30, 2016 and 2015, respectively, and 58% and 55% of our total revenues for the nine months ended September 30, 2016 and 2015, respectively.

[3] (a)Adjusted to include the historical results of the Predecessors. See Notes 1 and 2 for further discussion.