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 June 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. Yes þ 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). Yes þ No o
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). Yes o No þ
There were 101,081,387 common units and 2,062,890 general partner units of the registrant outstanding at July 28, 2016.

TABLE OF CONTENTS |  |

TESORO LOGISTICS LP
QUARTERLY REPORT ON FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2016

PART I. FINANCIAL INFORMATION | Page
Item 1. Financial Statements (Unaudited) |
Condensed Statements of Combined Consolidated Operations - Three and Six Months Ended June 30, 2016 and 2015 | 3
Condensed Consolidated Balance Sheets - June 30, 2016 and December 31, 2015 | 4
Condensed Statements of Combined Consolidated Cash Flows - Six Months Ended June 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 | 17
Item 3. Quantitative and Qualitative Disclosures About Market Risk | 32
Item 4. Controls and Procedures | 33
PART II. OTHER INFORMATION |
Item 1. Legal Proceedings | 34
Item 1A. Risk Factors | 34
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds | 34
Item 5. Other Information | 35
Item 6. Exhibits | 35
SIGNATURES | 37

2 | Tesoro Logistics LP 2016

FINANCIAL STATEMENTS |  |

PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
TESORO LOGISTICS LP
CONDENSED STATEMENTS OF COMBINED CONSOLIDATED OPERATIONS
(Unaudited)

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
| (In millions, except per unit amounts)
Revenues |  |  |  |  |  |  |
Affiliate | $ | 168 |  |  | $ | 154 |  |  | $ | 337 |  |  | $ | 302 |
Third-party | 125 |  |  | 121 |  |  | 256 |  |  | 236 |
Total Revenues | 293 |  |  | 275 |  |  | 593 |  |  | 538 |
Costs and Expenses |  |  |  |  |  |  |
Operating and maintenance expenses | 108 |  |  | 110 |  |  | 220 |  |  | 208 |
Imbalance settlement gains and reimbursements | (6 | ) |  | (11 | ) |  | (13 | ) |  | (19 | )
General and administrative expenses | 22 |  |  | 28 |  |  | 46 |  |  | 53 |
Depreciation and amortization expenses | 44 |  |  | 44 |  |  | 88 |  |  | 88 |
Net loss on asset disposals and impairments | — |  |  | — |  |  | 1 |  |  | — |
Total Costs and Expenses | 168 |  |  | 171 |  |  | 342 |  |  | 330 |
Operating Income | 125 |  |  | 104 |  |  | 251 |  |  | 208 |
Interest and financing costs, net | (45 | ) |  | (38 | ) |  | (89 | ) |  | (75 | )
Equity in earnings of unconsolidated affiliates | 3 |  |  | 1 |  |  | 7 |  |  | 4 |
Other income, net | — |  |  | — |  |  | 6 |  |  | — |
Net Earnings | $ | 83 |  |  | $ | 67 |  |  | $ | 175 |  |  | $ | 137 |
Loss attributable to Predecessor | $ | — |  |  | $ | 5 |  |  | $ | — |  |  | $ | 9 |
Net earnings attributable to noncontrolling interest | — |  |  | (6 | ) |  | — |  |  | (16 | )
Net Earnings Attributable to Partners | 83 |  |  | 66 |  |  | 175 |  |  | 130 |
General partner’s interest in net earnings, including incentive distribution rights | (36 | ) |  | (17 | ) |  | (68 | ) |  | (31 | )
Limited Partners’ Interest in Net Earnings | $ | 47 |  |  | $ | 49 |  |  | $ | 107 |  |  | $ | 99 |
Net Earnings per Limited Partner Unit: |  |  |  |  |  |  |
Common - basic | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |
Common - diluted | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |
Weighted Average Limited Partner Units Outstanding: |  |  |  |  |  |  |
Common units - basic | 95.2 |  |  | 80.7 |  |  | 94.4 |  |  | 80.5 |
Common units - diluted | 95.2 |  |  | 80.8 |  |  | 94.4 |  |  | 80.6 |
Cash Distributions Paid Per Unit | $ | 0.8100 |  |  | $ | 0.6950 |  |  | $ | 1.5900 |  |  | $ | 1.3625 |

See accompanying notes to condensed combined consolidated financial statements.
Tesoro Logistics LP 2016 | 3

FINANCIAL STATEMENTS |  |

TESORO LOGISTICS LP
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

| June 30, 2016 |  | December 31, 2015
| (In millions, except unit amounts)
ASSETS |  |  |
Current Assets |  |  |
Cash and cash equivalents | $ | 682 |  |  | $ | 16 |
Receivables, net |  |  |
Trade | 115 |  |  | 139 |
Affiliate | 91 |  |  | 85 |
Prepayments and other | 23 |  |  | 12 |
Total Current Assets | 911 |  |  | 252 |
Net Property, Plant and Equipment | 3,086 |  |  | 3,450 |
Acquired Intangibles, net | 962 |  |  | 976 |
Goodwill | 117 |  |  | 130 |
Investment in Unconsolidated Affiliates | 345 |  |  | 58 |
Other Noncurrent Assets | 29 |  |  | 26 |
Total Assets | $ | 5,450 |  |  | $ | 4,892 |
LIABILITIES AND EQUITY |  |  |
Current Liabilities |  |  |
Accounts payable |  |  |
Trade | $ | 57 |  |  | $ | 83 |
Affiliate | 40 |  |  | 48 |
Accrued interest and financing costs | 37 |  |  | 31 |
Other current liabilities | 42 |  |  | 59 |
Total Current Liabilities | 176 |  |  | 221 |
Debt, Net of Unamortized Issuance Costs | 3,218 |  |  | 2,844 |
Other Noncurrent Liabilities | 46 |  |  | 49 |
Total Liabilities | 3,440 |  |  | 3,114 |
Commitments and Contingencies (Note 6) |  |  |  |  |
Equity |  |  |
Common unitholders; 100,691,105 units issued and outstanding (93,478,326 in 2015) | 2,006 |  |  | 1,707 |
General partner; 1,900,515 units issued and outstanding (1,900,515 in 2015) | 4 |  |  | (13 | )
Noncontrolling interest | — |  |  | 84 |
Total Equity | 2,010 |  |  | 1,778 |
Total Liabilities and Equity | $ | 5,450 |  |  | $ | 4,892 |

See accompanying notes to condensed combined consolidated financial statements.
4 | Tesoro Logistics LP 2016

FINANCIAL STATEMENTS |  |

TESORO LOGISITICS LP
CONDENSED STATEMENTS OF COMBINED CONSOLIDATED CASH FLOWS
(Unaudited)

| Six Months Ended June 30,
| 2016 |  | 2015
| (In millions)
Cash Flows From (Used In) Operating Activities: |  |  |
Net earnings | $ | 175 |  |  | $ | 137 |
Adjustments to reconcile net earnings to net cash from operating activities: |  |  |
Depreciation and amortization expenses | 88 |  |  | 88 |
Other non-cash operating activities | 20 |  |  | 9 |
Changes in current assets and current liabilities | (32 | ) |  | (27 | )
Changes in noncurrent assets and noncurrent liabilities | 1 |  |  | 6 |
Net cash from operating activities | 252 |  |  | 213 |
Cash Flows Used In Investing Activities: |  |  |
Capital expenditures | (93 | ) |  | (163 | )
Other investing | (4 | ) |  | (6 | )
Net cash used in investing activities | (97 | ) |  | (169 | )
Cash Flows From (Used In) Financing Activities: |  |  |
Borrowings under revolving credit agreements | 600 |  |  | 262 |
Repayments under revolving credit agreement | (666 | ) |  | (223 | )
Proceeds from debt offering | 701 |  |  | — |
Repayment of term loan facility | (250 | ) |  | — |
Proceeds from issuance of units, net of issuance costs | 334 |  |  | 45 |
Quarterly distributions to unitholders | (149 | ) |  | (110 | )
Quarterly distributions to general partner | (57 | ) |  | (30 | )
Distributions to noncontrolling interest | — |  |  | (18 | )
Financing costs | (17 | ) |  | — |
Sponsor contributions of equity to the Predecessor | — |  |  | 12 |
Capital contributions by affiliate | 15 |  |  | 12 |
Net cash from (used in) financing activities | 511 |  |  | (50 | )
Increase (Decrease) in Cash and Cash Equivalents | 666 |  |  | (6 | )
Cash and Cash Equivalents, Beginning of Period | 16 |  |  | 19 |
Cash and Cash Equivalents, End of Period | $ | 682 |  |  | $ | 13 |

See accompanying notes to condensed combined consolidated financial statements.
Tesoro Logistics LP 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 those assets, liabilities and results of operations are collectively referred to as the “Predecessor.” The accompanying condensed combined consolidated financial statements and related notes present the results of operations and cash flows of our Predecessor at historical cost. The financial statements of our Predecessor have been prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessor had been operated as an unaffiliated entity. Our Predecessor did not record revenue for transactions with Tesoro in the Terminalling and Transportation segment.
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 Predecessor, for any interim period are not necessarily indicative of results for the full year.
CONDENSED CONSOLIDATING FINANCIAL INFORMATION. The parent company of the Partnership 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.
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 no longer have a consolidated non-guarantor subsidiary. For further discussion on the deconsolidation of RGS, see discussion below and in Note 4.
6 | Tesoro Logistics LP 2016

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 legal disputes, primarily XTO Energy Inc.’s (“XTO”) legal dispute with QEP Field Services, LLP (“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 $3.3 billion and $3.4 billion as of June 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 include any unamortized issuance costs associated with our total debt.
NEW ACCOUNTING STANDARDS AND DISCLOSURES
REVENUE RECOGNITION. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”), which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017, given the FASB’s recent deferral of ASU 2014-09’s effective date. Entities may choose to early adopt ASU 2014-09 as of the original effective date. The standard allows for either full retrospective adoption or modified retrospective adoption. We are currently evaluating the impact of the standard on our financial statements and related disclosures. Based on our initial evaluation, we believe that the standard could impact the amount and timing of revenues we recognize as certain of our revenue arrangements require us to provide multiple services and may include variable consideration.
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
Tesoro Logistics LP 2016 | 7

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

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.
PRINCIPAL VS AGENT CONSIDERATIONS. In March 2016, the FASB issued ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net)” (“ASU 2016-08”), which amends the principal versus agent guidance in ASU 2014-09. The amendments clarify how an entity should apply the control principle to certain types of arrangements, such as service transactions, by explaining what a principal controls before the specified good or service is transferred to the customer. The effective date and transition requirements for the amendments in ASU 2016-08 are the same as the effective date and transition requirements of ASU 2014-09. At this time, we are evaluating the potential impact of this standard on our financial statements.
NOTE 2 - RELATED-PARTY TRANSACTIONS
ACQUISITION
ALASKA LOGISTICS 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 to be 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 purchase consists of refined product terminals in Anchorage and Fairbanks (together, the “Alaska Logistics Assets”). Consideration paid for the first phase was $266 million, which comprised of approximately $239 million in cash, financed with borrowings under the Dropdown Credit Facility, and the issuance of equity to Tesoro with a fair value of $27 million. Consideration for the second phase is expected to be $178 million, comprised of approximately $160 million in cash, expected to be financed with borrowings under the Dropdown Credit Facility, and the issuance of equity securities with a fair value of approximately $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 Logistics Assets purchase. Under the terms of the Amended Omnibus Agreement as of June 30, 2016, we are required to pay Tesoro an annual corporate services fee of $9 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 June 30, 2016, we pay Tesoro a net annual service fee of $2 million for 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 2016

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 June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues (a) | $ | 168 |  |  | $ | 154 |  |  | $ | 337 |  |  | $ | 302 |
Operating and maintenance expenses | 34 |  |  | 29 |  |  | 71 |  |  | 58 |
Imbalance settlement gains and reimbursements from Tesoro (b) | 5 |  |  | 11 |  |  | 12 |  |  | 19 |
General and administrative expenses | 16 |  |  | 18 |  |  | 33 |  |  | 35 |

(a) | Tesoro accounted for 57% of our total revenues for both the three and six months ended June 30, 2016 and 56% of our total revenues for both the three and six months ended June 30, 2015.

(b) | Includes imbalance settlement gains of $2 million for both the three months ended June 30, 2016 and 2015, and $3 million and $4 million for the six months ended June 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 $9 million for the three months ended June 30, 2016 and 2015, respectively, and $9 million and $15 million for the six months ended June 30, 2016 and 2015, respectively.

PREDECESSOR TRANSACTIONS. Related-party transactions of our Predecessor were settled through equity. Our Predecessor 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 six months ended June 30, 2016, we paid quarterly cash distributions of $109 million to Tesoro and TLGP, including incentive distribution rights (“IDRs”). On July 20, 2016, we declared a quarterly cash distribution of $0.842 per unit, which will be paid on August 12, 2016. The distribution will include payments of $66 million to Tesoro and TLGP, including IDRs.
NOTE 3 - PROPERTY, PLANT AND EQUIPMENT
PROPERTY, PLANT AND EQUIPMENT BY SEGMENT, AT COST (in millions)

| June 30, 2016 |  | December 31, 2015
Gathering (a) | $ | 1,368 |  |  | $ | 1,700 |
Processing | 571 |  |  | 565 |
Terminalling and Transportation | 1,593 |  |  | 1,582 |
Gross Property, Plant and Equipment | 3,532 |  |  | 3,847 |
Accumulated depreciation (a) | (446 | ) |  | (397 | )
Net Property, Plant and Equipment | $ | 3,086 |  |  | $ | 3,450 |

(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.

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 | 4 |  |  | 2 |  |  | 1 |  |  | 7 |
Distributions received | (10 | ) |  | (4 | ) |  | (1 | ) |  | (15 | )
Balance at June 30, 2016 | $ | 289 |  |  | $ | 40 |  |  | $ | 16 |  |  | $ | 345 |

Tesoro Logistics LP 2016 | 9

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

(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 $138 million at June 30, 2016.

NOTE 5 - DEBT
DEBT BALANCE, NET OF UNAMORTIZED ISSUANCE COSTS (in millions)

| June 30, 2016 |  | December 31, 2015
Total debt | $ | 3,266 |  |  | $ | 2,883 |
Unamortized issuance costs (a) | (48 | ) |  | (39 | )
Debt, Net of Unamortized Issuance Costs | $ | 3,218 |  |  | $ | 2,844 |

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

REVOLVING CREDIT FACILITY AND DROPDOWN CREDIT FACILITY
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 improving 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 June 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 June 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 had no borrowings outstanding under the secured Revolving Credit Facility, resulting in the full loan availability of the borrowing capacity as of June 30, 2016.
As of June 30, 2016, our secured Dropdown Credit Facility provided for total loan availability of $1.0 billion. We had $239 million borrowings outstanding under the secured Dropdown Credit Facility, resulting in unused loan availability of $761 million or 76% the borrowing capacity as of June 30, 2016. The weighted average interest rate for borrowings under our secured Dropdown Credit Facility was 4.51% at June 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, 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. We may redeem some or all of the 2021 Notes, prior to October 15, 2016, at a make-whole price plus accrued and unpaid interest, if any. On or after October 15, 2016, the 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. We will have the right to redeem up to 35% of the aggregate principal amount
10 | Tesoro Logistics LP 2016

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

at 106.125% of face value with proceeds from certain equity issuances through October 15, 2016. 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.
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.
Tesoro Logistics LP 2016 | 11

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 $24 million and $33 million at June 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. We have liabilities totaling $19 million and $27 million at June 30, 2016 and December 31, 2015, respectively. This incident was covered by our pollution legal liability insurance policy, subject to a $1 million deductible and a $25 million loss limit. Pursuant to this policy, 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.
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 six months ended June 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 $22 million of allocated charges they are challenging, 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, 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 68,245,990 common public units outstanding as of June 30, 2016. Additionally, Tesoro owned 32,445,115 of our common units and 1,900,515 of our general partner units (the 1.9% general partner interest) as of June 30, 2016, which together constitutes a 33% 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 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 six months ended June 30, 2016, we issued an aggregate of 732,949 and 792,647 common units, respectively, under our ATM Program, generating proceeds of approximately $36 million and $38 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.
12 | Tesoro Logistics LP 2016

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

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

| Partnership |  |  |  |
| Common |  | General Partner |  | Noncontrolling Interest |  | Total
Balance at December 31, 2015 | $ | 1,707 |  |  | $ | (13 | ) |  | $ | 84 |  |  | $ | 1,778 |
Equity offering under ATM Program, net of issuance costs | 41 |  |  | — |  |  | — |  |  | 41 |
Proceeds from issuance of units, net of issuance costs | 293 |  |  | — |  |  | — |  |  | 293 |
Effect of deconsolidation of RGS (a) | (2 | ) |  | — |  |  | (84 | ) |  | (86 | )
Distributions (b) | (149 | ) |  | (57 | ) |  | — |  |  | (206 | )
Net earnings | 107 |  |  | 68 |  |  | — |  |  | 175 |
Contributions (c) | 12 |  |  | 1 |  |  | — |  |  | 13 |
Other | (3 | ) |  | 5 |  |  | — |  |  | 2 |
Balance at June 30, 2016 | $ | 2,006 |  |  | $ | 4 |  |  | $ | — |  |  | $ | 2,010 |

(a) | As the 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.

(b) | Represents cash distributions declared and paid during the six months ended June 30, 2016 relating to the fourth quarter of 2015 and the first quarter of 2016.

(c) | 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 June 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.
Tesoro Logistics LP 2016 | 13

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

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

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Net earnings | $ | 83 |  |  | $ | 67 |  |  | $ | 175 |  |  | $ | 137 |
Net earnings attributable to noncontrolling interest | — |  |  | (6 | ) |  | — |  |  | (16 | )
Net earnings, excluding noncontrolling interest | 83 |  |  | 61 |  |  | 175 |  |  | 121 |
General partner’s distributions | (2 | ) |  | (2 | ) |  | (4 | ) |  | (3 | )
General partner’s IDRs (a) | (36 | ) |  | (15 | ) |  | (66 | ) |  | (28 | )
Limited partners’ distributions on common units | (85 | ) |  | (64 | ) |  | (161 | ) |  | (120 | )
Distributions greater than earnings | $ | (40 | ) |  | $ | (20 | ) |  | $ | (56 | ) |  | $ | (30 | )
General partner’s earnings: |  |  |  |  |  |  |
Distributions | $ | 2 |  |  | $ | 2 |  |  | $ | 4 |  |  | $ | 3 |
General partner’s IDRs (a) | 36 |  |  | 15 |  |  | 66 |  |  | 28 |
Allocation of distributions greater than earnings (b) | (1 | ) |  | (5 | ) |  | (1 | ) |  | (9 | )
Total general partner’s earnings | $ | 37 |  |  | $ | 12 |  |  | $ | 69 |  |  | $ | 22 |
Limited partners’ earnings on common units: |  |  |  |  |  |  |
Distributions | $ | 85 |  |  | $ | 64 |  |  | $ | 161 |  |  | $ | 120 |
Allocation of distributions greater than earnings | (39 | ) |  | (15 | ) |  | (55 | ) |  | (21 | )
Total limited partners’ earnings on common units | $ | 46 |  |  | $ | 49 |  |  | $ | 106 |  |  | $ | 99 |
Weighted average limited partner units outstanding |  |  |  |  |  |  |
Common units - basic | 95.2 |  |  | 80.7 |  |  | 94.4 |  |  | 80.5 |
Common units - diluted | 95.2 |  |  | 80.8 |  |  | 94.4 |  |  | 80.6 |
Net earnings per limited partner unit: |  |  |  |  |  |  |
Common - basic | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |
Common - diluted | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |

(a) | 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 $2 million and $5 million of IDRs for the three and six months ended June 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.

(b) | We have revised the historical allocation of general partner earnings to include the Predecessor losses of $5 million and $9 million for the three and six months ended June 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 (a) | 0.842 |  |  | 123 |  |  | August 12, 2016 |  | August 2, 2016

(a) | This distribution was declared on July 20, 2016 and will be paid on the date of distribution.

14 | Tesoro Logistics LP 2016

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

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. Identifiable assets are those used by the segment, whereas other assets are principally cash and other assets that are not associated with a specific operating segment.
Tesoro Logistics LP 2016 | 15

NOTES TO CONDENSED COMBINED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) |  |

SEGMENT INFORMATION (in millions)

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues |  |  |  |  |  |  |
Gathering: |  |  |  |  |  |  |
Affiliate | $ | 18 |  |  | $ | 27 |  |  | $ | 40 |  |  | $ | 53 |
Third-party | 64 |  |  | 62 |  |  | 133 |  |  | 113 |
Total Gathering | 82 |  |  | 89 |  |  | 173 |  |  | 166 |
Processing: |  |  |  |  |  |  |
Affiliate | 25 |  |  | 25 |  |  | 51 |  |  | 45 |
Third-party | 43 |  |  | 42 |  |  | 88 |  |  | 89 |
Total Processing | 68 |  |  | 67 |  |  | 139 |  |  | 134 |
Terminalling and Transportation: |  |  |  |  |  |  |
Affiliate | 125 |  |  | 102 |  |  | 246 |  |  | 204 |
Third-party | 18 |  |  | 17 |  |  | 35 |  |  | 34 |
Total Terminalling and Transportation | 143 |  |  | 119 |  |  | 281 |  |  | 238 |
Total Segment Revenues | $ | 293 |  |  | $ | 275 |  |  | $ | 593 |  |  | $ | 538 |
Segment Operating Income |  |  |  |  |  |  |
Gathering | $ | 36 |  |  | $ | 45 |  |  | $ | 76 |  |  | $ | 79 |
Processing | 27 |  |  | 24 |  |  | 56 |  |  | 48 |
Terminalling and Transportation | 75 |  |  | 50 |  |  | 144 |  |  | 108 |
Total Segment Operating Income | 138 |  |  | 119 |  |  | 276 |  |  | 235 |
Unallocated general and administrative expenses | (13 | ) |  | (15 | ) |  | (25 | ) |  | (27 | )
Interest and financing costs, net | (45 | ) |  | (38 | ) |  | (89 | ) |  | (75 | )
Equity in earnings of unconsolidated affiliates | 3 |  |  | 1 |  |  | 7 |  |  | 4 |
Other income, net | — |  |  | — |  |  | 6 |  |  | — |
Net Earnings | $ | 83 |  |  | $ | 67 |  |  | $ | 175 |  |  | $ | 137 |
Capital Expenditures |  |  |  |  |  |  |
Gathering | $ | 21 |  |  | $ | 54 |  |  | $ | 46 |  |  | $ | 105 |
Processing | 8 |  |  | 4 |  |  | 13 |  |  | 5 |
Terminalling and Transportation | 13 |  |  | 19 |  |  | 24 |  |  | 34 |
Total Capital Expenditures | $ | 42 |  |  | $ | 77 |  |  | $ | 83 |  |  | $ | 144 |

16 | Tesoro Logistics LP 2016

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 “Predecessor” 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 both three and six months ended June 30, 2016, approximately 57% of our total revenues were derived from Tesoro under various long-term, fee-based commercial agreements, many 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 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.
Tesoro Logistics LP 2016 | 17

MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

Relative to these goals, in 2016, we intend to continue to implement 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 increased 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 in our footprint 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:

◦ | increase 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

◦ | expand 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 our Western U.S. footprint through:

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

◦ | optimize Tesoro volumes and grow third-party throughput at our terminalling and transportation assets; and

◦ | pursuing strategic assets in our footprint including completing the acquisition of Tesoro's recently acquired terminalling assets from Flint Hills Resources in Alaska.

ACQUISITION
ALASKA LOGISTICS 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 to be 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 purchase consists of refined product terminals in Anchorage and Fairbanks with combined storage capacity of over 600 thousand barrels, expected throughput of approximately 10 thousand barrels per day (“Mbpd”) and rail loading of 7 Mbpd. Consideration paid for the first phase was $266 million, which comprised of approximately $239 million in cash, financed with borrowings under the secured dropdown credit facility (the “Dropdown Credit Facility”), and the issuance of equity to Tesoro with a fair value of $27 million. Consideration for the second phase is expected to be $178 million, comprised of approximately $160 million in cash, expected to be financed with borrowings under the Dropdown Credit Facility, and the issuance of equity securities with a fair value of approximately $18 million.
CURRENT MARKET CONDITIONS
During the second quarter, the spot prices of the commodities that we handle have increased, including crude oil, natural gas, natural gas liquids and refined products. Thus, the second quarter continued the price recovery trend that was realized in the first quarter after over a year and a half of declines. This is the result of fundamentals of oil and gas supply shifting from oversupply toward more balanced supply as well as supply disruptions combined with stronger demand for these commodities. Despite the strengthening of prices, commodity prices remain relatively depressed compared to most periods, and this continues to create challenges for crude oil and natural gas producers who have modified their drilling and production plans. The U.S. oil and gas drilling rig count continued to decline in the second quarter though at quarter’s end, rig count was beginning to increase. In the crude oil and natural gas production basins where we operate, drilling for new wells is potentially not economic for producers to continue at sustained low commodity prices. However, improved drilling techniques and better well management have increased production per well. Also many producers have a back-log of uncompleted wells which are available for completion. Accordingly, these factors may further impact production volumes in conjunction with rig count trends. Lower retail prices and modest improved domestic economic conditions over the second quarter have continued to support increased demand for refined products from our downstream refining and marketing customers. 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 United States. Currently, we
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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

believe our diversified portfolios of businesses as well as our customers’ minimum volume commitments are sufficient to continue to meet our goals and objectives outlined above. However, if challenging market conditions for producers persist for a sustained period of time, our customers’ financial condition could deteriorate causing non-payment, their potential bankruptcy and project deferrals.
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 Predecessor and the consolidated financial results of TLLP for all periods presented. The financial statements of our Predecessor have been prepared from the separate records maintained by Tesoro and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessor had been operated as an unaffiliated entity. 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 expense (“EBITDA”) for items previously considered “special items” and loss attributable to our Predecessor. 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 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.

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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

We present the performance and liquidity measures defined above because 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.
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).
The following table and discussion is a summary of our results of operations for the three and six months ended June 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). Our financial results may not be comparable as our Predecessor did not record revenues with Tesoro. Our Predecessor 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.
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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

CONSOLIDATED RESULTS
SUMMARY (In millions, except per unit amounts)

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues |  |  |  |  |  |  |  |  |
Gathering | $ | 82 |  |  | $ | 89 |  |  | $ | 173 |  |  | $ | 166 |
Processing | 68 |  |  | 67 |  |  | 139 |  |  | 134 |
Terminalling and Transportation (a) | 143 |  |  | 119 |  |  | 281 |  |  | 238 |
Total Revenues | 293 |  |  | 275 |  |  | 593 |  |  | 538 |
Costs and Expenses |  |  |  |  |  |  |  |  |  |  |
Operating and maintenance expenses (b) | 102 |  |  | 99 |  |  | 207 |  |  | 189 |
General and administrative expenses | 22 |  |  | 28 |  |  | 46 |  |  | 53 |
Depreciation and amortization expenses | 44 |  |  | 44 |  |  | 88 |  |  | 88 |
Net loss on asset disposals and impairments | — |  |  | — |  |  | 1 |  |  | — |
Total Costs and Expenses | 168 |  |  | 171 |  |  | 342 |  |  | 330 |
Operating Income | 125 |  |  | 104 |  |  | 251 |  |  | 208 |
Interest and financing costs, net | (45 | ) |  | (38 | ) |  | (89 | ) |  | (75 | )
Equity in earnings of unconsolidated affiliates | 3 |  |  | 1 |  |  | 7 |  |  | 4 |
Other income, net | — |  |  | — |  |  | 6 |  |  | — |
Net Earnings | $ | 83 |  |  | $ | 67 |  |  | $ | 175 |  |  | $ | 137 |
Loss attributable to Predecessor | $ | — |  |  | $ | 5 |  |  | $ | — |  |  | $ | 9 |
Net earnings attributable to noncontrolling interest | — |  |  | (6 | ) |  | — |  |  | (16 | )
Net Earnings Attributable to Partners | 83 |  |  | 66 |  |  | 175 |  |  | 130 |
General partner’s interest in net earnings, including incentive distribution rights | (36 | ) |  | (17 | ) |  | (68 | ) |  | (31 | )
Limited Partners’ Interest in Net Earnings | $ | 47 |  |  | $ | 49 |  |  | $ | 107 |  |  | $ | 99 |
Net Earnings per Limited Partner Unit: |  |  |  |  |  |  |  |  |  |  |
Common - basic | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |
Common - diluted | $ | 0.48 |  |  | $ | 0.60 |  |  | $ | 1.12 |  |  | $ | 1.23 |
Weighted Average Limited Partner Units Outstanding: |  |  |  |  |  |  |  |  |  |  |
Common units - basic | 95.2 |  |  | 80.7 |  |  | 94.4 |  |  | 80.5 |
Common units - diluted | 95.2 |  |  | 80.8 |  |  | 94.4 |  |  | 80.6 |

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

(b) | Operating and maintenance expenses include net imbalance settlement gains of $2 million for both the three months ended June 30, 2016 and 2015, and $3 million and $4 million for the six months ended June 30, 2016 and 2015, respectively. Also includes reimbursements primarily related to pressure testing and repairs and maintenance costs pursuant to the Amended Omnibus Agreement of $3 million and $9 million for the three months ended June 30, 2016 and 2015, respectively, and $9 million and $15 million for the six months ended June 30, 2016 and 2015, respectively.

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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Reconciliation of Net Earnings to EBITDA: |  |  |  |  |  |  |  |
Net earnings | $ | 83 |  |  | $ | 67 |  |  | $ | 175 |  |  | $ | 137 |
Depreciation and amortization expenses | 44 |  |  | 44 |  |  | 88 |  |  | 88 |
Interest and financing costs, net of capitalized interest | 45 |  |  | 38 |  |  | 89 |  |  | 75 |
EBITDA | $ | 172 |  |  | $ | 149 |  |  | $ | 352 |  |  | $ | 300 |
Reconciliation of Net Cash from Operating Activities to Distributable Cash Flow and Pro Forma Distributable Cash Flow: |  |  |  |  |  |  |
Net cash from operating activities (a) | $ | 91 |  |  | $ | 65 |  |  | $ | 252 |  |  | $ | 213 |
Changes in assets and liabilities | 42 |  |  | 53 |  |  | 31 |  |  | 21 |
Predecessor impact | — |  |  | 5 |  |  | — |  |  | 11 |
Maintenance capital expenditures (b) | (14 | ) |  | (15 | ) |  | (24 | ) |  | (25 | )
Reimbursement for maintenance capital expenditures (b) | 10 |  |  | 2 |  |  | 14 |  |  | 3 |
Net earnings attributable to noncontrolling interest (c) | — |  |  | (6 | ) |  | — |  |  | (16 | )
Other adjustments for noncontrolling interest (c) | — |  |  | (12 | ) |  | — |  |  | (20 | )
Adjustments for unconsolidated affiliates (d) | (3 | ) |  | (3 | ) |  | (3 | ) |  | (1 | )
Other (e) | — |  |  | — |  |  | (2 | ) |  | 15 |
Distributable Cash Flow | 126 |  |  | 89 |  |  | 268 |  |  | 201 |
Pro forma adjustment for acquisition of noncontrolling interest (f) | — |  |  | 19 |  |  | — |  |  | 36 |
Pro Forma Distributable Cash Flow | $ | 126 |  |  | $ | 108 |  |  | $ | 268 |  |  | $ | 237 |

(a) | 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.

(b) | We exclude maintenance capital expenditures including 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.

(c) | Prior to 2016 for noncontrolling interests associated with QEPM and Rendezvous Gas Services, L.L.C. (“RGS”), we excluded earnings along with other adjustments to reflect gross cash available for distribution net of noncontrolling interest impacts.

(d) | We adjust net cash from operating activities to reflect cash distributions received from unconsolidated affiliates attributed to the period reported for the purposes of calculating distributable cash flow.

(e) | 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 six months ended June 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.

(f) | 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 JUNE 30, 2016 VERSUS THREE MONTHS ENDED JUNE 30, 2015
OVERVIEW. Our net earnings for the three months ended June 30, 2016 (“2016 Quarter”) increased $16 million to $83 million from $67 million for the three months ended June 30, 2015 (“2015 Quarter”).
REVENUES. The increase in revenue of $18 million, or 7%, to $293 million was driven primarily by the crude oil and refined product storage and pipeline assets in Los Angeles, California (the “LA Storage and Handling Assets”) purchased from Tesoro in November 2015 and by higher crude oil gathering throughput on the Tesoro High Plains Pipeline partially offset by declines in natural gas production leading to reduced volumes on our gathering system.
GENERAL AND ADMINISTRATIVE EXPENSES. General and administrative expenses decreased $6 million to $22 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 QEPFS acquisition.
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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

INTEREST AND FINANCING COSTS, NET. Net interest and financing costs increased $7 million, primarily related to the issuance of new senior notes during the 2016 Quarter and borrowings on the Dropdown Credit Facility related to the acquisition of the LA Storage and Handling Assets.
SIX MONTHS ENDED JUNE 30, 2016 VERSUS SIX MONTHS ENDED JUNE 30, 2015
OVERVIEW. Our net earnings for the six months ended June 30, 2016 (“2016 Period”) increased $38 million to $175 million from $137 million for the six months ended June 30, 2015 (“2015 Period”).
REVENUES. Revenues for the 2016 Period increased $55 million to $593 million from $538 million for the 2015 Period primarily driven by the LA Storage and Handling Assets purchased from Tesoro in November 2015. In addition, revenue increases were driven by higher crude oil gathering throughput on the Tesoro High Plains Pipeline, increased NGL processing throughput and pass-through revenue received from Tesoro during the 2016 Period, in which we recovered a temporary fee related to right-of-way costs, partially offset by a decrease in crude oil trucking revenues as a result of increased usage of the Tesoro High Plains Pipeline.
OPERATING AND MAINTENANCE EXPENSES. Operating and maintenance expenses for the 2016 Period increased $18 million to $207 million from $189 million for the 2015 Period primarily due to the reporting of gross operating and maintenance expense related to our transactions with RGS for the 2016 Period that were previously eliminated in the 2015 Period in consolidation and higher costs associated with the LA Storage and Handling Assets.
GENERAL AND ADMINISTRATIVE EXPENSES. General and administrative expenses decreased $7 million to $46 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 $14 million to $89 million from $75 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 write-off of debt issuance costs in connection with debt transactions as discussed in the “Capital Resources and Liquidity” section.
OTHER INCOME, NET. The 2016 Period includes a settlement gain of $6 million related to the legal settlement discussed further in Part II, Item 1 of this Quarterly Report on Form 10-Q.
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. In addition, we own four gathering systems and two pipelines regulated by the Federal Energy Regulatory Commission through, which we provide natural gas and crude oil transportation services.
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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

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

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues |  |  |  |  |  |  |
Gas gathering revenues | $ | 40 |  |  | $ | 46 |  |  | $ | 83 |  |  | $ | 82 |
Crude oil gathering pipeline revenues | 32 |  |  | 30 |  |  | 67 |  |  | 57 |
Crude oil gathering trucking revenues | 9 |  |  | 13 |  |  | 18 |  |  | 27 |
Other revenues | 1 |  |  | — |  |  | 5 |  |  | — |
Total Revenues | 82 |  |  | 89 |  |  | 173 |  |  | 166 |
Costs and Expenses |  |  |  |  |  |  |
Operating and maintenance expenses (a) | 30 |  |  | 24 |  |  | 62 |  |  | 47 |
General and administrative expenses | 2 |  |  | 3 |  |  | 5 |  |  | 6 |
Depreciation and amortization expenses | 14 |  |  | 17 |  |  | 29 |  |  | 34 |
Loss on asset disposals and impairments | — |  |  | — |  |  | 1 |  |  | — |
Total Costs and Expenses | 46 |  |  | 44 |  |  | 97 |  |  | 87 |
Gathering Segment Operating Income | $ | 36 |  |  | $ | 45 |  |  | $ | 76 |  |  | $ | 79 |
Volumes |  |  |  |  |  |  |
Gas gathering throughput (thousands of MMBtu/d) (b) | 854 |  |  | 1,071 |  |  | 878 |  |  | 1,046 |
Average gas gathering revenue per MMBtu (b) | $ | 0.51 |  |  | $ | 0.48 |  |  | $ | 0.52 |  |  | $ | 0.43 |
Crude oil gathering pipeline throughput (Mbpd) | 208 |  |  | 187 |  |  | 212 |  |  | 173 |
Average crude oil gathering pipeline revenue per barrel | $ | 1.72 |  |  | $ | 1.71 |  |  | $ | 1.74 |  |  | $ | 1.80 |
Crude oil gathering trucking volume (Mbpd) | 30 |  |  | 45 |  |  | 29 |  |  | 46 |
Average crude oil gathering trucking revenue per barrel | $ | 3.30 |  |  | $ | 3.32 |  |  | $ | 3.27 |  |  | $ | 3.28 |

(a) | Operating and maintenance expenses include imbalance settlement gains of $1 million for the both the three months ended June 30, 2016 and 2015, and $1 million and $2 million for the six months ended June 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 six months ended June 30, 2015, were both 146 thousand MMBtu/d and reduced our average gas gathering revenue per MMBtu by $0.05 for both periods.

THREE MONTHS ENDED JUNE 30, 2016 VERSUS THREE MONTHS ENDED JUNE 30, 2015
VOLUMES. Average crude oil gathering pipeline throughput volumes increased 21 Mbpd, or 11%, in the 2016 Quarter as a result of projects to expand the pipeline gathering system and interconnections with additional origin and destinations. Crude oil gathering trucking volumes decreased 15 Mbpd, or 33%, during the 2016 Quarter as more volumes were gathered via pipeline on to our High Plains Pipeline. The decrease in gas gathering throughput volumes of 217 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 well as declines in natural gas production leading to reduced volumes on our gathering system.
FINANCIAL RESULTS. Gathering revenues decreased $7 million, or 8%, to $82 million for the 2016 Quarter compared to $89 million in the 2015 Quarter primarily due to the recognition of revenue associated with volume shortfalls for one of our customers during the 2015 Quarter partially offset by an increase in the average gas gathering rates. In addition, crude oil gathering trucking revenues decreased due to lower volumes in the 2016 Quarter relative to the 2015 Quarter given increased usage of the High Plains Pipeline in lieu of trucking. 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 and maintenance expenses increased $6 million, or 25%, to $30 million in the 2016 Quarter compared to $24 million in the 2015 Quarter related to the reporting of gross operating and maintenance expenses related to our transactions with RGS for the 2016 Quarter that were previously eliminated in the 2015 Quarter. Operating and maintenance expenses for the rest of the Gathering segment were relatively flat in the 2016 Quarter compared to the 2015 Quarter.
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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

SIX MONTHS ENDED JUNE 30, 2016 VERSUS SIX MONTHS ENDED JUNE 30, 2015
VOLUMES. Average crude oil gathering pipeline throughput volumes increased 39 Mbpd, or 23%, in the 2016 Period as a result of projects to expand the pipeline gathering system and interconnections with additional origin and destinations. Crude oil gathering trucking volumes decreased 17 Mbpd, or 37%, 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 168 MMBtu/d, or 16% in the 2016 Period as compared to the 2015 Period is driven by the 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.
FINANCIAL RESULTS. Gathering revenues increased $7 million, or 4%, to $173 million for the 2016 Period compared to $166 million in the 2015 Period primarily due to pass-through revenue received from Tesoro during the 2016 Period, which recovered a temporary fee related to right-of-way costs. Additionally, higher crude oil pipeline throughput on our High Plains Pipeline was partially offset by decreases in crude oil gathering trucking revenues due to lower volumes in the 2016 Period relative to the 2015 Period as a result of increased usage of the High Plains Pipeline in lieu of trucking. Gas gathering revenues were relatively flat as increases in the average gas gathering rate recognized were offset by a decline in gas gathering throughput as natural gas production has declined.
Operating and maintenance expenses increased $15 million, or 32%, to $62 million in the 2016 Period compared to $47 million in the 2015 Period primarily related to the reporting of gross operating and maintenance expense related to our transactions with RGS for the 2016 Period that were previously eliminated in the 2015 Period. Operating and maintenance 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 June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues |  |  |  |  |  |  |
NGLs processing revenues | $ | 25 |  |  | $ | 25 |  |  | $ | 51 |  |  | $ | 45 |
Fee-based processing revenues | 25 |  |  | 24 |  |  | 51 |  |  | 53 |
Other processing revenues | 18 |  |  | 18 |  |  | 37 |  |  | 36 |
Total Revenues | 68 |  |  | 67 |  |  | 139 |  |  | 134 |
Costs and Expenses |  |  |  |  |  |  |
Operating and maintenance expenses | 29 |  |  | 30 |  |  | 60 |  |  | 60 |
General and administrative expenses | — |  |  | 2 |  |  | — |  |  | 4 |
Depreciation and amortization expenses | 12 |  |  | 11 |  |  | 23 |  |  | 22 |
Total Costs and Expenses | 41 |  |  | 43 |  |  | 83 |  |  | 86 |
Processing Segment Operating Income | $ | 27 |  |  | $ | 24 |  |  | $ | 56 |  |  | $ | 48 |
Volumes |  |  |  |  |  |  |
NGLs processing throughput (Mbpd) | 7.4 |  |  | 7.8 |  |  | 7.8 |  |  | 7.4 |
Average keep-whole fee per barrel of NGLs | $ | 36.60 |  |  | $ | 35.14 |  |  | $ | 35.81 |  |  | $ | 33.60 |
Fee-based processing throughput (thousands of MMBtu/d) | 645 |  |  | 768 |  |  | 660 |  |  | 729 |
Average fee-based processing revenue per MMBtu | $ | 0.43 |  |  | $ | 0.36 |  |  | $ | 0.43 |  |  | $ | 0.40 |

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MANAGEMENT’S DISCUSSION AND ANALYSIS |  |

THREE MONTHS ENDED JUNE 30, 2016 VERSUS THREE MONTHS ENDED JUNE 30, 2015
VOLUMES. Fee-based processing volumes decreased 123 thousand MMBtu/d, or 16%, to 645 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 slightly by 0.4 Mbpd, or 5%, to 7.4 Mbpd in the 2016 Quarter.
FINANCIAL RESULTS. Processing revenues were relatively flat at $68 million for the 2016 Quarter compared to $67 million in the 2015 Quarter. Improved utilization of our processing facilities along with annual rate escalations resulted in increased NGL processing rates, offset by a decline in volumes in the 2016 Quarter compared to the 2015 Quarter.
SIX MONTHS ENDED JUNE 30, 2016 VERSUS SIX MONTHS ENDED JUNE 30, 2015
VOLUMES. Fee-based processing volumes decreased 69 thousand MMBtu/d, or 9%, to 660 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 increased marginally by 0.4 Mbpd, or 5%, to 7.8 Mbpd in the 2016 Period as a result of increased optimization of our processing facilities, partially offset by decreased production of fee-based gas customers.
FINANCIAL RESULTS. Processing revenues increased $5 million, or 4%, to $139 million for the 2016 Period compared to $134 million in the 2015 Period primarily due to an increase in the average keep-whole processing fee per barrel of NGLs as well as the increase in the processing volumes. Improved utilization 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, crude oil and refined products terminals and storage facilities, a rail-car unloading facility, a petroleum coke handling and storage facility and other pipelines, which transport products and crude oil from Tesoro’s refineries to nearby facilities.
TERMINALLING AND TRANSPORTATION SEGMENT OPERATING RESULTS (in millions, except barrel and per barrel amounts)

| Three Months Ended June 30, |  | Six Months Ended June 30,
| 2016 |  | 2015 |  | 2016 |  | 2015
Revenues (a) |  |  |  |  |  |  |
Terminalling revenues | $ | 112 |  |  | $ | 92 |  |  | $ | 220 |  |  | $ | 182 |
Pipeline transportation revenues | 31 |  |  | 27 |  |  | 61 |  |  | 56 |
Total Revenues | 143 |  |  | 119 |  |  | 281 |  |  | 238 |
Costs and Expenses |  |  |  |  |  |  |
Operating and maintenance expenses (b) | 43 |  |  | 45 |  |  | 85 |  |  | 82 |
General and administrative expenses | 7 |  |  | 8 |  |  | 16 |  |  | 16 |
Depreciation and amortization expenses | 18 |  |  | 16 |  |  | 36 |  |  | 32 |
Total Costs and Expenses | 68 |  |  | 69 |  |  | 137 |  |  | 130 |
Terminalling and Transportation Segment Operating Income | $ | 75 |  |  | $ | 50 |  |  | $ | 144 |  |  | $ | 108 |
Volumes |  |  |  |  |  |  |
Terminalling throughput (Mbpd) | 994 |  |  | 913 |  |  | 950 |  |  | 916 |
Average terminalling revenue per barrel | $ | 1.24 |  |  | $ | 1.10 |  |  | $ | 1.27 |  |  | $ | 1.10 |
Pipeline transportation throughput (Mbpd) | 867 |  |  | 801 |  |  | 845 |  |  | 810 |
Average pipeline transportation revenue per barrel | $ | 0.40 |  |  | $ | 0.38 |  |  | $ | 0.40 |  |  | $ | 0.38 |

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

(b) | Operating and maintenance expenses include imbalance settlement gains of $1 million for both the three months ended June 30, 2016 and 2015, and $2 million for both the six months ended June 30, 2016 and 2015.

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THREE MONTHS ENDED JUNE 30, 2016 VERSUS THREE MONTHS ENDED JUNE 30, 2015
VOLUMES. Terminalling throughput volumes increased 81 Mbpd, or 9%, primarily due to storage assets and commercial agreements with Tesoro executed in connection with the LA Storage and Handling Asset acquisition. Pipeline transportation throughput volumes increased 66 Mbpd, or 8%, in the 2016 Quarter compared to the 2015 Quarter primarily due to higher pipeline volumes in southern California as a result of the acquired assets and increased throughput along the Salt Lake City pipeline in the 2016 Quarter as a result of maintenance activities on the system during the 2015 Quarter.
FINANCIAL RESULTS. Revenues increased $24 million, or 20%, to $143 million in the 2016 Quarter compared to $119 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 acquisition as well as increased pipeline transportation throughput volumes.
SIX MONTHS ENDED JUNE 30, 2016 VERSUS SIX MONTHS ENDED JUNE 30, 2015
VOLUMES. Terminalling throughput volumes increased 34 Mpbd, or 4% and pipeline transportation throughput volumes increased 35 Mbpd, or 4%, in the 2016 Period compared to the 2015 Period primarily due to storage assets and commercial agreements with Tesoro executed in connection with the LA Storage and Handling Asset acquisition.
FINANCIAL RESULTS. Revenues increased $43 million, or 18%, to $281 million in the 2016 Period compared to $238 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 acquisition as well as increased pipeline transportation 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: | June 30, 2016 |  | December 31, 2015
Credit Facilities | $ | 239 |  |  | $ | 555 |
Senior Notes | 3,020 |  |  | 2,320 |
Capital lease obligations | 7 |  |  | 8 |
Total Debt | 3,266 |  |  | 2,883 |
Unamortized Issuance Costs (a) | (48 | ) |  | (39 | )
Debt, Net of Unamortized Issuance Costs | 3,218 |  |  | 2,844 |
Total Equity | 2,010 |  |  | 1,778 |
Total Capitalization | $ | 5,228 |  |  | $ | 4,622 |

(a) | Includes unamortized premiums of $4 million associated with our senior notes at both June 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. W e 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
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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 six months ended June 30, 2016, we issued an aggregate of 732,949 and 792,647 common units, respectively, under our ATM Program, generating proceeds of approximately $36 million and $38 million, respectively, before issuance costs. We paid fees of less than $0.4 million related to the issuance of units under this program for both the three and six months ended June 30, 2016. 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.
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 June 30, 2016.
AVAILABLE CAPACITY UNDER OUR CREDIT FACILITIES (in millions)

| Total Capacity |  | Amount Borrowed as of June 30, 2016 |  | Available Capacity |  | Weighted Average Interest Rate |  | Expiration
Revolving Credit Facility | $ | 600 |  |  | $ | — |  |  | $ | 600 |  |  | — | % |  | January 29, 2021
Dropdown Credit Facility | 1,000 |  |  | 239 |  |  | 761 |  |  | 4.51 | % |  | January 29, 2021
Total Credit Facilities | $ | 1,600 |  |  | $ | 239 |  |  | $ | 1,361 |  |  |  |  |

EXPENSES AND FEES OF OUR CREDIT FACILITIES

Credit Facility | 30 day Eurodollar (LIBOR) Rate at June 30, 2016 |  | Eurodollar Margin |  | Base Rate |  | Base Rate Margin |  | Commitment Fee (unused portion)
Revolving Credit Facility (a) | 0.47% |  | 2.00% |  | 3.50% |  | 1.00% |  | 0.38%
Dropdown Credit Facility (a) | 0.47% |  | 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
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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.
SOURCES AND USES OF CASH
COMPONENTS OF CASH FLOWS (in millions)

| Six Months Ended June 30,
| 2016 |  | 2015
Cash Flows From (Used In): |  |  |
Operating Activities | $ | 252 |  |  | $ | 213 |
Investing Activities | (97 | ) |  | (169 | )
Financing Activities | 511 |  |  | (50 | )
Increase (Decrease) in Cash and Cash Equivalents | $ | 666 |  |  | $ | (6 | )

OPERATING ACTIVITIES. Net cash from operating activities increased $39 million to $252 million in the 2016 Period compared to $213 million for the 2015 Period. The increase in cash from operations was primarily driven by the increase in net earnings of $38 million from the 2015 Period to the 2016 Period and a $11 million impact of non-cash items were offset by the change in working capital.
INVESTING ACTIVITIES. Net cash used in investing activities for the 2016 Period decreased $72 million to $97 million compared to $169 million in the 2015 Period. The decrease related to this outflow was a result of higher capital expenditures in the 2015 Period including spending related to the construction of the Connolly Gathering System, the second phase of the Bakken area storage hub, and various projects on our Southern California distribution system. See “Capital Expenditures” below for a discussion of the various maintenance and growth projects in the 2016 Period.
FINANCING ACTIVITIES. Net cash provided by financing activities for the 2016 Period was $511 million compared to a use of cash of $50 million for the 2015 Period. We received $701 million of proceeds from debt offerings and $334 million in net proceeds from issuances of units. Offsetting these proceeds were higher quarterly cash distributions totaling $206 million during the 2016 Period compared to quarterly cash distributions totaling $140 million paid in the 2015 Period. We paid down $66 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.
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.
During the 2016 Period, we spent $62 million, net of $1 million in reimbursements from entities including Tesoro, on growth capital projects and $10 million, net of $10 million in reimbursements from entities including Tesoro, on maintenance capital
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projects. 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.
TLLP's expected 2016 capital expenditures are currently forecasted to total approximately $240 million, or $270 million offset by expected reimbursements of $30 million primarily for maintenance capital expenditures. Our revised capital spending estimate reflects the deferral of several discretionary projects and delays in several growth projects in both the Rockies and Bakken regions attributed to low commodity prices and our current view of spending related to the Los Angeles Refinery Interconnect Pipeline System.
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: |  |  |
Completed: |  |  |
Bakken Area Storage Hub (a) | $ | 30 |  |  | $ | 4 |
In Process: |  |  |
High Plains Pipeline Expansion (b) | 25-30 |  |  | 4 |
Uinta Compression (c) | 50-55 |  |  | 28 |
Terminalling and Transportation Segment: |  |  |
In Process: |  |  |
Terminal Expansions (d) | 30 |  |  | 5 |
Under Development: |  |  |
Los Angeles Refinery Interconnect Pipeline System (e) | 150-200 |  |  | — |

(a) | 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, storage capacity has grown to over 1 million barrels.

(b) | 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.

(c) | 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.

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

(e) | 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.

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 (a) |  | 0.842 |  |  | 3.37 |  |  | 123 |  |  | August 12, 2016 |  | August 2, 2016

(a) | This distribution was declared on July 20, 2016 and will be paid on the date of distribution.

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ENVIRONMENTAL AND OTHER MATTERS
ENVIRONMENTAL REGULATION. We are subject to extensive federal, state and local environmental laws and regulations. These laws, which change frequently, regulate the discharge of materials into the environment or otherwise relate to protection of the environment. Compliance with these laws and regulations may require us to remediate environmental damage from any discharge of petroleum, natural gas or chemical substances from our facilities or require us to install additional pollution control equipment on our equipment and facilities. Our failure to comply with these or any other environmental or safety-related regulations could result in the assessment of administrative, civil, or criminal penalties, the imposition of investigatory and remedial liabilities, and the issuance of injunctions that may subject us to additional operational constraints.
Future expenditures may be required to comply with the federal, state and local environmental requirements for our various sites, including our storage facilities, pipelines, gas processing complexes and refined products terminals. The impact of these legislative and regulatory developments, if enacted or adopted, could result in increased compliance costs and additional operating restrictions on our business, each of which could have an adverse impact on our liquidity, financial position or results of operations. 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 and Part II, Item 1 of this Quarterly Report on Form 10-Q 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;

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• | 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 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;

• | 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;

• | 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 update any information contained herein or to publicly release the results of any revisions to any forward-looking statements that may be made to reflect events or circumstances that occur, or that we become aware of, after the date of this Quarterly Report on Form 10-Q.
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
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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.
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 $3.3 billion and $3.4 billion as of June 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 June 30, 2016, would change annual interest expense by less than $1 million. As of June 30, 2016, we had $239 million of borrowings outstanding under our Dropdown Credit Facility. The were no borrowings outstanding under our Revolving Credit Facility as of June 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 June 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.
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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. The following discussion should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2015. Although we cannot provide assurance, we believe that an adverse resolution of the matters described below will not have a material impact on our liquidity, consolidated financial position, or results of operations.
TIOGA, NORTH DAKOTA CRUDE OIL PIPELINE RELEASE. In September 2013, the Partnership responded to the release of crude oil in a rural field northeast of Tioga, North Dakota (the “Crude Oil Pipeline Release”). The environmental liabilities related to the Crude Oil Pipeline Release include amounts estimated for remediation activities that will be conducted to restore the site for agricultural use. We have liabilities totaling $19 million and $27 million at June 30, 2016 and December 31, 2015, respectively. This incident was covered by our pollution legal liability insurance policy, subject to a $1 million deductible and a $25 million loss limit. Pursuant to this policy, 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.
On March 24, 2016, we received a closure letter from the U.S. Department of Transportation, through the Pipeline and Hazardous Materials Safety Administration (“PHMSA”) concerning PHMSA’s October 31, 2013 safety order related to the Crude Oil Pipeline Release. No further action is required to comply with the safety order.
QUESTAR GAS COMPANY V. QEP FIELD SERVICES COMPANY. Prior to the acquisition of all of the limited liability company interests of QEP Field Services, LLP (“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.
XTO ENERGY INC. V. QEP FIELD SERVICES COMPANY. XTO Energy Inc. (“XTO”) filed a complaint on January 30, 2014, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, unjust enrichment and an accounting 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 $22 million of allocated charges they are challenging, 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.
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
We may acquire units to satisfy tax withholding obligations in connection with the vesting of units issued to certain employees. There were no such units acquired during the three months ended June 30, 2016.
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OTHER INFORMATION AND EXHIBITS |  |

ITEM 5. OTHER INFORMATION
QEP MIDSTREAM, LP LONG-TERM INCENTIVE PLAN. On July 20, 2016, the Amended and Restated QEP Midstream, LP Long-Term Incentive Plan (the “Plan”) was terminated. The Plan had 1,633,411 units authorized and available for issuance as of December 31, 2015 that are no longer available as a result of the termination. These units were inadvertently omitted in the table regarding Tesoro Logistics GP, LLC’s equity compensation plans in Part III, Item 12 of our Annual Report on Form 10-K for December 31, 2015.
WAIVER AND RELEASE OF THE AMENDED & RESTATED MANAGEMENT STABILITY AGREEMENT. On August 2, 2016, Tesoro Corporation and Don J. Sorensen entered into a Waiver and Release (“the “Waiver”) to the Amended & Restated Management Stability Agreement originally executed on December 31, 2008 (the “Agreement”). Under the terms of the Waiver, Mr. Sorensen waived and released any and all rights and benefits under the Agreement and the parties formally terminated the Agreement. In light of such termination of the Agreement, Mr. Sorensen will participate in Tesoro’s Executive Severance and CIC Plan.
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).
*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.
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 |  | Amendment No. 2 to Secondment and Logistics Services Agreement, dated as of March 31, 2016, among Tesoro Refining & Marketing Company LLC, Tesoro Companies Inc., Tesoro Alaska Company LLC, Tesoro Great Plains Midstream LLC, Tesoro Great Plains Gathering and Marketing LLC, BakkenLink Pipeline LLC, ND Land Holdings LLC, Tesoro Alaska Terminals LLC, Tesoro Logistics GP LLC, Tesoro Logistics Operations LLC, Tesoro Logistics Pipelines LLC, Tesoro High Plains Pipeline Company LLC, Tesoro Logistics Northwest Pipeline LLC, Tesoro Alaska Pipeline Company LLC, QEP Field Services LLC, QEP Midstream Partners Operating LLC, QEPM Gathering I LLC, Rendezvous Pipeline Company LLC, and Green River Processing LLC (incorporated by reference herein to Exhibit 10.1 to the Partnership’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016, File No. 1-35143).
10.2 |  | 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).
10.3 |  | 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).
10.4 |  | 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).
*#10.5 |  | Amended and Restated Tesoro Corporation Executive Severance and Change in Control Plan effective May 1, 2013.
*#10.6 |  | Waiver and Release of the Amended & Restated Management Stability Agreement of Don J. Sorenson.
*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.

Tesoro Logistics LP 2016 | 35

EXHIBITS |  |

Exhibit Number |  | Description of Exhibit
*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

# | Compensatory plan or arrangement

36 | Tesoro Logistics LP 2016

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: | August 4, 2016 | By: | /s/ GREGORY J. GOFF
|  |  | Gregory J. Goff
|  |  | Chief Executive Officer
|  |  | (Principal Executive Officer)
Date: | August 4, 2016 | By: | /s/ STEVEN M. STERIN
|  |  | Steven M. Sterin
|  |  | Executive Vice President and Chief Financial Officer
|  |  | (Principal Financial Officer)

Tesoro Logistics LP 2016 | 37