10-Q 1 a2018033110q20180331.htm 10-Q
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
________________________________________________________________________________________________________________________
FORM 10-Q
________________________________________________________________________________________________________________________
(Mark One)

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

For the quarterly period ended March 31, 2018

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

For the transition period from to
Commission File No. 001-36550
________________________________________________________________________________________________________________________
PAR PACIFIC HOLDINGS, INC.
(Exact name of registrant as specified in its charter)
________________________________________________________________________________________________________________________

Delaware | 84-1060803
(State or other jurisdiction of | (I.R.S. Employer
incorporation or organization) | Identification No.)

800 Gessner Road, Suite 875 |
Houston, Texas | 77024
(Address of principal executive offices) | (Zip Code)

(281) 899-4800
(Registrant’s telephone number, including area code)
(Former name, former address and former fiscal year, if changed since last report)

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 ý No ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, 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 ý No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer | ¨ |  | Accelerated filer | ý
Non-accelerated filer | ¨ | (Do not check if a smaller reporting company) | Smaller reporting company | ¨
|  |  | Emerging growth company | ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Securities Act. Yes ¨ No ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ¨ No ý
45,881,918 shares of Common Stock, $0.01 par value, were outstanding as of May 4, 2018.

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
TABLE OF CONTENTS

PART I FINANCIAL INFORMATION | Page No.
Item 1. | Financial Statements |
| Condensed Consolidated Balance Sheets | 1
| Condensed Consolidated Statements of Operations | 2
| Condensed Consolidated Statements of Cash Flows | 3
| Notes to Condensed Consolidated Financial Statements | 4
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 23
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 40
Item 4. | Controls and Procedures | 42
PART II OTHER INFORMATION |
Item 1. | Legal Proceedings | 42
Item 1A. | Risk Factors | 42
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 42
Item 3. | Defaults Upon Senior Securities | 43
Item 4. | Mine Safety Disclosures | 43
Item 5. | Other Information | 43
Item 6. | Exhibits | 44

The terms “Par,” “Company,” “we,” “our,” and “us” refer to Par Pacific Holdings, Inc. and its consolidated subsidiaries unless the context suggests otherwise.

PART I - FINANCIAL INFORMATION
Item 1. FINANCIAL STATEMENTS
PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(in thousands, except share and per share data)

| March 31, 2018 |  | December 31, 2017
ASSETS |  |  |  |  |
Current assets |  |  |  |
Cash and cash equivalents | $ | 64,957 |  |  | $ | 118,333 |
Restricted cash | 743 |  |  | 744 |
Total cash, cash equivalents, and restricted cash | 65,700 |  |  | 119,077 |
Trade accounts receivable | 128,123 |  |  | 121,831 |
Inventories | 296,267 |  |  | 345,357 |
Prepaid and other current assets | 98,137 |  |  | 17,279 |
Total current assets | 588,227 |  |  | 603,544 |
Property and equipment |  |  |  |
Property, plant, and equipment | 566,257 |  |  | 529,238 |
Proved oil and gas properties, at cost, successful efforts method of accounting | 400 |  |  | 400 |
Total property and equipment | 566,657 |  |  | 529,638 |
Less accumulated depreciation and depletion | (87,691 | ) |  | (79,622 | )
Property and equipment, net | 478,966 |  |  | 450,016 |
Long-term assets |  |  |  |
Investment in Laramie Energy, LLC | 132,768 |  |  | 127,192 |
Intangible assets, net | 25,940 |  |  | 26,604 |
Goodwill | 152,884 |  |  | 107,187 |
Other long-term assets | 29,340 |  |  | 32,864 |
Total assets | $ | 1,408,125 |  |  | $ | 1,347,407 |
LIABILITIES AND STOCKHOLDERS’ EQUITY |  |  |  |
Current liabilities |  |  |  |
Obligations under inventory financing agreements | $ | 383,806 |  |  | $ | 363,756 |
Accounts payable | 61,096 |  |  | 52,543 |
Deferred revenue | 10,021 |  |  | 9,522 |
Accrued taxes | 19,286 |  |  | 17,687 |
Other accrued liabilities | 34,971 |  |  | 27,444 |
Total current liabilities | 509,180 |  |  | 470,952 |
Long-term liabilities |  |  |  |
Long-term debt, net of current maturities | 386,500 |  |  | 384,812 |
Common stock warrants | 6,063 |  |  | 6,808 |
Long-term capital lease obligations | 6,387 |  |  | 1,220 |
Other liabilities | 36,196 |  |  | 35,896 |
Total liabilities | 944,326 |  |  | 899,688 |
Commitments and contingencies (Note 12) |  |  |  |  |
Stockholders’ equity |  |  |  |
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued | — |  |  | — |
Common stock, $0.01 par value; 500,000,000 shares authorized at March 31, 2018 and December 31, 2017, 46,018,511 shares and 45,776,087 shares issued at March 31, 2018 and December 31, 2017, respectively | 459 |  |  | 458 |
Additional paid-in capital | 594,189 |  |  | 593,295 |
Accumulated deficit | (132,993 | ) |  | (148,178 | )
Accumulated other comprehensive income | 2,144 |  |  | 2,144 |
Total stockholders’ equity | 463,799 |  |  | 447,719 |
Total liabilities and stockholders’ equity | $ | 1,408,125 |  |  | $ | 1,347,407 |

See accompanying notes to the condensed consolidated financial statements.
1

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
(in thousands, except per share amounts)

| Three Months Ended
| March 31,
| 2018 |  | 2017
Revenues | $ | 765,439 |  |  | $ | 605,253 |
Operating expenses |  |  |
Cost of revenues (excluding depreciation) | 661,899 |  |  | 501,289 |
Operating expense (excluding depreciation) | 51,010 |  |  | 50,348 |
Depreciation, depletion, and amortization | 13,037 |  |  | 11,260 |
General and administrative expense (excluding depreciation) | 11,205 |  |  | 12,914 |
Acquisition and integration expense | 632 |  |  | 253 |
Total operating expenses | 737,783 |  |  | 576,064 |
Operating income | 27,656 |  |  | 29,189 |
Other income (expense) |  |  |
Interest expense and financing costs, net | (8,377 | ) |  | (8,942 | )
Other income, net | 119 |  |  | 130 |
Change in value of common stock warrants | 745 |  |  | (689 | )
Change in value of contingent consideration | (10,500 | ) |  | — |
Equity earnings from Laramie Energy, LLC | 5,576 |  |  | 8,746 |
Total other income (expense), net | (12,437 | ) |  | (755 | )
Income before income taxes | 15,219 |  |  | 28,434 |
Income tax expense | (34 | ) |  | (648 | )
Net income | $ | 15,185 |  |  | $ | 27,786 |
Income per share |  |  |
Basic | $ | 0.33 |  |  | $ | 0.60 |
Diluted | $ | 0.33 |  |  | $ | 0.58 |
Weighted-average number of shares outstanding |  |  |
Basic | 45,634 |  |  | 45,476 |
Diluted | 45,677 |  |  | 51,865 |

See accompanying notes to the condensed consolidated financial statements.
2

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(in thousands)

| Three Months Ended March 31,
| 2018 |  | 2017
Cash flows from operating activities: |  |  |  |  |
Net income | $ | 15,185 |  |  | $ | 27,786 |
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities: |  |  |  |  |
Depreciation, depletion, and amortization | 13,037 |  |  | 11,260 |
Non-cash interest expense | 1,864 |  |  | 2,364 |
Change in value of common stock warrants | (745 | ) |  | 689 |
Deferred taxes | 31 |  |  | 202 |
Stock-based compensation | 1,439 |  |  | 2,536 |
Unrealized (gain) loss on derivative contracts | (846 | ) |  | (1,488 | )
Equity (earnings) losses from Laramie Energy, LLC | (5,576 | ) |  | (8,746 | )
Net changes in operating assets and liabilities: |  |  |  |  |
Trade accounts receivable | (6,086 | ) |  | 6,362 |
Prepaid and other assets | (79,117 | ) |  | 32,049 |
Inventories | 53,484 |  |  | (94,743 | )
Obligations under inventory financing agreements | (1,494 | ) |  | 76,515 |
Accounts payable and other accrued liabilities | 21,465 |  |  | (29,792 | )
Net cash provided by operating activities | 12,641 |  |  | 24,994 |
Cash flows from investing activities: |  |  |  |  |
Acquisitions of businesses, net of cash acquired | (74,680 | ) |  | — |
Capital expenditures | (9,612 | ) |  | (7,579 | )
Net cash used in investing activities | (84,292 | ) |  | (7,579 | )
Cash flows from financing activities: |  |  |  |  |
Proceeds from borrowings | 25,000 |  |  | 74,700 |
Repayments of borrowings | (27,655 | ) |  | (91,636 | )
Net borrowings (repayments) on deferred payment arrangement | 21,544 |  |  | (1,912 | )
Payment of deferred loan costs | (72 | ) |  | — |
Other financing activities, net | (543 | ) |  | (128 | )
Net cash provided by (used in) financing activities | 18,274 |  |  | (18,976 | )
Net decrease in cash, cash equivalents, and restricted cash | (53,377 | ) |  | (1,561 | )
Cash, cash equivalents, and restricted cash at beginning of period | 119,077 |  |  | 49,018 |
Cash, cash equivalents, and restricted cash at end of period | $ | 65,700 |  |  | $ | 47,457 |
Supplemental cash flow information: |  |  |  |  |
Net cash received (paid) for: |  |  |
Interest | $ | 3,219 |  |  | $ | (5,249 | )
Taxes | — |  |  | — |
Non-cash investing and financing activities: |  |  |  |  |
Accrued capital expenditures | $ | 1,466 |  |  | $ | 1,676 |

See accompanying notes to the condensed consolidated financial statements.
3

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Note 1—Overview
Par Pacific Holdings, Inc. and its wholly owned subsidiaries (“Par” or the “Company”) own, manage, and maintain interests in energy and infrastructure businesses. Currently, we operate in three primary business segments:
1) Refining - Our refinery in Kapolei, Hawaii, produces ultra-low sulfur diesel (“ULSD”), gasoline, jet fuel, marine fuel, low sulfur fuel oil (“LSFO”), and other associated refined products primarily for consumption in Hawaii. Our refinery in Newcastle, Wyoming, produces gasoline, ULSD, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota.
2) Retail - Our retail outlets in Hawaii sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our Hawaii retail network includes Hele and “76” branded retail sites, company-operated convenience stores, 7-Eleven operated convenience stores, other sites operated by third parties, and unattended cardlock stations. We recently completed the rebranding of 10 of our 34 company-operated convenience stores in Hawaii to “nomnom,” a new proprietary brand. Our retail outlets in Washington and Idaho sell gasoline, diesel, and retail merchandise and operate under the “Cenex®” and “Zip Trip®” brand names.
3) Logistics - We own and operate terminals, pipelines, a single-point mooring (“SPM”), and trucking operations to distribute refined products throughout the islands of Oahu, Maui, Hawaii, Molokai, and Kauai. In addition, we own and operate a crude oil pipeline gathering system, a refined products pipeline, storage facilities, and loading racks in Wyoming. We also own and operate a jet fuel storage facility and pipeline that serve the Ellsworth Air Force Base in South Dakota.
We own a 39.1% equity investment in Laramie Energy, LLC (“Laramie Energy”). Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado.
Our Corporate and Other reportable segment includes administrative costs and several small non-operated oil and gas interests that were owned by our predecessor.
Note 2—Summary of Significant Accounting Policies
Principles of Consolidation and Basis of Presentation
The condensed consolidated financial statements include the accounts of Par and its subsidiaries. All intercompany balances and transactions have been eliminated in consolidation. Certain amounts previously reported in our condensed consolidated financial statements for prior periods have been reclassified to conform with the current presentation.
The accompanying condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, the instructions to Form 10-Q, and Article 10 of Regulation S-X of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Accordingly, they do not include all of the information and notes required by GAAP for complete consolidated financial statements. The condensed consolidated financial statements contained in this report include all material adjustments of a normal recurring nature that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods presented. The results of operations for the interim periods presented are not necessarily indicative of the results that may be expected for the complete fiscal year or for any other period. The condensed consolidated balance sheet as of December 31, 2017 was derived from our audited consolidated financial statements as of that date. These condensed consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2017.
Use of Estimates
The preparation of our condensed consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the related disclosures. Actual amounts could differ from these estimates.
Inventories
Beginning in 2018, Inventories also include Renewable Identification Numbers (“RINs”). RINs are stated at the lower of cost or net realizable value. The net cost of RINs is recognized within Cost of revenues (excluding depreciation) in our condensed consolidated statements of operations.
4

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Cost Classifications
Cost of revenues (excluding depreciation) includes the hydrocarbon-related costs of inventory sold, transportation costs of delivering product to customers, crude oil consumed in the refining process, costs to satisfy our RINs obligations, and certain hydrocarbon fees and taxes. Cost of revenues (excluding depreciation) also includes the unrealized gains (losses) on derivatives and inventory valuation adjustments. Certain direct operating expenses related to our logistics segment are also included in Cost of revenues (excluding depreciation).
Operating expense (excluding depreciation) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, and environmental compliance costs as well as chemicals and catalysts and other direct operating expenses.
The following table summarizes depreciation expense excluded from each line item in our consolidated statements of operations (in thousands):

|  | Three Months Ended March 31,
|  | 2018 |  | 2017
Cost of revenues |  | $ | 1,607 |  |  | $ | 1,457 |
Operating expense |  | 6,904 |  |  | 5,634 |
General and administrative expense |  | 1,147 |  |  | 721 |

Recent Accounting Pronouncements
There have been no developments to recent accounting pronouncements, including the expected dates of adoption and estimated effects on our financial condition, results of operations, and cash flows, from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2017, except for the following:
In February 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income ("ASU 2018-02"). This ASU permits entities to elect to reclassify to retained earnings the stranded effects in Accumulated Other Comprehensive Income related to the changes in the statutory tax rate that were charged to income from continuing operations under the requirements of ASC 740. The guidance in ASU 2018-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. Management is still evaluating the effects of the available adoption methods and has not yet determined which method will be elected.
Accounting Principles Adopted
On January 1, 2018, we adopted ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), as amended by other ASUs issued since May 2014 (“ASU 2014-09”), using the modified retrospective method as permitted. Under this method, the cumulative effect of initially applying ASU 2014-09 is recognized as an adjustment to the opening balance of retained earnings (or accumulated deficit) and revenues reported in the periods prior to the date of adoption are not changed. Because the adoption of ASU 2014-09 did not have a material impact on the amount or timing of revenues recognized for the sale of refined products, we did not make such an adjustment to retained earnings. Please read Note 5—Revenue Recognition for further information.
On January 1, 2018, we adopted ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (“ASU 2016-15”) and ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (“ASU 2016-18”). The primary purpose of ASU 2016-15 was to reduce the diversity in practice relating to eight specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies); distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle. ASU 2016-18 required that an entity include restricted cash and restricted cash equivalents within its statement of cash flows and in the reconciliation to the statement of operations. As the new guidance must be applied using a retrospective transition method, we have also retrospectively revised the comparative period Statement of Cash Flows to reflect the adoption of these ASUs. The adoption of these ASUs did not have a material impact on our financial condition, results of operations, or cash flows.
5

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
On January 1, 2018, we adopted ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business (“ASU 2017-01”). This ASU updated the definition of a business combination and provided a framework for determining whether a transaction involves an asset or a business. The adoption of this ASU changed the policy under which we perform our assessments and accounting for future acquisition or disposal transactions, including the Northwest Retail Acquisition. Please read Note 4—Acquisitions for further information.
On January 1, 2018, we adopted ASU 2017-07, Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (“ASU 2017-07”). This ASU required entities to (1) disaggregate the current-service-cost component from the other components of net benefit cost (the “other components”) and present it with other current compensation costs for related employees in the income statement and (2) present the other components elsewhere in the income statement and outside of income from operations if that subtotal is presented. In addition, the ASU required entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. As the other components of our net benefit cost are not material, we have not retrospectively revised our comparative periods presented in the statement of operations.
On January 1, 2018, we adopted ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU was to reduce the diversity in practice and cost and complexity in applying the guidance in Topic 718 related to the change to terms or conditions of a share-based payment award. The adoption of ASU 2017-09 did not have a material impact on our financial condition, results of operations, or cash flows.
In March 2018, the FASB issued ASU No. 2018-05, Income Taxes (Topic 740): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 ("ASU 2018-05"). Under ASU 2018-05, an entity would estimate, to the extent possible, the impacts of the Tax Cut and Jobs Act enacted on December 22, 2017 (“U.S. tax reform”) and then adjust the estimates when better information is available or the amount becomes determinable over something similar to the measurement period under business combination guidance. This ASU was effective upon issuance. As of March 31, 2018, we believe the impacts of the U.S. tax reform have been reasonably estimated and recorded within our condensed consolidated financial statements.
Note 3—Investment in Laramie Energy, LLC
We have a 39.1% ownership interest in Laramie Energy. Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado. On February 28, 2018, Laramie Energy closed on a purchase and contribution agreement with an unaffiliated third party that contributed all of its oil and gas properties located in the Piceance Basin and a $23.5 million cash payment, collectively with a fair market value of $28.1 million, into Laramie Energy in exchange for 70,227 of Laramie Energy's newly issued Class A Units. As a result of this transaction, our ownership interest in Laramie Energy decreased from 42.3% to 39.1%.
Laramie Energy has a $400 million revolving credit facility with a borrowing base currently set at $230 million that is secured by a lien on its natural gas and crude oil properties and related assets. As of March 31, 2018, the balance outstanding on the revolving credit facility was approximately $172.5 million. We are guarantors of Laramie Energy’s credit facility, with recourse limited to the pledge of our equity interest of our wholly owned subsidiary, Par Piceance Energy Equity, LLC. Under the terms of its credit facility, Laramie Energy is generally prohibited from making future cash distributions to its owners, including us.
The change in our equity investment in Laramie Energy is as follows (in thousands):

| Three Months Ended March 31, 2018
Beginning balance | $ | 127,192 |
Equity earnings from Laramie Energy | 4,303 |
Accretion of basis difference | 1,273 |
Ending balance | $ | 132,768 |

6

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Summarized financial information for Laramie Energy is as follows (in thousands):

| March 31, 2018 |  | December 31, 2017
Current assets | $ | 23,626 |  |  | $ | 18,757 |
Non-current assets | 776,181 |  |  | 720,444 |
Current liabilities | 33,218 |  |  | 42,149 |
Non-current liabilities | 270,150 |  |  | 237,497 |

| Three Months Ended March 31,
| 2018 |  | 2017
Natural gas and oil revenues | $ | 46,681 |  |  | $ | 40,612 |
Income from operations | 6,044 |  |  | 1,163 |
Net income | 7,290 |  |  | 17,528 |

Laramie Energy's net income for the three months ended March 31, 2018 includes $14.9 million of depreciation, depletion, and amortization (“DD&A”) and $4.6 million of unrealized gain on derivative instruments. Laramie Energy’s net income for the three months ended March 31, 2017 includes $13.3 million of DD&A and $24.2 million of unrealized gain on derivative instruments.
At March 31, 2018 and December 31, 2017, our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $61.5 million and $67.2 million, respectively. This difference arose due to lack of control and marketability discounts and an other-than-temporary impairment of our equity investment in Laramie Energy in 2015. We attributed this difference to natural gas and crude oil properties and are amortizing the difference over 15 years based on the estimated timing of production of proved reserves.
Note 4—Acquisitions
On January 9, 2018, we entered into an Asset Purchase Agreement with CHS, Inc. to acquire twenty-one (21) owned retail gasoline, convenience store facilities and twelve (12) leased retail gasoline, convenience store facilities, all at various locations in Washington and Idaho (collectively, “Northwest Retail”). On March 23, 2018, we completed the acquisition for cash consideration of approximately $75 million (the “Northwest Retail Acquisition”).
As part of the Northwest Retail Acquisition, Par and CHS, Inc. entered into a multi-year branded petroleum marketing agreement for the continued supply of Cenex®-branded refined products to the acquired Cenex® Zip Trip convenience stores. In addition, the parties also entered into a multi-year supply agreement pursuant to which Par will supply refined products to CHS, Inc. within the Rocky Mountain and Pacific Northwest markets.
We accounted for the acquisition of Northwest Retail as a business combination whereby the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Northwest Retail and utilization of our net operating loss carryforwards, as well as trade names and other intangible assets that do not qualify for separate recognition. The acquired trade names will be amortized over their estimated useful lives on a straight-line basis, which approximates their consumptive life.
7

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
A summary of the preliminary fair value of the assets acquired and liabilities assumed is as follows (in thousands):

Cash | $ | 128 |
Trade accounts receivable | 152 |
Inventories | 4,394 |
Prepaid and other current assets | 198 |
Property, plant and equipment | 30,254 |
Goodwill (1) | 45,683 |
Accounts payable and other current liabilities | (757 | )
Long-term capital lease obligations | (5,244 | )
Total | $ | 74,808 |

________________________________________________________
(1) The total goodwill balance of $45.7 million was allocated to our retail segment.
We have recorded a preliminary estimate of the fair value of the assets acquired and liabilities assumed and expect to finalize the purchase price allocation during 2018.
We incurred $0.6 million of acquisition and integration costs related to the Northwest Retail Acquisition for the three months ended March 31, 2018. These costs are included in Acquisition and integration expense on our consolidated statement of operations.
Note 5—Revenue Recognition
On January 1, 2018, we adopted ASU 2014-09 (ASC Topic 606) using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. As such, the comparative financial information for prior periods has not been adjusted and continues to be reported under ASC Topic 605. We did not identify any significant differences in our existing revenue recognition policies that require modification under the new standard; therefore, we did not recognize a cumulative adjustment on opening equity as of January 1, 2018.
As of March 31, 2018 and December 31, 2017, receivables from contracts with customers were $112.5 million and $112.3 million, respectively. Our refining segment recognizes deferred revenues when cash payments are received in advance of delivery of products to the customer. Deferred revenue was $10.0 million and $9.5 million as of March 31, 2018 and December 31, 2017, respectively. We have elected to apply a practical expedient to not disclose the value of unsatisfied performance obligations for contracts with an original expected duration of less than one year.
Refining and Retail
Our refining and retail segment revenues are primarily associated with the sale of refined products. We recognize revenues upon delivery of refined products to a customer, which is the point in time at which title and risk of loss is transferred to the customer. The refining segment’s contracts with its customers state the terms of the sale, including the description, quantity, delivery terms, and price of each product sold. Payments from customers are generally due in full within 2 to 30 days of product delivery or invoice date.
We account for certain transactions on a net basis under FASB ASC Topic 845, “Nonmonetary Transactions”. These transactions include nonmonetary crude oil and refined product exchange transactions, certain crude oil buy/sell arrangements, and sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.
Upon adoption of Topic ASC 606, we made an accounting policy election to apply the sales tax practical expedient, whereby all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within Cost of revenues (excluding depreciation). This change in our accounting policy did not have a material impact on our consolidated financial information for the three months ended March 31, 2018.
Logistics
We recognize transportation and storage fees as services are provided to a customer. Substantially all of our logistics revenues represent intercompany transactions that are eliminated in consolidation.
8

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
The following table provides information about disaggregated revenue by major product line and includes a reconciliation of the disaggregated revenue with reportable segments (in thousands):

Three Months Ended March 31, 2018 |  | Refining |  | Logistics |  | Retail
Product or service: |  |  |  |  |  |
Gasoline |  | $ | 239,261 |  |  | $ | — |  |  | $ | 58,202 |
Distillates (1) |  | 398,529 |  |  | — |  |  | 6,996 |
Other refined products (2) |  | 102,473 |  |  | — |  |  | — |
Merchandise |  | — |  |  | — |  |  | 13,394 |
Transportation and terminalling services |  | — |  |  | 33,067 |  |  | — |
Total segment revenues |  | $ | 740,263 |  |  | $ | 33,067 |  |  | $ | 78,592 |

_______________________________________________________

(1) | Distillates primarily include diesel and jet fuel.

(2) | Other refined products include fuel oil, gas oil, and naphtha.

Note 6—Inventories
Inventories at March 31, 2018 consisted of the following (in thousands):

| Titled Inventory |  | Supply and Offtake Agreements (1) |  | Total
Crude oil and feedstocks | $ | 14,538 |  |  | $ | 62,977 |  |  | $ | 77,515 |
Refined products and blendstock | 57,926 |  |  | 116,383 |  |  | 174,309 |
Warehouse stock and other (2) | 44,443 |  |  | — |  |  | 44,443 |
Total | $ | 116,907 |  |  | $ | 179,360 |  |  | $ | 296,267 |

Inventories at December 31, 2017 consisted of the following (in thousands):

| Titled Inventory |  | Supply and Offtake Agreements (1) |  | Total
Crude oil and feedstocks | $ | 93,970 |  |  | $ | 56,014 |  |  | $ | 149,984 |
Refined products and blendstock | 63,505 |  |  | 108,917 |  |  | 172,422 |
Warehouse stock and other | 22,951 |  |  | — |  |  | 22,951 |
Total | $ | 180,426 |  |  | $ | 164,931 |  |  | $ | 345,357 |

________________________________________________________

(1) | Please read Note 8—Inventory Financing Agreements for further information.

(2) | Includes $18.3 million of RINs.

As of March 31, 2018 and December 31, 2017, there was no reserve for the lower of cost or net realizable value of inventory.
Note 7—Prepaid and Other Current Assets
Prepaid and other current assets at March 31, 2018 and December 31, 2017 consisted of the following (in thousands):

| March 31, 2018 |  | December 31, 2017
Advances to suppliers for crude oil purchases | $ | 76,410 |  |  | $ | — |
Collateral posted with broker for derivative instruments | 11 |  |  | 215 |
Prepaid insurance | 5,306 |  |  | 7,547 |
Derivative assets | 7,432 |  |  | 4,296 |
Other | 8,978 |  |  | 5,221 |
Total | $ | 98,137 |  |  | $ | 17,279 |

Note 8—Inventory Financing Agreements
Supply and Offtake Agreements
On June 1, 2015, we entered into several agreements with J. Aron & Company (“J. Aron”) to support the operations of our Hawaii refinery (the “Supply and Offtake Agreements”). On May 8, 2017, we and J. Aron amended the Supply and Offtake Agreements and extended the term through May 31, 2021 with a one-year extension option upon mutual agreement of the parties. As part of this amendment, J. Aron may enter into agreements with third parties whereby J. Aron will remit payments to these third parties for refinery procurement contracts for which we will become immediately obligated to reimburse J. Aron. As of March 31, 2018, we had no obligations due to J. Aron under this letter of credit agreement. On December 21, 2017, in connection with the issuance of the 7.75% Senior Secured Notes, we amended and restated the Supply and Offtake Agreements to update the terms of the collateral as noted below.
During the term of the Supply and Offtake Agreements, we and J. Aron will identify mutually acceptable contracts for the purchase of crude oil from third parties. Per the Supply and Offtake Agreements, J. Aron will provide up to 94 thousand barrels per day of crude oil to our Hawaii refinery. Additionally, we agreed to sell and J. Aron agreed to buy, at market prices, refined
9

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
products produced at our Hawaii refinery. We will then repurchase the refined products from J. Aron prior to selling the refined products to our retail operations or to third parties. The agreements also provide for the lease of crude oil and certain refined product storage facilities to J. Aron. Following the expiration or termination of the Supply and Offtake Agreements, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at the leased storage facilities at then-current market prices.
Though title to the crude oil and certain refined product inventories resides with J. Aron, the Supply and Offtake Agreements are accounted for similar to a product financing arrangement; therefore, the crude oil and refined products inventories will continue to be included on our condensed consolidated balance sheets until processed and sold to a third party. Each reporting period, we record a liability in an amount equal to the amount we expect to pay to repurchase the inventory held by J. Aron based on current market prices.
For the three months ended March 31, 2018, we incurred approximately $4.8 million in handling fees related to the Supply and Offtake Agreements, which is included in Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations. For the three months ended March 31, 2017, we incurred approximately $3.1 million in handling fees related to the Supply and Offtake Agreements. For the three months ended March 31, 2018, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.7 million of expenses related to the Supply and Offtake Agreements. For the three months ended March 31, 2017, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.8 million of expenses related to the Supply and Offtake Agreements.
The Supply and Offtake Agreements also include a deferred payment arrangement (“Deferred Payment Arrangement”) whereby we can defer payments owed under the agreements up to the lesser of $125 million or 85% of the eligible accounts receivable and inventory. Upon execution of the Supply and Offtake Agreements, we paid J. Aron a deferral arrangement fee of $1.3 million. The deferred amounts under the Deferred Payment Arrangement bear interest at a rate equal to three-month LIBOR plus 3.75% per annum. We also agreed to pay a deferred payment availability fee equal to 0.75% of the unused capacity under the Deferred Payment Arrangement. Amounts outstanding under the Deferred Payment Arrangement are included in Obligations under inventory financing agreements on our condensed consolidated balance sheets. Changes in the amount outstanding under the Deferred Payment Arrangement are included within Cash flows from financing activities on the condensed consolidated statements of cash flows. As of March 31, 2018 and December 31, 2017, the capacity of the Deferred Payment Arrangement was $73.1 million and $83.1 million, respectively. As of March 31, 2018 and December 31, 2017, we had $62.7 million and $41.1 million outstanding, respectively.
Under the Supply and Offtake Agreements, we pay or receive certain fees from J. Aron based on changes in market prices over time. In February 2016, we fixed the market fee for the period from December 1, 2016 through May 31, 2018 for $14.6 million to be settled in eighteen equal monthly payments. In 2017, we fixed the market fee for the period from June 1, 2018 through May 2021 for an additional $2.2 million. The receivable from J. Aron was recorded as a reduction to our Obligations under inventory financing agreements pursuant to our Master Netting Agreement. As of March 31, 2018 and December 31, 2017, the receivable was $4.7 million and $7.1 million, respectively.
The agreements also provide us with the ability to economically hedge price risk on our inventories and crude oil purchases. Please read Note 10—Derivatives for further information.
Note 9—Debt
The following table summarizes our outstanding debt (in thousands):

| March 31, 2018 |  | December 31, 2017
5.00% Convertible Senior Notes due 2021 | $ | 115,000 |  |  | $ | 115,000 |
7.75% Senior Secured Notes due 2025 | 300,000 |  |  | 300,000 |
ABL Credit Facility | — |  |  | — |
Principal amount of long-term debt | 415,000 |  |  | 415,000 |
Less: unamortized discount and deferred financing costs | (28,500 | ) |  | (30,188 | )
Total debt, net of unamortized discount and deferred financing costs | 386,500 |  |  | 384,812 |
Less: current maturities | — |  |  | — |
Long-term debt, net of current maturities | $ | 386,500 |  |  | $ | 384,812 |

10

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Our debt is subject to various affirmative and negative covenants. As of March 31, 2018, we were in compliance with all debt covenants. Under the ABL Credit Facility and the indenture governing the 7.75% Senior Secured Notes, our subsidiaries are restricted from paying dividends or making other equity distributions, subject to certain exceptions.
7.75% Senior Secured Notes Due 2025
On December 21, 2017, Par Petroleum, LLC and Par Petroleum Finance Corp. (collectively, the "Issuers"), both our wholly-owned subsidiaries, completed the issuance and sale of $300 million in aggregate principal amount of 7.75% Senior Secured Notes in a private placement under Rule 144A and Regulation S of the Securities Act of 1933, as amended. The net proceeds of $289.2 million (net of financing costs and original issue discount of 1%) from the sale were used to repay our previous credit facilities and the forward sale agreement with J. Aron and for general corporate purposes.
The 7.75% Senior Secured Notes bear interest at a rate of 7.750% per year beginning December 21, 2017 (payable semi-annually in arrears on June 15 and December 15 of each year, beginning on June 15, 2018) and will mature on December 15, 2025.
ABL Credit Facility
On December 21, 2017, in connection with the issuance of the 7.75% Senior Secured Notes, Par Petroleum, LLC, Par Hawaii Inc., Mid Pac Petroleum, LLC (“Mid Pac”), HIE Retail, LLC, and Wyoming Refining Company (“WRC”) (collectively, the “ABL Borrowers”), entered into a Loan and Security Agreement dated as of December 21, 2017 (the “ABL Credit Facility”) with certain lenders and Bank of America, N.A., as administrative agent and collateral agent. The ABL Credit Facility provides for a revolving credit facility in the maximum principal amount at any time outstanding of $75 million, subject to a borrowing base, which provides for revolving loans and for the issuance of letters of credit (the “ABL Revolver”). The ABL Revolver had no outstanding balance as of March 31, 2018 and had a borrowing base of approximately $47.2 million at March 31, 2018.
5.00% Convertible Senior Notes Due 2021
As of March 31, 2018, the outstanding principal amount of the 5.00% Convertible Senior Notes was $115.0 million, the unamortized discount and deferred financing cost was $18.3 million, and the carrying amount of the liability component was $96.7 million.
Cross Default Provisions
Included within each of our debt agreements are customary cross default provisions that require the repayment of amounts outstanding on demand should an event of default occur and not be cured within the permitted grace period, if any. As of March 31, 2018, we are in compliance with all of our debt agreements.
Guarantors
In connection with our shelf registration statement on Form S-3, which was filed with the Securities and Exchange Commission (“SEC”) on September 2, 2016 and declared effective on September 16, 2016 (“Registration Statement”), we may sell non-convertible debt securities and other securities in one or more offerings with an aggregate initial offering price of up to $750 million. Any non-convertible debt securities issued under the Registration Statement may be fully and unconditionally guaranteed (except for customary release provisions), on a joint and several basis, by some or all of our subsidiaries, other than subsidiaries that are “minor” within the meaning of Rule 3-10 of Regulation S-X (the “Guarantor Subsidiaries”). We have no “independent assets or operations” within the meaning of Rule 3-10 of Regulation S-X and certain of the Guarantor Subsidiaries may be subject to restrictions on their ability to distribute funds to us, whether by cash dividends, loans, or advances.
Note 10—Derivatives
Commodity Derivatives
We utilize crude oil commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, future sales of refined products, and crude oil consumption in our refining process. The derivative contracts that we execute to manage our price risk include exchange traded futures, options, and over-the-counter (“OTC”) swaps. Our futures, options, and OTC swaps are marked-to-market and changes in the fair value of these contracts are recognized within Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations.
We are obligated to repurchase the crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements. We have determined that this obligation contains an embedded derivative, similar to forward purchase contracts of crude oil and refined products. As such, we have accounted for this embedded derivative at fair value with changes in the fair
11

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
value recorded in Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations. We are required under the Supply and Offtake Agreements to hedge the time spread between the period of crude oil cargo pricing and the month of delivery. We utilize OTC swaps to accomplish this.
We have entered into forward purchase contracts for crude oil and forward sales contracts of refined products. We elect the normal purchases normal sales (“NPNS”) exception for all forward contracts that meet the definition of a derivative and are not expected to net settle. Any gains and losses with respect to these forward contracts designated as NPNS are not reflected in earnings until the delivery occurs.
We elect to offset fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. Our condensed consolidated balance sheets present derivative assets and liabilities on a net basis. Please read Note 11—Fair Value Measurements for the gross fair value and net carrying value of our derivative instruments. Our cash margin that is required as collateral deposits cannot be offset against the fair value of open contracts except in the event of default.
At March 31, 2018, our open commodity derivative contracts represented:

• | OTC swap purchases of 210 thousand barrels that economically hedge our crude oil and refined products month-end target volumes related to our Supply and Offtake Agreements;

• | futures and OTC swap contracts of 30 thousand barrels that economically hedge our purchases of ethanol;

• | futures purchases contracts of 305 thousand barrels that economically hedge our sales of refined products; and

• | option collars of 60 thousand barrels per month and OTC swaps of 15 thousand barrels per month, both through December 2018, that economically hedge our internally consumed fuel.

Interest Rate Derivatives
We are exposed to interest rate volatility in our outstanding debt and in the Supply and Offtake Agreements. We utilize interest rate swaps to manage our interest rate risk. As of March 31, 2018, we had locked in an average fixed rate of 0.97% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $100 million. The interest rate swaps mature in February 2019. In February 2018, we terminated a separate $100 million floating interest rate swap originally maturing in March 2021, which resulted in a realized gain of $3.7 million.
Our 5.00% Convertible Senior Notes include a redemption option and a related make-whole premium which represent an embedded derivative that is not clearly and closely related to the 5.00% Convertible Senior Notes. As such, we have accounted for this embedded derivative at fair value with changes in the fair value recorded in Interest expense and financing costs, net, on our condensed consolidated statements of operations. As of March 31, 2018, this embedded derivative was deemed to have a de minimis fair value.
The following table provides information on the fair value amounts (in thousands) of these derivatives as of March 31, 2018 and December 31, 2017 and their placement within our condensed consolidated balance sheets.

| Balance Sheet Location |  | March 31, 2018 |  | December 31, 2017
|  |  | Asset (Liability)
Commodity derivatives (1) | Prepaid and other current assets |  | $ | 6,281 |  |  | $ | 2,814 |
Commodity derivatives | Other accrued liabilities |  | — |  |  | (39 | )
J. Aron repurchase obligation derivative | Obligations under inventory financing agreements |  | (13,222 | ) |  | (19,564 | )
Interest rate derivatives | Prepaid and other current assets |  | 1,151 |  |  | 1,482 |
Interest rate derivatives | Other long-term assets |  | — |  |  | 2,328 |

_________________________________________________________

(1) | Does not include cash collateral of $11.0 thousand and $0.2 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of March 31, 2018 and December 31, 2017, respectively.

12

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
The following table summarizes the pre-tax gains (losses) recognized in Net income (loss) on our condensed consolidated statements of operations resulting from changes in fair value of derivative instruments not designated as hedges charged directly to earnings (in thousands):

|  |  | Three Months Ended March 31,
| Statement of Operations Location |  | 2018 |  | 2017
Commodity derivatives | Cost of revenues (excluding depreciation) |  | $ | 4,932 |  |  | $ | (6,367 | )
J. Aron repurchase obligation derivative | Cost of revenues (excluding depreciation) |  | 6,342 |  |  | 10,607 |
Interest rate derivatives | Interest expense and financing costs, net |  | 1,236 |  |  | 110 |

Note 11—Fair Value Measurements
Assets and Liabilities Measured at Fair Value on a Recurring Basis
Common Stock Warrants
As of March 31, 2018 and December 31, 2017, we had 354,350 common stock warrants outstanding. We estimate the fair value of our outstanding common stock warrants using the difference between the strike price of the warrant and the market price of our common stock, which is a Level 3 fair value measurement. As of March 31, 2018 and December 31, 2017, the warrants had a weighted-average exercise price of $0.09 and $0.09 and a remaining term of 4.42 years and 4.67 years, respectively.
The estimated fair value of the common stock warrants was $17.11 and $19.21 per share as of March 31, 2018 and December 31, 2017, respectively.
Derivative Instruments
We utilize crude oil commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil, future sales of refined products, and cost of crude oil consumed in the refining process. We utilize interest rate swaps to manage our interest rate risk.
We classify financial assets and liabilities according to the fair value hierarchy. Financial assets and liabilities classified as Level 1 instruments are valued using quoted prices in active markets for identical assets and liabilities. These include our exchange traded futures. Level 2 instruments are valued using quoted prices for similar assets and liabilities in active markets and inputs other than quoted prices that are observable for the asset or liability. Our Level 2 instruments include OTC swaps and options. These commodity derivatives are valued using market quotations from independent price reporting agencies and commodity exchange price curves that are corroborated with market data. Level 3 instruments are valued using significant unobservable inputs that are not supported by sufficient market activity. The valuation of our J. Aron repurchase obligation derivative requires that we make estimates of the prices and differentials assuming settlement at the end of the reporting period; therefore, it is classified as a Level 3 instrument. We do not have other commodity derivatives classified as Level 3 at March 31, 2018 or December 31, 2017. Please read Note 10—Derivatives for further information on derivatives.
13

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Financial Statement Impact
Fair value amounts by hierarchy level as of March 31, 2018 and December 31, 2017 are presented gross in the tables below (in thousands):

| March 31, 2018
| Level 1 |  | Level 2 |  | Level 3 |  | Gross Fair Value |  | Effect of Counter-Party Netting |  | Net Carrying Value on Balance Sheet (1)
Assets |  |  |  |  |  |  |  |  |  |  |
Commodity derivatives | $ | 1,114 |  |  | $ | 32,452 |  |  | $ | — |  |  | $ | 33,566 |  |  | $ | (27,285 | ) |  | $ | 6,281 |
Interest rate derivatives | — |  |  | 1,151 |  |  | — |  |  | 1,151 |  |  | — |  |  | 1,151 |
Total | $ | 1,114 |  |  | $ | 33,603 |  |  | $ | — |  |  | $ | 34,717 |  |  | $ | (27,285 | ) |  | $ | 7,432 |
Liabilities |  |  |  |  |  |  |  |  |  |  |
Common stock warrants | $ | — |  |  | $ | — |  |  | $ | (6,063 | ) |  | $ | (6,063 | ) |  | $ | — |  |  | $ | (6,063 | )
Commodity derivatives | (149 | ) |  | (27,136 | ) |  | — |  |  | (27,285 | ) |  | 27,285 |  |  | — |
J. Aron repurchase obligation derivative | — |  |  | — |  |  | (13,222 | ) |  | (13,222 | ) |  | — |  |  | (13,222 | )
Total | $ | (149 | ) |  | $ | (27,136 | ) |  | $ | (19,285 | ) |  | $ | (46,570 | ) |  | $ | 27,285 |  |  | $ | (19,285 | )

| December 31, 2017
| Level 1 |  | Level 2 |  | Level 3 |  | Gross Fair Value |  | Effect of Counter-Party Netting |  | Net Carrying Value on Balance Sheet (1)
Assets |  |  |  |  |  |  |  |  |  |  |
Commodity derivatives | $ | 557 |  |  | $ | 21,907 |  |  | $ | — |  |  | $ | 22,464 |  |  | $ | (19,650 | ) |  | $ | 2,814 |
Interest rate derivatives | — |  |  | 3,810 |  |  | — |  |  | 3,810 |  |  | — |  |  | 3,810 |
Total | $ | 557 |  |  | $ | 25,717 |  |  | $ | — |  |  | $ | 26,274 |  |  | $ | (19,650 | ) |  | $ | 6,624 |
Liabilities |  |  |  |  |  |  |  |  |  |  |
Common stock warrants | $ | — |  |  | $ | — |  |  | $ | (6,808 | ) |  | $ | (6,808 | ) |  | $ | — |  |  | $ | (6,808 | )
Commodity derivatives | (596 | ) |  | (19,093 | ) |  | — |  |  | (19,689 | ) |  | 19,650 |  |  | (39 | )
J. Aron repurchase obligation derivative | — |  |  | — |  |  | (19,564 | ) |  | (19,564 | ) |  | — |  |  | (19,564 | )
Total | $ | (596 | ) |  | $ | (19,093 | ) |  | $ | (26,372 | ) |  | $ | (46,061 | ) |  | $ | 19,650 |  |  | $ | (26,411 | )

_________________________________________________________

(1) | Does not include cash collateral of $7.0 million and $7.2 million as of March 31, 2018 and December 31, 2017, respectively, included within Prepaid and other current assets and Other long-term assets on our condensed consolidated balance sheets.

14

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
A roll forward of Level 3 financial instruments measured at fair value on a recurring basis is as follows (in thousands):

| Three Months Ended March 31,
| 2018 |  | 2017
Balance, at beginning of period | $ | (26,372 | ) |  | $ | (25,134 | )
Settlements | — |  |  | — |
Total unrealized income (loss) included in earnings | 7,087 |  |  | 9,919 |
Balance, at end of period | $ | (19,285 | ) |  | $ | (15,215 | )

The carrying value and fair value of long-term debt and other financial instruments as of March 31, 2018 and December 31, 2017 are as follows (in thousands):

| March 31, 2018
| Carrying Value |  | Fair Value
5.00% Convertible Senior Notes due 2021 (1) (3) | $ | 96,674 |  |  | $ | 136,951 |
7.75% Senior Secured Notes due 2025 (1) | 289,826 |  |  | 303,855 |
Common stock warrants (2) | 6,063 |  |  | 6,063 |

| December 31, 2017
| Carrying Value |  | Fair Value
5.00% Convertible Senior Notes due 2021 (1) (3) | $ | 95,486 |  |  | $ | 149,007 |
7.75% Senior Secured Notes due 2025 (1) | 289,326 |  |  | 300,423 |
Common stock warrants (2) | 6,808 |  |  | 6,808 |

_________________________________________________________

(1) | The fair values measurements of the 5.00% Convertible Senior Notes and the 7.75% Senior Secured Notes are considered Level 2 measurements as discussed below.

(2) | The fair value of the common stock warrants is considered a Level 3 measurement in the fair value hierarchy.

(3) | The carrying value of the 5.00% Convertible Senior Notes excludes the fair value of the equity component, which was classified as equity upon issuance.

The fair value of the 5.00% Convertible Senior Notes was determined by aggregating the fair value of the liability and equity components of the notes. The fair value of the liability component of the 5.00% Convertible Senior Notes was determined using a discounted cash flow analysis in which the projected interest and principal payments were discounted at an estimated market yield for a similar debt instrument without the conversion feature. The equity component was estimated based on the Black-Scholes model for a call option with strike price equal to the conversion price, a term matching the remaining life of the 5.00% Convertible Senior Notes, and an implied volatility based on market values of options outstanding as of March 31, 2018. The fair value of the 5.00% Convertible Senior Notes is considered a Level 2 measurement in the fair value hierarchy.
The fair value of the 7.75% Senior Secured Notes was determined using a market approach based on quoted prices. Because the 7.75% Senior Secured Notes may not be actively traded, the inputs used to measure the fair value are classified as Level 2 inputs within the fair value hierarchy.
The fair value of all non-derivative financial instruments recorded in current assets, including cash and cash equivalents, restricted cash, and trade accounts receivable, and current liabilities, including accounts payable, approximate their carrying value due to their short-term nature.
Note 12—Commitments and Contingencies
In the ordinary course of business, we are a party to various lawsuits and other contingent matters. We establish accruals for specific legal matters when we determine that the likelihood of an unfavorable outcome is probable and the loss is reasonably estimable. It is possible that an unfavorable outcome of one or more of these lawsuits or other contingencies could have a material impact on our financial condition, results of operations, or cash flows.
15

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Tesoro Earn-out Dispute
On June 17, 2013, a wholly owned subsidiary of Par entered into a membership interest purchase agreement with Andeavor Corporation, formerly known as Tesoro Corporation (“Tesoro”), pursuant to which the subsidiary purchased all of the issued and outstanding membership interests in Tesoro Hawaii, LLC, an entity that was renamed Hawaii Independent Energy, LLC, and thereafter renamed Par Hawaii Refining, LLC (“PHR”). The cash consideration for the acquisition was subject to an earn-out provision during the years 2014-2016, subject to, among other things, an annual earn-out cap of $20 million and an overall cap of $40 million. During 2016, we paid Tesoro a total of $16.8 million to settle the 2014 and 2015 earn-out periods. Tesoro disputed our calculation of the 2015 and 2016 earn-out amounts and asserted that it was entitled to an additional earn-out amount of $4.3 million for the 2015 earn-out period and a total earn-out amount of $8.3 million for the 2016 earn-out period. On March 22, 2018, Tesoro agreed to settle the earnout dispute and release and discharge any related claims in exchange for our payment of $10.5 million.
Mid Pac Earnout and Indemnity Dispute
Pursuant to a Stock Purchase Agreement dated August 3, 2011 and amended October 25, 2011 (the “SPA”), Mid Pac purchased all the issued and outstanding stock of Inter Island Petroleum, Inc. (“Inter Island”) from Brian J. and Wendy Barbata (collectively, the “Barbatas”). The SPA provides for an earn-out payment to be made to the Barbatas in an amount equal to four times the amount by which the average of Inter Island’s earnings before interest, taxes, depreciation, and amortization during the relevant earn-out period exceeds $3.5 million. The earn-out payment is capped at a maximum of $4.5 million. Mid Pac contends that there are no amounts owed to the Barbatas for the earn-out period, while the Barbatas contend they are entitled to $4.5 million. Mid Pac intends to vigorously oppose any such claims.
Any claims by the Barbatas may be offset by Mid Pac’s claims for indemnification under the SPA. By letters dated December 31, 2013 and April 25, 2014, Mid Pac has asserted indemnification claims against the Barbatas exceeding $1 million with respect to environmental losses arising from certain terminals operated by Inter Island and its subsidiaries. The Barbatas have disputed such claims. Arbitration for the earn-out and indemnification claims is scheduled to commence on November 27, 2018.
United Steelworkers Union Dispute
A portion of our employees at the Hawaii refinery are represented by the United Steelworkers Union (“USW”). On March 23, 2015, the union ratified a four-year extension of the collective bargaining agreement. On January 13, 2016, the USW filed a claim against PHR before the United States National Labor Relations Board (the “NLRB”) alleging a refusal to bargain collectively and in good faith. On March 29, 2016, the NLRB deferred final determination on the USW charge to the grievance/arbitration process under the extant collective bargaining agreement. Arbitration has been scheduled for the week of October 1, 2018. PHR denies the USW’s allegations and intends to vigorously defend itself in connection with such claim in the grievance/arbitration process and any subsequent proceeding before the NLRB.
Environmental Matters
Like other petroleum refiners and exploration and production companies, our operations are subject to extensive and periodically-changing federal and state environmental regulations governing air emissions, wastewater discharges, and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent and the cost of compliance can be expected to increase over time.
Periodically, we receive communications from various federal, state, and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective actions for these asserted violations. We intend to respond in a timely manner to all such communications and to take appropriate corrective action. Except as disclosed below, we do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations, or cash flows.
Our Hawaii refinery and our Wyoming refinery were each granted a one-year small refinery exemption for the year 2017 from the U.S. Environmental Protection Agency (“EPA”). Owing primarily to the receipt of these small refinery exemptions, our first quarter 2018 net income includes a $13.2 million RINs benefit.
Wyoming refinery
Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the EPA and/or the Wyoming Department of Environmental Quality, some of which date back to the late 1970s and several of which remain in effect, requiring further actions at the Wyoming refinery. The largest cost component arising from these various decrees relates to the investigation, monitoring, and remediation of soil, groundwater, surface water, and sediment contamination associated with
16

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
the facility’s historic operations. Investigative work by Wyoming Refining and negotiations with the relevant agencies as to remedial approaches remain ongoing on a number of aspects of the contamination, meaning that investigation, monitoring, and remediation costs are not reasonably estimable for some elements of these efforts. As of March 31, 2018, we have accrued $17.8 million for the well-understood components of these efforts based on current information, approximately one-third of which we expect to incur in the next five years and the remainder being incurred over approximately 30 years.
Additionally, we believe the Wyoming refinery will need to modify or close a series of wastewater impoundments in the next several years and replace those impoundments with a new wastewater treatment system. Based on current information, reasonable estimates we have received suggest costs of approximately $11.6 million to design and construct a new wastewater treatment system.
Finally, among the various historic consent decrees, orders, and settlement agreements into which WRC and its wholly owned subsidiary, Wyoming Pipeline Company (collectively, “Wyoming Refining”) has entered, there are several penalty orders associated with exceedances of permitted limits by the Wyoming refinery’s wastewater discharges. Although the frequency of these exceedances has declined over time, Wyoming Refining may become subject to new penalty enforcement action in the next several years, which could involve penalties in excess of $100 thousand.
Regulation of Greenhouse Gases
The EPA regulates greenhouse gases (“GHG”) under the federal Clean Air Act (“CAA”). New construction or material expansions that meet certain GHG emissions thresholds will likely require that, among other things, a GHG permit be issued in accordance with the federal CAA regulations and we will be required, in connection with such permitting, to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce GHG emissions.
Furthermore, the EPA is currently developing refinery-specific GHG regulations and performance standards that are expected to impose GHG emission limits and/or technology requirements. These control requirements may affect a wide range of refinery operations. Any such controls could result in material increased compliance costs, additional operating restrictions for our business, and an increase in the cost of the products we produce, which could have a material adverse effect on our financial condition, results of operations, or cash flows.
On September 29, 2015, the EPA announced a final rule updating standards that control toxic air emissions from petroleum refineries, addressing, among other things, flaring operations, fenceline air quality monitoring, and additional emission reductions from storage tanks and delayed coking units. Affected existing sources will be required to comply with the new requirements no later than 2018, with certain refiners required to comply earlier depending on the relevant provision and refinery construction date. We do not anticipate that compliance with this rule will have a material impact on our financial condition, results of operations, or cash flows.
In 2007, the State of Hawaii passed Act 234, which required that GHG emissions be rolled back on a statewide basis to 1990 levels by the year 2020. Although delayed, the Hawaii Department of Health has issued regulations that would require each major facility to reduce CO 2 emissions by 16% by 2020 relative to a calendar year 2010 baseline (the first year in which GHG emissions were reported to the EPA under 40 CFR Part 98). Those rules are pending final approval by the Hawaii State Government. The Hawaii refinery’s capacity to reduce fuel use and GHG emissions is limited. However, the state’s pending regulation allows, and the Hawaii refinery expects to be able to demonstrate, that additional reductions are not cost-effective or necessary in light of the state’s current GHG inventory and future year projections. The pending regulation allows for “partnering” with other facilities (principally power plants) that have already dramatically reduced greenhouse emissions or are on schedule to reduce CO 2 emissions in order to comply with the state’s Renewable Portfolio Standards.
Fuel Standards
In 2007, the U.S. Congress passed the Energy Independence and Security Act of 2007 (the “EISA”) that, among other things, set a target fuel economy standard of 35 miles per gallon for the combined fleet of cars and light trucks in the U.S. by model year 2020 and contained a second Renewable Fuel Standard (the “RFS2”). In August 2012, the EPA and National Highway Traffic Safety Administration jointly adopted regulations that establish an average industry fuel economy of 54.5 miles per gallon by model year 2025. The RFS2 requires an increasing amount of renewable fuel usage, up to 36 billion gallons by 2022. In the near term, the RFS2 will be satisfied primarily with fuel ethanol blended into gasoline. The RFS2 may present production and logistics challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase credits from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.
17

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
In October 2010, the EPA issued a partial waiver decision under the CAA to allow for an increase in the amount of ethanol permitted to be blended into gasoline from 10% (“E10”) to 15% (“E15”) for 2007 and newer light duty motor vehicles. In January 2011, the EPA issued a second waiver for the use of E15 in vehicles model years 2001-2006. There are numerous issues, including state and federal regulatory issues, that need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines. Consequently, unless either the state or federal regulations are revised, RINs will be required to fulfill the federal mandate for renewable fuels.
In March 2014, the EPA published a final Tier 3 gasoline standard that lowers the allowable sulfur level in gasoline to 10 parts per million (“ppm”) and also lowers the allowable benzene, aromatics, and olefins content of gasoline, with the most recent rulemaking addressing certain technical corrections and clarifications effective June 21, 2016. The effective date for the new standard was January 1, 2017, however, approved small volume refineries have until January 1, 2020 to meet the standard. As noted above, our refineries were granted small volume refinery status by the EPA for 2017.
There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in the EISA and other fuel-related regulations. Along with credit and trading options, potential capital upgrades for the Hawaii and Wyoming refineries are being evaluated. We may also experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels.
Environmental Agreement
On September 25, 2013, Par Petroleum, LLC (formerly Hawaii Pacific Energy, a wholly owned subsidiary of Par created for purposes of the PHR acquisition), Tesoro, and PHR entered into an Environmental Agreement (“Environmental Agreement”) that allocated responsibility for known and contingent environmental liabilities related to the acquisition of PHR, including the Consent Decree as described below.
Consent Decree
On July 18, 2016, PHR and subsidiaries of Tesoro entered into a consent decree with the EPA, the U.S. Department of Justice (“DOJ”), and other state governmental authorities concerning alleged violations of the federal CAA related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (“Consent Decree”), including our Hawaii refinery. As a result of the Consent Decree, PHR expanded its previously-announced 2016 Hawaii refinery turnaround to undertake additional capital improvements to reduce emissions of air pollutants and to provide for certain nitrogen oxide and sulfur dioxide emission controls and monitoring and to install certain lock detection and repair equipment required by the Consent Decree. Although the turnaround was completed during the third quarter of 2016, work related to the Consent Decree is ongoing. This work subjects us to risks associated with engineering, procurement, and construction of improvements and repairs to our facilities and related penalties and fines to the extent applicable deadlines under the Consent Decree are not satisfied, as well as risks related to the performance of equipment required by, or affected by, the Consent Decree. Each of these risks could have a material adverse effect on our business, financial condition, or results of operations.
Tesoro is responsible under the Environmental Agreement for directly paying, or reimbursing PHR, for all reasonable third-party capital expenditures incurred pursuant to the Consent Decree to the extent related to acts or omissions prior to the date of the closing of the PHR acquisition. Tesoro is obligated to pay all applicable fines and penalties related to the Consent Decree. Through March 31, 2018, Tesoro has reimbursed us for $12.2 million of the total capital expenditures of $12.9 million incurred in connection with the Consent Decree. Net capital expenditures and reimbursements related to the Consent Decree for the three months ended March 31, 2018 and 2017 are presented within Capital expenditures on our condensed consolidated statement of cash flows for the related periods. As of March 31, 2018, we estimate the remaining capital expenditures associated with the Consent Decree to be approximately $1 million, which we have not yet requested Tesoro to reimburse under the Environmental Agreement, subject to their rights thereunder.
Indemnification
In addition to its obligation to reimburse us for capital expenditures incurred pursuant to the Consent Decree, Tesoro agreed to indemnify us for claims and losses arising out of related breaches of Tesoro’s representations, warranties, and covenants in the Environmental Agreement, certain defined “corrective actions” relating to pre-existing environmental conditions, third-party claims arising under environmental laws for personal injury or property damage arising out of or relating to releases of hazardous materials that occurred prior to the date of the closing of the PHR acquisition, any fine, penalty, or other cost assessed by a governmental authority in connection with violations of environmental laws by PHR prior to the date of the closing of the PHR acquisition, certain groundwater remediation work, fines, or penalties imposed on PHR by the Consent Decree related to acts or omissions of Tesoro prior to the date of the closing of the PHR acquisition, and claims and losses related to the Pearl City Superfund Site.
18

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
Tesoro’s indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a deductible of $1 million and a cap of $15 million for certain of Tesoro’s indemnification obligations related to certain pre-existing conditions, as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions.
Recovery Trusts
We emerged from the reorganization of Delta Petroleum Corporation (“Delta”) on August 31, 2012 (“Emergence Date”) when the plan of reorganization (“Plan”) was consummated. On the Emergence Date, we formed the Delta Petroleum General Recovery Trust (“General Trust”). The General Trust was formed to pursue certain litigation against third parties, including preference actions, fraudulent transfer and conveyance actions, rights of setoff and other claims, or causes of action under the U.S. Bankruptcy Code and other claims and potential claims that Delta and its subsidiaries (collectively, “Debtors”) hold against third parties. On February 27, 2018, the Bankruptcy Court entered its final decree closing the Chapter 11 bankruptcy cases of Delta and the other Debtors, discharging the trustee for the General Trust, and finding that all assets of the General Trust were resolved, abandoned, or liquidated and have been distributed in accordance with the requirements of the Plan. In addition, the final decree required the Company or the General Trust, as applicable, to maintain the current accruals owed on account of the remaining claims of the U.S. Government and Noble Energy, Inc.
As of March 31, 2018, two related claims totaling approximately $22.4 million remained to be resolved and we have accrued approximately $0.5 million representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end.
One of the two remaining claims was filed by the U.S. Government for approximately $22.4 million relating to ongoing litigation concerning a plugging and abandonment obligation in Pacific Outer Continental Shelf Lease OCS-P 0320, comprising part of the Sword Unit in the Santa Barbara Channel, California. The second unliquidated claim, which is related to the same plugging and abandonment obligation, was filed by Noble Energy Inc., the operator and majority interest owner of the Sword Unit. We believe the probability of issuing stock to satisfy the full claim amount is remote, as the obligations upon which such proof of claim is asserted are joint and several among all working interest owners and Delta, our predecessor, only owned an approximate 3.4% aggregate working interest in the unit.
The settlement of claims is subject to ongoing litigation and we are unable to predict with certainty how many shares will be required to satisfy all claims. Pursuant to the Plan, allowed claims were settled at a ratio of 54.4 shares per $1,000 of claim.
Note 13—Stockholders’ Equity
Incentive Plan
The following table summarizes our compensation costs recognized in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) under the Amended and Restated Par Pacific Holdings, Inc. 2012 Long-term Incentive Plan and Stock Purchase Plan (in thousands):

| Three Months Ended March 31,
| 2018 |  | 2017
Restricted Stock Awards | $ | 843 |  |  | $ | 1,703 |
Restricted Stock Units | 150 |  |  | 84 |
Stock Option Awards | 446 |  |  | 750 |

During the three months ended March 31, 2018, we granted 229 thousand shares of restricted stock and restricted stock units with a fair value of approximately $4.0 million. As of March 31, 2018, there were approximately $8.7 million of total unrecognized compensation costs related to restricted stock awards and restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 3.0 years.
During the three months ended March 31, 2018, we granted 252 thousand stock option awards with a weighted-average exercise price of $17.34 per share. As of March 31, 2018, there were approximately $4.7 million of total unrecognized compensation costs related to stock option awards, which are expected to be recognized on a straight-line basis over a weighted-average period of 2.9 years.
During the three months ended March 31, 2018, we granted 49 thousand performance restricted stock units to executive officers. These performance restricted stock units had a fair value of approximately $0.8 million and are subject to certain annual
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PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
performance targets as defined by our Board of Directors. As of March 31, 2018, there were approximately $1.3 million of total unrecognized compensation costs related to the performance restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 2.6 years.
Note 14—Income (Loss) per Share
Basic income (loss) per share is computed by dividing net income (loss) by the sum of the weighted-average number of common shares outstanding and the weighted-average number of shares issuable under the common stock warrants, representing 354 thousand shares during the three months ended March 31, 2018 and 352 thousand shares during the three months ended March 31, 2017, respectively. The common stock warrants are included in the calculation of basic income (loss) per share because they are issuable for minimal consideration. The following table sets forth the computation of basic and diluted income (loss) per share (in thousands, except per share amounts):

| Three Months Ended March 31,
| 2018 |  | 2017
Net income | $ | 15,185 |  |  | $ | 27,786 |
Less: Undistributed income allocated to participating securities (1) | 192 |  |  | 299 |
Net income attributable to common stockholders | 14,993 |  |  | 27,487 |
Plus: Net income effect of convertible securities | — |  |  | 2,509 |
Numerator for diluted income per common share | $ | 14,993 |  |  | $ | 29,996 |
Basic weighted-average common stock shares outstanding | 45,634 |  |  | 45,476 |
Plus: dilutive effects of common stock equivalents | 43 |  |  | 6,389 |
Diluted weighted-average common stock shares outstanding | 45,677 |  |  | 51,865 |
Basic income per common share | $ | 0.33 |  |  | $ | 0.60 |
Diluted income per common share | $ | 0.33 |  |  | $ | 0.58 |

________________________________________________________

(1) | Participating securities include restricted stock that has been issued but has not yet vested.

For the three months ended March 31, 2018, our calculation of diluted shares outstanding excluded 46 thousand shares of unvested restricted stock and 1.3 million stock options. For the three months ended March 31, 2017, our calculation of diluted shares outstanding excluded 120 thousand shares of unvested restricted stock and 2.0 million stock options.
As discussed in Note 9—Debt, we have the option of settling the 5.00% Convertible Senior Notes in cash or shares of common stock, or any combination thereof, upon conversion. For the three months ended March 31, 2018 and March 31, 2017, diluted income (loss) per share was determined using the if-converted method. Our calculation of diluted shares outstanding for the three months ended March 31, 2018 excluded 6.4 million common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on January 1, 2018.
Note 15—Income Taxes
In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future results of operations, and tax planning strategies in making this assessment. Based upon the level of historical taxable income, significant book losses during recent prior periods, and projections for future results of operations over the periods in which the deferred tax assets are deductible, among other factors, management continues to conclude that we did not meet the “more likely than not” requirement in order to recognize deferred tax assets and a valuation allowance has been recorded for substantially all of our net deferred tax assets at March 31, 2018.
During the three months ended March 31, 2018 and 2017, no adjustments were recognized for uncertain tax positions.
As of December 31, 2017, we had approximately $1.6 billion in net operating loss carryforwards (“NOL carryforwards”); however, we currently have a valuation allowance against this and substantially all of our other deferred taxed assets. We will
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PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017
continue to assess the realizability of our deferred tax assets based on consideration of actual and projected operating results and tax planning strategies. Should actual operating results continue to improve, the amount of the deferred tax asset considered more likely than not to be realizable could be increased.
Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our NOL carryforwards will not always be available to offset taxable income apportioned to the various states. The states from which our refining, retail, and logistics revenues are derived are not the same states in which our NOLs were incurred; therefore, we expect to incur state tax liabilities on the net income of our refining, retail, and logistics operations.
Note 16—Segment Information
We report the results for the following four business segments: (i) Refining, (ii) Retail, (iii) Logistics, and (iv) Corporate and Other. Beginning in the first quarter of 2018, the results of operations of Northwest Retail are included in our retail segment.
Summarized financial information concerning reportable segments consists of the following (in thousands):

Three Months Ended March 31, 2018 |  | Refining |  | Logistics |  | Retail |  | Corporate, Eliminations and Other (1) |  | Total
Revenues |  | $ | 740,263 |  |  | $ | 33,067 |  |  | $ | 78,592 |  |  | $ | (86,483 | ) |  | $ | 765,439 |
Cost of revenues (excluding depreciation) |  | 668,479 |  |  | 20,810 |  |  | 59,147 |  |  | (86,537 | ) |  | 661,899 |
Operating expense (excluding depreciation) |  | 37,349 |  |  | 1,822 |  |  | 11,839 |  |  | — |  |  | 51,010 |
Depreciation, depletion, and amortization |  | 8,362 |  |  | 1,642 |  |  | 1,868 |  |  | 1,165 |  |  | 13,037 |
General and administrative expense (excluding depreciation) |  | — |  |  | — |  |  | — |  |  | 11,205 |  |  | 11,205 |
Acquisition and integration expense |  | — |  |  | — |  |  | — |  |  | 632 |  |  | 632 |
Operating income (loss) |  | $ | 26,073 |  |  | $ | 8,793 |  |  | $ | 5,738 |  |  | $ | (12,948 | ) |  | $ | 27,656 |
Interest expense and financing costs, net |  |  |  |  |  |  |  |  |  | (8,377 | )
Other income, net |  |  |  |  |  |  |  |  |  | 119 |
Change in value of common stock warrants |  |  |  |  |  |  |  |  |  | 745 |
Change in value of contingent consideration |  |  |  |  |  |  |  |  |  | (10,500 | )
Equity earnings from Laramie Energy, LLC |  |  |  |  |  |  |  |  |  | 5,576 |
Income before income taxes |  |  |  |  |  |  |  |  |  | 15,219 |
Income tax expense |  |  |  |  |  |  |  |  |  | (34 | )
Net income |  |  |  |  |  |  |  |  |  | $ | 15,185 |
Capital expenditures |  | $ | 4,974 |  |  | $ | 2,683 |  |  | $ | 701 |  |  | $ | 1,254 |  |  | $ | 9,612 |

21

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
For the Interim Periods Ended March 31, 2018 and 2017

Three Months Ended March 31, 2017 |  | Refining |  | Logistics |  | Retail |  | Corporate, Eliminations and Other (1) |  | Total
Revenues |  | $ | 574,079 |  |  | $ | 29,995 |  |  | $ | 77,682 |  |  | $ | (76,503 | ) |  | $ | 605,253 |
Cost of revenues (excluding depreciation) |  | 503,044 |  |  | 15,298 |  |  | 59,799 |  |  | (76,852 | ) |  | 501,289 |
Operating expense (excluding depreciation) |  | 36,216 |  |  | 3,797 |  |  | 10,315 |  |  | 20 |  |  | 50,348 |
Depreciation, depletion, and amortization |  | 7,403 |  |  | 1,487 |  |  | 1,448 |  |  | 922 |  |  | 11,260 |
General and administrative expense (excluding depreciation) |  | — |  |  | — |  |  | — |  |  | 12,914 |  |  | 12,914 |
Acquisition and integration expense |  | — |  |  | — |  |  | — |  |  | 253 |  |  | 253 |
Operating income (loss) |  | $ | 27,416 |  |  | $ | 9,413 |  |  | $ | 6,120 |  |  | $ | (13,760 | ) |  | $ | 29,189 |
Interest expense and financing costs, net |  |  |  |  |  |  |  |  |  | (8,942 | )
Other income, net |  |  |  |  |  |  |  |  |  | 130 |
Change in value of common stock warrants |  |  |  |  |  |  |  |  |  | (689 | )
Equity earnings from Laramie Energy, LLC |  |  |  |  |  |  |  |  |  | 8,746 |
Income before income taxes |  |  |  |  |  |  |  |  |  | 28,434 |
Income tax expense |  |  |  |  |  |  |  |  |  | (648 | )
Net income |  |  |  |  |  |  |  |  |  | $ | 27,786 |
Capital expenditures |  | $ | 1,009 |  |  | $ | 1,197 |  |  | $ | 3,497 |  |  | $ | 1,876 |  |  | $ | 7,579 |

________________________________________________________

(1) | Includes eliminations of intersegment revenues and cost of revenues of $85.9 million and $77.2 million for the three months ended March 31, 2018 and 2017, respectively.

Note 17—Related Party Transactions
Equity Group Investments (“EGI”) - Service Agreement
On September 17, 2013, we entered into a letter agreement (“Services Agreement”) with Equity Group Investments (“EGI”), an affiliate of Zell Credit Opportunities Fund, LP (“ZCOF”), which owns 10% or more of our common stock directly or through affiliates. Pursuant to the Services Agreement, EGI agreed to provide us with ongoing strategic, advisory, and consulting services that may include (i) advice on financing structures and our relationship with lenders and bankers, (ii) advice regarding public and private offerings of debt and equity securities, (iii) advice regarding asset dispositions, acquisitions, or other asset management strategies, (iv) advice regarding potential business acquisitions, dispositions, or combinations involving us or our affiliates, or (v) such other advice directly related or ancillary to the above strategic, advisory, and consulting services as may be reasonably requested by us.
EGI does not receive a fee for the provision of the strategic, advisory, or consulting services set forth in the Services Agreement, but may be periodically reimbursed by us, upon request, for (i) travel and out-of-pocket expenses, provided that, in the event that such expenses exceed $50 thousand in the aggregate with respect to any single proposed matter, EGI will obtain our consent prior to incurring additional costs, and (ii) provided that we provide prior consent to their engagement with respect to any particular proposed matter, all reasonable fees and disbursements of counsel, accountants, and other professionals incurred in connection with EGI’s services under the Services Agreement. In consideration of the services provided by EGI under the Services Agreement, we agreed to indemnify EGI for certain losses relating to or arising out of the Services Agreement or the services provided thereunder.
The Services Agreement has a term of one year and will be automatically extended for successive one-year periods unless terminated by either party at least 60 days prior to any extension date. There were no significant costs incurred related to this agreement during the three months ended March 31, 2018 or 2017.
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Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Overview
We are a growth-oriented company headquartered in Houston, Texas, that manages and maintains interests in energy and infrastructure businesses. We were created through the successful reorganization of Delta in August 2012. The reorganization converted approximately $265 million of unsecured debt to equity and allowed us to preserve significant tax attributes.
Our business is organized into three primary operating segments:
1) Refining - Our refinery in Kapolei, Hawaii, produces ULSD, gasoline, jet fuel, marine fuel, LSFO, and other associated refined products primarily for consumption in Hawaii. Our refinery in Newcastle, Wyoming, produces gasoline, ULSD, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota.
2) Retail - Our retail outlets in Hawaii sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our Hawaii retail network includes Hele and “76” branded retail sites, company-operated convenience stores, 7-Eleven operated convenience stores, other sites operated by third parties, and unattended cardlock locations. We recently completed the rebranding of 10 of our 34 company-operated convenience stores in Hawaii to “nomnom,” a new proprietary brand. Our retail outlets in Washington and Idaho sell gasoline, diesel, and retail merchandise and operate under the “Cenex®” and “Zip Trip®” brand names.
3) Logistics - We own and operate terminals, pipelines, a single-point mooring (“SPM”), and trucking operations to distribute refined products throughout the islands of Oahu, Maui, Hawaii, Molokai, and Kauai. In addition, we own and operate a crude oil pipeline gathering system, a refined products pipeline, storage facilities, and loading racks in Wyoming. We also own and operate a jet fuel storage facility and pipeline that serve the Ellsworth Air Force Base in South Dakota.
We own a 39.1% equity investment in Laramie Energy. Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado.
We have four reportable segments: (i) Refining, (ii) Retail, (iii) Logistics, and (iv) Corporate and Other. Beginning in the first quarter of 2018, the results of operations of Northwest Retail are included in our retail segment. Our Corporate and Other reportable segment includes administrative costs and several small non-operated oil and gas interests that were owned by our predecessor. Please read Note 16—Segment Information to our condensed consolidated financial statements included in this Quarterly Report on Form 10-Q for detailed information on our operating results by segment.
Results of Operations
Three months ended March 31, 2018 compared to the three months ended March 31, 2017
Net Income (Loss). During 2018, our financial performance was primarily driven by a $10.5 million charge related to the Tesoro earn-out settlement and declining crack spreads and crude oil differentials, partially offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption. Our net income (loss) changed from a net income of $27.8 million for the three months ended March 31, 2017 to a net income of $15.2 million for the three months ended March 31, 2018. Other factors impacting our results period over period include the decrease in our Equity earnings (losses) from Laramie Energy and the change in value of common stock warrants.
Adjusted EBITDA and Adjusted Net Income (Loss). For the three months ended March 31, 2018, Adjusted EBITDA was $26.1 million compared to $32.3 million for the three months ended March 31, 2017. The change was primarily related to declining crack spreads and crude oil differentials, offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption.
For the three months ended March 31, 2018, Adjusted Net Income (Loss) was approximately $8.2 million compared to $10.0 million for the three months ended March 31, 2017. The change was primarily related to declining crack spreads and crude oil differentials, and a decrease in our Equity earnings (losses) from Laramie Energy. The decreases were partially offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption.
23

The following tables summarize our consolidated results of operations for the three months ended March 31, 2018 compared to the three months ended March 31, 2017 (in thousands). The following should be read in conjunction with our condensed consolidated financial statements and notes thereto included elsewhere in this Quarterly Report.

| Three Months Ended March 31, |  |  |  |
| 2018 |  | 2017 |  | $ Change |  | % Change(1)
Revenues | $ | 765,439 |  |  | $ | 605,253 |  |  | $ | 160,186 |  |  | 26 | %
Cost of revenues (excluding depreciation) | 661,899 |  |  | 501,289 |  |  | 160,610 |  |  | 32 | %
Operating expense (excluding depreciation) | 51,010 |  |  | 50,348 |  |  | 662 |  |  | 1 | %
Depreciation, depletion, and amortization | 13,037 |  |  | 11,260 |  |  | 1,777 |  |  | 16 | %
General and administrative expense (excluding depreciation) | 11,205 |  |  | 12,914 |  |  | (1,709 | ) |  | (13 | )%
Acquisition and integration expense | 632 |  |  | 253 |  |  | 379 |  |  | 150 | %
Total operating expenses | 737,783 |  |  | 576,064 |  |  |  |  |  |
Operating income | 27,656 |  |  | 29,189 |  |  |  |  |  |
Other income (expense) |  |  |  |  |  |  |  |
Interest expense and financing costs, net | (8,377 | ) |  | (8,942 | ) |  | 565 |  |  | 6 | %
Other income, net | 119 |  |  | 130 |  |  | (11 | ) |  | (8 | )%
Change in value of common stock warrants | 745 |  |  | (689 | ) |  | 1,434 |  |  | 208 | %
Change in value of contingent consideration | (10,500 | ) |  | — |  |  | (10,500 | ) |  | NM |
Equity earnings from Laramie Energy, LLC | 5,576 |  |  | 8,746 |  |  | (3,170 | ) |  | (36 | )%
Total other income (expense), net | (12,437 | ) |  | (755 | ) |  |  |  |  |
Income before income taxes | 15,219 |  |  | 28,434 |  |  |  |  |  |
Income tax expense | (34 | ) |  | (648 | ) |  | 614 |  |  | 95 | %
Net income | $ | 15,185 |  |  | $ | 27,786 |  |  |  |  |  |

________________________________________________________
(1) NM - Not meaningful
24

The following tables summarize our operating income (loss) by segment for the three months ended March 31, 2018 and 2017 (in thousands). The following should be read in conjunction with our condensed consolidated financial statements and notes thereto included elsewhere in this Quarterly Report.

Three months ended March 31, 2018 |  | Refining |  | Logistics |  | Retail |  | Corporate, Eliminations and Other (1) |  | Total
Revenues |  | $ | 740,263 |  |  | $ | 33,067 |  |  | $ | 78,592 |  |  | $ | (86,483 | ) |  | $ | 765,439 |
Cost of revenues (excluding depreciation) |  | 668,479 |  |  | 20,810 |  |  | 59,147 |  |  | (86,537 | ) |  | 661,899 |
Operating expense (excluding depreciation) |  | 37,349 |  |  | 1,822 |  |  | 11,839 |  |  | — |  |  | 51,010 |
Depreciation, depletion, and amortization |  | 8,362 |  |  | 1,642 |  |  | 1,868 |  |  | 1,165 |  |  | 13,037 |
General and administrative expense (excluding depreciation) |  | — |  |  | — |  |  | — |  |  | 11,205 |  |  | 11,205 |
Acquisition and integration expense |  | — |  |  | — |  |  | — |  |  | 632 |  |  | 632 |
Operating income (loss) |  | $ | 26,073 |  |  | $ | 8,793 |  |  | $ | 5,738 |  |  | $ | (12,948 | ) |  | $ | 27,656 |

Three months ended March 31, 2017 |  | Refining |  | Logistics |  | Retail |  | Corporate, Eliminations and Other (1) |  | Total
Revenues |  | $ | 574,079 |  |  | $ | 29,995 |  |  | $ | 77,682 |  |  | $ | (76,503 | ) |  | $ | 605,253 |
Cost of revenues (excluding depreciation) |  | 503,044 |  |  | 15,298 |  |  | 59,799 |  |  | (76,852 | ) |  | 501,289 |
Operating expense (excluding depreciation) |  | 36,216 |  |  | 3,797 |  |  | 10,315 |  |  | 20 |  |  | 50,348 |
Depreciation, depletion, and amortization |  | 7,403 |  |  | 1,487 |  |  | 1,448 |  |  | 922 |  |  | 11,260 |
General and administrative expense (excluding depreciation) |  | — |  |  | — |  |  | — |  |  | 12,914 |  |  | 12,914 |
Acquisition and integration expense |  | — |  |  | — |  |  | — |  |  | 253 |  |  | 253 |
Operating income (loss) |  | $ | 27,416 |  |  | $ | 9,413 |  |  | $ | 6,120 |  |  | $ | (13,760 | ) |  | $ | 29,189 |

________________________________________________________

(1) | Includes eliminations of intersegment Revenues and Cost of revenues (excluding depreciation) of $85.9 million and $77.2 million for the three months ended March 31, 2018 and 2017, respectively.

25

Below is a summary of key operating statistics for the refining segment for the three months ended March 31, 2018 and 2017:

| Three Months Ended March 31,
| 2018 |  | 2017
Total Refining Segment |  |  |
Feedstocks Throughput (Mbpd) | 92.7 |  |  | 91.1 |
Refined product sales volume (Mbpd) | 102.3 |  |  | 94.8 |
Hawaii Refinery |  |  |
Feedstocks Throughput (Mbpd) | 76.2 |  |  | 76.8 |
Source of Crude Oil: |  |  |
North America | 39.7 | % |  | 44.2 | %
Latin America | — | % |  | 0.3 | %
Africa | 39.9 | % |  | 22.8 | %
Asia | 6.7 | % |  | 25.8 | %
Middle East | 13.7 | % |  | 6.9 | %
Total | 100.0 | % |  | 100.0 | %
Yield (% of total throughput) |  |  |
Gasoline and gasoline blendstocks | 28.2 | % |  | 27.5 | %
Distillate | 47.2 | % |  | 45.0 | %
Fuel oils | 16.3 | % |  | 18.4 | %
Other products | 5.2 | % |  | 5.9 | %
Total yield | 96.9 | % |  | 96.8 | %
Refined product sales volume (Mbpd) |  |  |
On-island sales volume | 69.4 |  |  | 61.8 |
Exports sale volume | 14.6 |  |  | 18.2 |
Total refined product sales volume | 84.0 |  |  | 80.0 |
4-1-2-1 Singapore Crack Spread (1) ($ per barrel) | $ | 6.38 |  |  | $ | 6.74 |
4-1-2-1 Mid Pacific Crack Spread (1) ($ per barrel) | 7.38 |  |  | 7.69 |
Mid Pacific Crude Oil Differential (2) ($ per barrel) | (0.02 | ) |  | (1.21 | )
Operating income (loss) per bbl ($/throughput bbl) | 2.96 |  |  | 4.01 |
Adjusted Gross Margin per bbl ($/throughput bbl) (3) | 5.20 |  |  | 7.06 |
Production costs per bbl ($/throughput bbl) (4) | 3.64 |  |  | 3.71 |
DD&A per bbl ($/throughput bbl) | 0.71 |  |  | 0.64 |

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| Three Months Ended March 31,
| 2018 |  | 2017
Wyoming Refinery |  |  |
Feedstocks Throughput (Mbpd) | 16.5 |  |  | 14.3 |
Yield (% of total throughput) |  |  |
Gasoline and gasoline blendstocks | 49.9 | % |  | 54.2 | %
Distillate | 44.8 | % |  | 39.8 | %
Fuel oil | 2.5 | % |  | 2.7 | %
Other products | 0.4 | % |  | 1.4 | %
Total yield | 97.6 | % |  | 98.1 | %
Refined product sales volume (Mbpd) | 18.3 |  |  | 14.8 |
Wyoming 3-2-1 Index (5) | $ | 15.65 |  |  | $ | 16.51 |
Operating income (loss) per bbl ($/throughput bbl) | 3.89 |  |  | (0.24 | )
Adjusted Gross Margin per bbl ($/throughput bbl) (3) | 13.96 |  |  | 9.45 |
Production costs per bbl ($/throughput bbl) (4) | 7.74 |  |  | 7.46 |
DD&A per bbl ($/throughput bbl) | 2.33 |  |  | 2.31 |

________________________________________________________

(1) | The profitability of our Hawaii business is heavily influenced by crack spreads in both the Singapore and U.S. West Coast markets. These markets reflect the closest liquid market alternatives to source refined products for Hawaii. We believe the Singapore and Mid Pacific crack spreads (or four barrels of Brent crude oil converted into one barrel of gasoline, two barrels of distillate (diesel and jet fuel) and one barrel of fuel oil) best reflect a market indicator for our Hawaii operations. The Mid Pacific crack spread is calculated using a ratio of 80% Singapore and 20% San Francisco indexes.

(2) | Weighted-average differentials, excluding shipping costs, of a blend of crude oils with an API of 31.98 and sulfur weight percentage of 0.65% that is indicative of our typical crude oil mix quality compared to Brent crude oil.

(3) | Please see discussion of Adjusted Gross Margin below. We calculate Adjusted Gross Margin per barrel by dividing Adjusted Gross Margin by total refining throughput.

(4) | Management uses production costs per barrel to evaluate performance and compare efficiency to other companies in the industry. There are a variety of ways to calculate production costs per barrel; different companies within the industry calculate it in different ways. We calculate production costs per barrel by dividing all direct production costs, which include the costs to run the refinery including personnel costs, repair and maintenance costs, insurance, utilities, and other miscellaneous costs, by total refining throughput. Our production costs are included in Operating expense (excluding depreciation) on our condensed consolidated statement of operations, which also includes costs related to our bulk marketing operations.

(5) | The profitability of our Wyoming refinery is heavily influenced by crack spreads in nearby markets. We believe the Wyoming 3-2-1 Index is the best market indicator for our operations in Wyoming. The Wyoming 3-2-1 Index is computed by taking two parts gasoline and one part distillate (ultra-low sulfur diesel) as created from three barrels of West Texas Intermediate Crude Oil (“WTI”). Pricing is based 50% on applicable product pricing in Rapid City, South Dakota, and 50% on applicable product pricing in Denver, Colorado.

27

Below is a summary of key operating statistics for the retail and logistics segments for the three months ended March 31, 2018 and 2017:

| Three Months Ended March 31,
| 2018 |  | 2017
Retail Segment |  |  |
Retail sales volumes (thousands of gallons) (1) | 22,190 |  |  | 22,058 |
Logistics Segment |  |  |
Pipeline throughput (Mbpd) |  |  |
Crude oil pipelines | 88.4 |  |  | 91.1 |
Refined product pipelines | 90.9 |  |  | 90.5 |
Total pipeline throughput | 179.3 |  |  | 181.6 |

________________________________________________________

(1) | Retail sales volumes for the three months ended March 31, 2018, includes the nine days of retail sales volumes from Northwest Retail since acquisition on March 23, 2018.

Non-GAAP Performance Measures
Management uses certain financial measures to evaluate our operating performance that are considered non-GAAP financial measures. These measures should not be considered a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP and our calculations thereof may not be comparable to similarly titled measures reported by other companies.
Adjusted Gross Margin
Adjusted Gross Margin is defined as (i) operating income (loss) plus operating expense (excluding depreciation), depreciation, depletion, and amortization, inventory valuation adjustments (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase obligation, and purchase price allocation adjustments), and unrealized losses (gains) on derivatives or (ii) revenues less cost of revenues (excluding depreciation) less inventory valuation adjustments and unrealized losses (gains) on derivatives. We define cost of revenues (excluding depreciation) as the hydrocarbon-related costs of inventory sold, transportation costs of delivering product to customers, crude oil consumed in the refining process, costs to satisfy our RINS obligations, and certain hydrocarbon fees and taxes. Cost of revenues (excluding depreciation) also includes the unrealized gains (losses) on derivatives and inventory valuation adjustments that we exclude from Adjusted Gross Margin.
Management believes Adjusted Gross Margin is an important measure of operating performance and uses Adjusted Gross Margin per barrel to evaluate operating performance and compare profitability to other companies in the industry and to industry benchmarks. Management believes Adjusted Gross Margin provides useful information to investors because it eliminates the gross impact of volatile commodity prices and adjusts for certain non-cash items and timing differences created by our inventory financing agreements and lower of cost or net realizable value adjustments to demonstrate the earnings potential of the business before other fixed and variable costs, which are reported separately in Operating expense (excluding depreciation) and Depreciation, depletion, and amortization.
Adjusted Gross Margin should not be considered an alternative to operating income (loss), net cash flows from operating activities, or any other measure of financial performance or liquidity presented in accordance with GAAP. Adjusted Gross Margin presented by other companies may not be comparable to our presentation since each company may define this term differently as they may include other manufacturing costs and depreciation expense in cost of revenues.
28

The following tables present a reconciliation of Adjusted Gross Margin to the most directly comparable GAAP financial measure, operating income (loss), on a historical basis, for selected segments, for the periods indicated (in thousands):

Three months ended March 31, 2018 | Refining |  | Logistics |  | Retail
Operating income | $ | 26,073 |  |  | $ | 8,793 |  |  | $ | 5,738 |
Operating expense (excluding depreciation) | 37,349 |  |  | 1,822 |  |  | 11,839 |
Depreciation, depletion, and amortization | 8,362 |  |  | 1,642 |  |  | 1,868 |
Inventory valuation adjustment | (11,887 | ) |  | — |  |  | — |
Unrealized gain on derivatives | (3,505 | ) |  | — |  |  | — |
Adjusted Gross Margin | $ | 56,392 |  |  | $ | 12,257 |  |  | $ | 19,445 |

Three months ended March 31, 2017 | Refining |  | Logistics |  | Retail
Operating income | $ | 27,416 |  |  | $ | 9,413 |  |  | $ | 6,120 |
Operating expense (excluding depreciation) | 36,216 |  |  | 3,797 |  |  | 10,315 |
Depreciation, depletion, and amortization | 7,403 |  |  | 1,487 |  |  | 1,448 |
Inventory valuation adjustment | (8,792 | ) |  | — |  |  | — |
Unrealized loss on derivatives | (1,287 | ) |  | — |  |  | — |
Adjusted Gross Margin | $ | 60,956 |  |  | $ | 14,697 |  |  | $ | 17,883 |

Adjusted Net Income (Loss) and Adjusted EBITDA
Adjusted Net Income (Loss) is defined as Net income excluding changes in the value of contingent consideration and common stock warrants, acquisition and integration expense, unrealized (gains) losses on derivatives, loss on termination of financing agreements, release of tax valuation allowance, inventory valuation adjustment, and severance costs. Beginning in 2018, Adjusted Net Income (Loss) also excludes Par's share of Laramie Energy's unrealized loss (gain) on derivatives. The exclusion of Par's share of Laramie Energy's unrealized loss (gain) on derivatives from Adjusted Net Income (Loss) is consistent with our treatment of Par’s unrealized (gains) losses on derivatives, which are also excluded from Adjusted Net Income (Loss). We have recast the non-GAAP information for the three months ended March 31, 2017 to conform to the current period presentation.
Adjusted EBITDA is Adjusted Net Income (Loss) excluding interest expense and financing costs, taxes, DD&A, and, beginning in 2018, equity losses (earnings) from Laramie Energy, excluding Par's share of unrealized loss (gain) on derivatives. We believe Adjusted Net Income (Loss) and Adjusted EBITDA are useful supplemental financial measures that allow investors to assess:

• | The financial performance of our assets without regard to financing methods, capital structure, or historical cost basis;

• | The ability of our assets to generate cash to pay interest on our indebtedness; and

• | Our operating performance and return on invested capital as compared to other companies without regard to financing methods and capital structure.

Adjusted Net Income (Loss) and Adjusted EBITDA should not be considered in isolation or as a substitute for operating income (loss), net income (loss), cash flows provided by operating, investing, and financing activities, or other income or cash flow statement data prepared in accordance with GAAP. Adjusted Net Income (Loss) and Adjusted EBITDA presented by other companies may not be comparable to our presentation as other companies may define these terms differently.
29

The following table presents a reconciliation of Adjusted Net Income (Loss) and Adjusted EBITDA to the most directly comparable GAAP financial measure, Net income, on a historical basis for the periods indicated (in thousands):

| Three Months Ended March 31,
| 2018 |  | 2017
Net income | $ | 15,185 |  |  | $ | 27,786 |
Inventory valuation adjustment | (11,887 | ) |  | (8,792 | )
Unrealized loss (gain) on derivatives | (3,505 | ) |  | (1,287 | )
Acquisition and integration expense | 632 |  |  | 253 |
Change in value of common stock warrants | (745 | ) |  | 689 |
Change in value of contingent consideration | 10,500 |  |  | — |
Severance costs | — |  |  | 1,595 |
Par's share of Laramie Energy's unrealized loss (gain) on derivatives (1) | (1,988 | ) |  | (10,237 | )
Adjusted Net Income | 8,192 |  |  | 10,007 |
Depreciation, depletion, and amortization | 13,037 |  |  | 11,260 |
Interest expense and financing costs, net | 8,377 |  |  | 8,942 |
Equity losses (earnings) from Laramie Energy, LLC, excluding Par's share of unrealized loss (gain) on derivatives | (3,588 | ) |  | 1,491 |
Income tax expense | 34 |  |  | 648 |
Adjusted EBITDA | $ | 26,052 |  |  | $ | 32,348 |

________________________________________

(1) | Included in Equity earnings from Laramie Energy, LLC on our Condensed Consolidated Statements of Operations.

Factors Impacting Segment Results
Three months ended March 31, 2018 compared to the three months ended March 31, 2017
Refining. Operating income for our refining segment was $26.1 million for the three months ended March 31, 2018, a decrease of $1.3 million compared to an operating income of $27.4 million for the three months ended March 31, 2017. The decrease in profitability was primarily driven by lower crack spreads and crude oil differentials. The combined Mid Pacific crack spread decreased 17% from $8.90 per barrel for the three months ended March 31, 2017 to $7.40 per barrel for the three months ended March 31, 2018. The Wyoming Index decreased 5% from $16.51 per barrel for the three months ended March 31, 2017 to $15.65 per barrel for the three months ended March 31, 2018. These decreases were partially offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption.
Logistics. Operating income for our logistics segment was $8.8 million for the three months ended March 31, 2018, a decrease of $0.6 million compared to operating income of $9.4 million for the three months ended March 31, 2017. The decrease in profitability is primarily due to higher repair and maintenance costs during the quarter.
Retail. Operating income for our retail segment was $5.7 million for the three months ended March 31, 2018, which was relatively consistent with our operating income of $6.1 million for the three months ended March 31, 2017.
30

Adjusted Gross Margin
Three months ended March 31, 2018 compared to the three months ended March 31, 2017
Refining. For the three months ended March 31, 2018, our refining Adjusted Gross Margin was approximately $56.4 million, a decrease of $4.6 million compared to $61.0 million for the three months ended March 31, 2017. The decrease was primarily due to lower crack spreads and crude oil differentials. The combined Mid Pacific crack spread decreased 17% from $8.90 per barrel for the three months ended March 31, 2017 to $7.40 per barrel for the three months ended March 31, 2018. The Wyoming Index decreased 5% from $16.51 per barrel for the three months ended March 31, 2017 to $15.65 per barrel for the three months ended March 31, 2018. These decreases were partially offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption.
Logistics. For the three months ended March 31, 2018, our logistics Adjusted Gross Margin was approximately $12.3 million, a decrease of $2.4 million compared to $14.7 million for the three months ended March 31, 2017. The decrease was primarily driven by higher transportation costs.
Retail. For the three months ended March 31, 2018, our retail Adjusted Gross Margin was approximately $19.4 million, an increase of $1.5 million when compared to approximately $17.9 million for the three months ended March 31, 2017. The increase was primarily due to an increase in sales prices of 9%, partially offset by a 8% increase in fuel costs.
Discussion of Consolidated Results
Three months ended March 31, 2018 compared to the three months ended March 31, 2017
Revenues. For the three months ended March 31, 2018, revenues were $765.4 million, a $160.1 million increase compared to $605.3 million for the three months ended March 31, 2017. The increase was primarily due to an increase of $160.1 million in third-party revenues at our refining segment primarily as a result of increased prices and volumes sold. Average Brent prices increased from $54.57 per barrel in the three months ended March 31, 2017 to $67.19 per barrel in the three months ended March 31, 2018. Average WTI prices increased from $51.82 per barrel in the three months ended March 31, 2017 to $62.89 per barrel in the three months ended March 31, 2018. Refined product sales volumes increased 7.9% from 94.8 Mbpd in the three months ended March 31, 2017 to 102.3 Mbpd in the three months ended March 31, 2018.
Cost of Revenues (Excluding Depreciation). For the three months ended March 31, 2018, cost of revenues (excluding depreciation), was $661.9 million, a $160.6 million increase compared to $501.3 million for the three months ended March 31, 2017. The increase was primarily due to the increase in feedstock prices and volumes sold and was partially offset by a $13.2 million of RINs benefit primarily due to our refineries obtaining a small refinery exemption. Refined product sales volumes increased 7.9% from 94.8 Mbpd in the three months ended March 31, 2017 to 102.3 Mbpd in the three months ended March 31, 2018.
Operating Expense (Excluding Depreciation). For the three months ended March 31, 2018, operating expense (excluding depreciation) was approximately $51.0 million, an increase of $0.7 million compared to $50.3 million for the three months ended March 31, 2017. The increase was primarily due to operating expenses for the acquired Northwest Retail assets for the nine-day period since acquisition on March 23, 2018.
Depreciation, Depletion, and Amortization. For the three months ended March 31, 2018, DD&A was approximately $13.0 million, an increase of $1.7 million when compared to $11.3 million for the three months ended March 31, 2017. The increase was primarily due to accelerated depreciation associated with equipment and storage tanks that were retired during the quarter.
General and Administrative Expense (Excluding Depreciation). For the three months ended March 31, 2018, general and administrative expense (excluding depreciation) was approximately $11.2 million, a decrease of $1.7 million when compared to $12.9 million for the three months ended March 31, 2017. The decrease was primarily due to severance costs and professional fees incurred in 2017 that were not incurred in 2018.
Acquisition and Integration Expense. For the three months ended March 31, 2018, we incurred approximately $0.6 million of acquisition and integration costs related to the Northwest Retail Acquisition. For the three months ended March 31, 2017, we incurred approximately $0.3 million of integration costs related to the Wyoming Refining acquisition completed in July 2016.
Interest Expense and Financing Costs, Net. For the three months ended March 31, 2018, our interest expense and financing costs were approximately $8.4 million, a decrease of $0.5 million when compared to $8.9 million for the three months ended March 31, 2017. The decrease was primarily due to a net increase in gains on interest rate derivatives of $1.1 million and
31

lower interest expense of $5.7 million related to the debt and credit agreements terminated in December 2017, partially offset by higher interest expense of $6.1 million related to the 7.75% Senior Secured Notes entered into in December 2017.
Change in Value of Common Stock Warrants. For the three months ended March 31, 2018, the change in value of common stock warrants resulted in a gain of approximately $0.7 million, a change of $1.4 million when compared to a loss of $0.7 million for the three months ended March 31, 2017. For the three months ended March 31, 2018, our stock price decreased from $19.28 per share as of December 31, 2017 to $17.17 per share as of March 31, 2018, which resulted in a decrease in the fair value of the common stock warrants. During the three months ended March 31, 2017, our stock price increased from $14.54 per share on December 31, 2016 to $16.49 per share on March 31, 2017, which resulted in an increase in the value of the common stock warrants.
Change in Value of Contingent Consideration. For the three months ended March 31, 2018, the change in the value of our contingent consideration liability resulted in a loss of $10.5 million as a result of the settlement agreement reached with Tesoro. For the three months ended March 31, 2017, there was no change in value of our contingent consideration liability. Please read Note 12—Commitments and Contingencies for more information.
Equity Earnings (Losses) From Laramie Energy. For the three months ended March 31, 2018, equity earnings from Laramie Energy were approximately $5.6 million, a change of $3.1 million compared to equity earnings of $8.7 million for the three months ended March 31, 2017. The change was primarily due to a decrease in realized natural gas prices and a decrease in gains on derivative instruments of $14.4 million, partially offset by an increase in NGL prices and production volumes during the three months ended March 31, 2018 compared to the same period in 2017. In addition, our ownership percentage decreased from 42.3% to 39.1% on February 28, 2018 due to an investment made by a third-party.
Income Taxes. For the three months ended March 31, 2018, we recorded income tax expense of $34 thousand primarily due to deferred federal income taxes. For the three months ended March 31, 2017, we recorded income tax expense of $0.6 million primarily due to alternative minimum tax of $446 thousand.
Consolidating Condensed Financial Information
On December 21, 2017, Par Petroleum, LLC (the “Issuer”), issued its 7.75% Senior Secured Notes due 2025 in a private offering under Rule 144A and Regulation S of the Securities Act. The notes were co-issued by Par Petroleum Finance Corp., which has no independent assets or operations. The notes are guaranteed on a senior unsecured basis only as to payment of principal and interest by Par Pacific Holdings, Inc. (the “Parent”) and are guaranteed on a senior secured basis by all of the subsidiaries of Par Petroleum, LLC (other than Par Petroleum Finance Corp.).
The following supplemental condensed consolidating financial information reflects (i) the Parent's separate accounts, (ii) Par Petroleum, LLC and its consolidated subsidiaries’ accounts, (iii) the accounts of subsidiaries of the Parent that are not guarantors of the 7.75% Senior Secured Notes and consolidating adjustments and eliminations, and (iv) the Parent's consolidated accounts for the dates and periods indicated. For purposes of the following condensed consolidating information, the Parent’s investment in its subsidiaries is accounted for under the equity method of accounting (dollar amounts in thousands).
32

| As of March 31, 2018
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
ASSETS |  |  |  |  |  |  |
Current assets |  |  |  |  |  |  |
Cash and cash equivalents | $ | 51,945 |  |  | $ | 12,656 |  |  | $ | 356 |  |  | $ | 64,957 |
Restricted cash | 743 |  |  | — |  |  | — |  |  | 743 |
Trade accounts receivable | — |  |  | 127,179 |  |  | 944 |  |  | 128,123 |
Inventories | — |  |  | 296,267 |  |  | — |  |  | 296,267 |
Prepaid and other current assets | 8,093 |  |  | 89,699 |  |  | 345 |  |  | 98,137 |
Due from related parties | 22,402 |  |  | 25,510 |  |  | (47,912 | ) |  | — |
Total current assets | 83,183 |  |  | 551,311 |  |  | (46,267 | ) |  | 588,227 |
Property and equipment |  |  |  |  |  |  |  |
Property, plant, and equipment | 17,125 |  |  | 548,974 |  |  | 158 |  |  | 566,257 |
Proved oil and gas properties, at cost, successful efforts method of accounting | — |  |  | — |  |  | 400 |  |  | 400 |
Total property and equipment | 17,125 |  |  | 548,974 |  |  | 558 |  |  | 566,657 |
Less accumulated depreciation and depletion | (7,339 | ) |  | (79,980 | ) |  | (372 | ) |  | (87,691 | )
Property and equipment, net | 9,786 |  |  | 468,994 |  |  | 186 |  |  | 478,966 |
Long-term assets |  |  |  |  |  |  |  |
Investment in Laramie Energy, LLC | — |  |  | — |  |  | 132,768 |  |  | 132,768 |
Investment in subsidiaries | 576,060 |  |  | — |  |  | (576,060 | ) |  | — |
Intangible assets, net | — |  |  | 25,940 |  |  | — |  |  | 25,940 |
Goodwill | — |  |  | 150,286 |  |  | 2,598 |  |  | 152,884 |
Other long-term assets | 3,579 |  |  | 25,761 |  |  | — |  |  | 29,340 |
Total assets | $ | 672,608 |  |  | $ | 1,222,292 |  |  | $ | (486,775 | ) |  | $ | 1,408,125 |
LIABILITIES AND STOCKHOLDERS’ EQUITY |  |  |  |  |  |  |  |
Current liabilities |  |  |  |  |  |  |  |
Obligations under inventory financing agreements | $ | — |  |  | $ | 383,806 |  |  | $ | — |  |  | $ | 383,806 |
Accounts payable | 2,662 |  |  | 56,941 |  |  | 1,493 |  |  | 61,096 |
Advances from customers | — |  |  | 10,021 |  |  | — |  |  | 10,021 |
Accrued taxes | 62 |  |  | 19,224 |  |  | — |  |  | 19,286 |
Other accrued liabilities | 7,197 |  |  | 30,136 |  |  | (2,362 | ) |  | 34,971 |
Due to related parties | 95,583 |  |  | — |  |  | (95,583 | ) |  | — |
Total current liabilities | 105,504 |  |  | 500,128 |  |  | (96,452 | ) |  | 509,180 |
Long-term liabilities |  |  |  |  |  |  |  |
Long-term debt, net of current maturities | 96,674 |  |  | 289,826 |  |  | — |  |  | 386,500 |
Common stock warrants | 6,063 |  |  | — |  |  | — |  |  | 6,063 |
Long-term capital lease obligations | 568 |  |  | 5,819 |  |  | — |  |  | 6,387 |
Other liabilities | — |  |  | 41,480 |  |  | (5,284 | ) |  | 36,196 |
Total liabilities | 208,809 |  |  | 837,253 |  |  | (101,736 | ) |  | 944,326 |
Stockholders’ equity |  |  |  |  |  |  |
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued | — |  |  | — |  |  | — |  |  | — |
Common stock, $0.01 par value; 500,000,000 shares authorized and 46,018,511 shares issued | 459 |  |  | — |  |  | — |  |  | 459 |
Additional paid-in capital | 594,189 |  |  | 345,825 |  |  | (345,825 | ) |  | 594,189 |
Accumulated earnings (deficit) | (132,993 | ) |  | 36,240 |  |  | (36,240 | ) |  | (132,993 | )
Accumulated other comprehensive income | 2,144 |  |  | 2,974 |  |  | (2,974 | ) |  | 2,144 |
Total stockholders’ equity | 463,799 |  |  | 385,039 |  |  | (385,039 | ) |  | 463,799 |
Total liabilities and stockholders’ equity | $ | 672,608 |  |  | $ | 1,222,292 |  |  | $ | (486,775 | ) |  | $ | 1,408,125 |

33

| As of December 31, 2017
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
ASSETS |  |  |  |  |  |  |
Current assets |  |  |  |  |  |  |
Cash and cash equivalents | $ | 65,615 |  |  | $ | 51,429 |  |  | $ | 1,289 |  |  | $ | 118,333 |
Restricted cash | 744 |  |  | — |  |  | — |  |  | 744 |
Trade accounts receivable | — |  |  | 120,032 |  |  | 1,799 |  |  | 121,831 |
Inventories | — |  |  | 345,072 |  |  | 285 |  |  | 345,357 |
Prepaid and other current assets | 11,768 |  |  | 7,115 |  |  | (1,604 | ) |  | 17,279 |
Due from related parties | 8,113 |  |  | 32,171 |  |  | (40,284 | ) |  | — |
Total current assets | 86,240 |  |  | 555,819 |  |  | (38,515 | ) |  | 603,544 |
Property and equipment |  |  |  |  |  |  |  |
Property, plant, and equipment | 15,773 |  |  | 513,307 |  |  | 158 |  |  | 529,238 |
Proved oil and gas properties, at cost, successful efforts method of accounting | — |  |  | — |  |  | 400 |  |  | 400 |
Total property and equipment | 15,773 |  |  | 513,307 |  |  | 558 |  |  | 529,638 |
Less accumulated depreciation and depletion | (6,226 | ) |  | (73,029 | ) |  | (367 | ) |  | (79,622 | )
Property and equipment, net | 9,547 |  |  | 440,278 |  |  | 191 |  |  | 450,016 |
Long-term assets |  |  |  |  |  |  |  |
Investment in Laramie Energy, LLC | — |  |  | — |  |  | 127,192 |  |  | 127,192 |
Investment in subsidiaries | 552,748 |  |  | — |  |  | (552,748 | ) |  | — |
Intangible assets, net | — |  |  | 26,604 |  |  | — |  |  | 26,604 |
Goodwill | — |  |  | 104,589 |  |  | 2,598 |  |  | 107,187 |
Other long-term assets | 1,976 |  |  | 30,888 |  |  | — |  |  | 32,864 |
Total assets | $ | 650,511 |  |  | $ | 1,158,178 |  |  | $ | (461,282 | ) |  | $ | 1,347,407 |
LIABILITIES AND STOCKHOLDERS’ EQUITY |  |  |  |  |  |  |  |
Current liabilities |  |  |  |  |  |  |  |
Obligations under inventory financing agreements | $ | — |  |  | $ | 363,756 |  |  | $ | — |  |  | $ | 363,756 |
Accounts payable | 4,510 |  |  | 46,273 |  |  | 1,760 |  |  | 52,543 |
Advances from customers | — |  |  | 9,522 |  |  | — |  |  | 9,522 |
Accrued taxes | — |  |  | 20,227 |  |  | (2,540 | ) |  | 17,687 |
Other accrued liabilities | 12,913 |  |  | 14,420 |  |  | 111 |  |  | 27,444 |
Due to related parties | 82,524 |  |  | — |  |  | (82,524 | ) |  | — |
Total current liabilities | 99,947 |  |  | 454,198 |  |  | (83,193 | ) |  | 470,952 |
Long-term liabilities |  |  |  |  |  |  |  |
Long-term debt, net of current maturities | 95,486 |  |  | 289,326 |  |  | — |  |  | 384,812 |
Common stock warrants | 6,808 |  |  | — |  |  | — |  |  | 6,808 |
Long-term capital lease obligations | 551 |  |  | 669 |  |  | — |  |  | 1,220 |
Other liabilities | — |  |  | 41,253 |  |  | (5,357 | ) |  | 35,896 |
Total liabilities | 202,792 |  |  | 785,446 |  |  | (88,550 | ) |  | 899,688 |
Commitments and contingencies |  |  |  |  |  |  |
Stockholders’ equity |  |  |  |  |  |  |
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued | — |  |  | — |  |  | — |  |  | — |
Common stock, $0.01 par value; 500,000,000 shares authorized and 45,776,087 shares issued | 458 |  |  | — |  |  | — |  |  | 458 |
Additional paid-in capital | 593,295 |  |  | 345,825 |  |  | (345,825 | ) |  | 593,295 |
Accumulated earnings (deficit) | (148,178 | ) |  | 23,933 |  |  | (23,933 | ) |  | (148,178 | )
Accumulated other comprehensive income | 2,144 |  |  | 2,974 |  |  | (2,974 | ) |  | 2,144 |
Total stockholders’ equity | 447,719 |  |  | 372,732 |  |  | (372,732 | ) |  | 447,719 |
Total liabilities and stockholders’ equity | $ | 650,511 |  |  | $ | 1,158,178 |  |  | $ | (461,282 | ) |  | $ | 1,347,407 |

34

| Three Months Ended March 31, 2018
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
Revenues | $ | — |  |  | $ | 764,927 |  |  | $ | 512 |  |  | $ | 765,439 |
Operating expenses |  |  |  |  |  |  |
Cost of revenues (excluding depreciation) | — |  |  | 661,579 |  |  | 320 |  |  | 661,899 |
Operating expense (excluding depreciation) | — |  |  | 51,010 |  |  | — |  |  | 51,010 |
Depreciation, depletion, and amortization | 1,113 |  |  | 11,919 |  |  | 5 |  |  | 13,037 |
General and administrative expense (excluding depreciation) | 5,225 |  |  | 5,905 |  |  | 75 |  |  | 11,205 |
Acquisition and integration expense | 431 |  |  | 201 |  |  | — |  |  | 632 |
Total operating expenses | 6,769 |  |  | 730,614 |  |  | 400 |  |  | 737,783 |
Operating income (loss) | (6,769 | ) |  | 34,313 |  |  | 112 |  |  | 27,656 |
Other income (expense) |  |  |  |  |  |  |
Interest expense and financing costs, net | (2,654 | ) |  | (5,723 | ) |  | — |  |  | (8,377 | )
Other income (expense), net | 155 |  |  | (30 | ) |  | (6 | ) |  | 119 |
Change in value of common stock warrants | 745 |  |  | — |  |  | — |  |  | 745 |
Change in value of contingent consideration | — |  |  | (10,500 | ) |  | — |  |  | (10,500 | )
Equity earnings (losses) from subsidiaries | 23,708 |  |  | — |  |  | (23,708 | ) |  | — |
Equity earnings from Laramie Energy, LLC | — |  |  | — |  |  | 5,576 |  |  | 5,576 |
Total other income (expense), net | 21,954 |  |  | (16,253 | ) |  | (18,138 | ) |  | (12,437 | )
Income (loss) before income taxes | 15,185 |  |  | 18,060 |  |  | (18,026 | ) |  | 15,219 |
Income tax benefit (expense) | — |  |  | (5,753 | ) |  | 5,719 |  |  | (34 | )
Net income (loss) | $ | 15,185 |  |  | $ | 12,307 |  |  | $ | (12,307 | ) |  | $ | 15,185 |
Adjusted EBITDA | $ | (5,070 | ) |  | $ | 31,011 |  |  | $ | 111 |  |  | $ | 26,052 |

35

| Three Months Ended March 31, 2017
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
Revenues | $ | — |  |  | $ | 604,618 |  |  | $ | 635 |  |  | $ | 605,253 |
Operating expenses |  |  |  |  |  |  |
Cost of revenues (excluding depreciation) | — |  |  | 501,048 |  |  | 241 |  |  | 501,289 |
Operating expense (excluding depreciation) | — |  |  | 50,348 |  |  | — |  |  | 50,348 |
Depreciation, depletion, and amortization | 713 |  |  | 10,360 |  |  | 187 |  |  | 11,260 |
General and administrative expense (excluding depreciation) | 5,308 |  |  | 6,443 |  |  | 1,163 |  |  | 12,914 |
Acquisition and integration expense | 253 |  |  | — |  |  | — |  |  | 253 |
Total operating expenses | 6,274 |  |  | 568,199 |  |  | 1,591 |  |  | 576,064 |
Operating income (loss) | (6,274 | ) |  | 36,419 |  |  | (956 | ) |  | 29,189 |
Other income (expense) |  |  |  |  |  |  |
Interest expense and financing costs, net | (4,686 | ) |  | (4,256 | ) |  | — |  |  | (8,942 | )
Other income (expense), net | 118 |  |  | 9 |  |  | 3 |  |  | 130 |
Change in value of common stock warrants | (689 | ) |  | — |  |  | — |  |  | (689 | )
Equity earnings (losses) from subsidiaries | 39,317 |  |  | — |  |  | (39,317 | ) |  | — |
Equity earnings from Laramie Energy, LLC | — |  |  | — |  |  | 8,746 |  |  | 8,746 |
Total other income (expense), net | 34,060 |  |  | (4,247 | ) |  | (30,568 | ) |  | (755 | )
Income (loss) before income taxes | 27,786 |  |  | 32,172 |  |  | (31,524 | ) |  | 28,434 |
Income tax benefit (expense) | — |  |  | (10,116 | ) |  | 9,468 |  |  | (648 | )
Net income (loss) | $ | 27,786 |  |  | $ | 22,056 |  |  | $ | (22,056 | ) |  | $ | 27,786 |
Adjusted EBITDA | $ | (3,990 | ) |  | $ | 37,104 |  |  | $ | (766 | ) |  | $ | 32,348 |

36

Non-GAAP Financial Measures
Adjusted EBITDA for the supplemental consolidating condensed financial information, which is segregated at the “Parent Guarantor,” “Issuer”, and “Non-Guarantor Subsidiaries and Eliminations” levels, is calculated in the same manner as for the Par Pacific Holdings, Inc. Adjusted EBITDA calculations. See “Results of Operations — Non-GAAP Performance Measures — Adjusted Net Income (Loss) and Adjusted EBITDA” above.
The following tables present a reconciliation of Adjusted EBITDA to the most directly comparable GAAP financial measure, net income (loss), on a historical basis for the periods indicated (in thousands):

| Three Months Ended March 31, 2018
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
Net income (loss) | $ | 15,185 |  |  | $ | 12,307 |  |  | $ | (12,307 | ) |  | $ | 15,185 |
Inventory valuation adjustment | — |  |  | (11,887 | ) |  | — |  |  | (11,887 | )
Unrealized loss (gain) on derivatives | — |  |  | (3,505 | ) |  | — |  |  | (3,505 | )
Acquisition and integration expense | 431 |  |  | 201 |  |  | — |  |  | 632 |
Change in value of common stock warrants | (745 | ) |  | — |  |  | — |  |  | (745 | )
Change in value of contingent consideration | — |  |  | 10,500 |  |  | — |  |  | 10,500 |
Par's share of Laramie Energy's unrealized loss (gain) on derivatives | — |  |  | — |  |  | (1,988 | ) |  | (1,988 | )
Depreciation, depletion, and amortization | 1,113 |  |  | 11,919 |  |  | 5 |  |  | 13,037 |
Interest expense and financing costs, net | 2,654 |  |  | 5,723 |  |  | — |  |  | 8,377 |
Equity losses (earnings) from Laramie Energy, LLC, excluding Par's share of unrealized loss (gain) on derivatives | — |  |  | — |  |  | (3,588 | ) |  | (3,588 | )
Equity losses (income) from subsidiaries | (23,708 | ) |  | — |  |  | 23,708 |  |  | — |
Income tax expense (benefit) | — |  |  | 5,753 |  |  | (5,719 | ) |  | 34 |
Adjusted EBITDA | $ | (5,070 | ) |  | $ | 31,011 |  |  | $ | 111 |  |  | $ | 26,052 |

| Three Months Ended March 31, 2017
| Parent Guarantor |  | Issuer |  | Non-Guarantor Subsidiaries and Eliminations |  | Par Pacific Holdings, Inc. and Subsidiaries
Net income (loss) | $ | 27,786 |  |  | $ | 22,056 |  |  | $ | (22,056 | ) |  | $ | 27,786 |
Inventory valuation adjustment | — |  |  | (8,792 | ) |  | — |  |  | (8,792 | )
Unrealized loss (gain) on derivatives | — |  |  | (1,287 | ) |  | — |  |  | (1,287 | )
Acquisition and integration expense | 253 |  |  | — |  |  | — |  |  | 253 |
Change in value of common stock warrants | 689 |  |  | — |  |  | — |  |  | 689 |
Severance costs | 1,200 |  |  | 395 |  |  | — |  |  | 1,595 |
Par's share of Laramie Energy's unrealized loss (gain) on derivatives | — |  |  | — |  |  | (10,237 | ) |  | (10,237 | )
Depreciation, depletion, and amortization | 713 |  |  | 10,360 |  |  | 187 |  |  | 11,260 |
Interest expense and financing costs, net | 4,686 |  |  | 4,256 |  |  | — |  |  | 8,942 |
Equity losses (earnings) from Laramie Energy, LLC, excluding Par's share of unrealized loss (gain) on derivatives | — |  |  | — |  |  | 1,491 |  |  | 1,491 |
Equity losses (income) from subsidiaries | (39,317 | ) |  | — |  |  | 39,317 |  |  | — |
Income tax expense (benefit) | — |  |  | 10,116 |  |  | (9,468 | ) |  | 648 |
Adjusted EBITDA | $ | (3,990 | ) |  | $ | 37,104 |  |  | $ | (766 | ) |  | $ | 32,348 |

37

Liquidity and Capital Resources
Our liquidity and capital requirements are primarily a function of our debt maturities and debt service requirements, fixed capacity payments and contractual obligations, capital expenditures, and working capital needs. Examples of working capital needs include purchases and sales of commodities and associated margin and collateral requirements, facility maintenance costs, and other costs such as payroll. Our primary sources of liquidity are cash flows from operations, cash on hand, amounts available under our credit agreements, and access to capital markets.
Our liquidity position as of March 31, 2018 was $122.6 million and consisted of $70.3 million at Par Petroleum, LLC and subsidiaries, $51.9 million at Par Pacific Holdings, and $0.4 million at all our other subsidiaries. Our consolidated liquidity position as of May 4, 2018 was $156.6 million. The change in our liquidity position from March 31, 2018 to May 4, 2018 was primarily attributable to changes in working capital.
As of March 31, 2018, we had access to the J. Aron Deferred Payment Arrangement, the ABL Credit Facility, and cash on hand of $65.0 million. In addition, we have the Supply and Offtake Agreements with J. Aron, which are used to finance the majority of the inventory at our Hawaii refinery. Generally, the primary uses of our capital resources have been in the operations of our refining and retail segments, payments related to acquisitions, to repay or refinance indebtedness, and cash capital contributions to Laramie Energy.
We believe our cash flows from operations and available capital resources will be sufficient to meet our current capital expenditures, working capital, and debt service requirements for the next 12 months.We may seek to raise additional debt or equity capital to fund any other significant changes to our business or to refinance existing debt. We cannot offer any assurances that such capital will be available in sufficient amounts or at an acceptable cost.
We may from time to time seek to retire or repurchase our outstanding 5.00% Convertible Senior Notes or 7.75% Senior Secured Notes through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions, or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions, and other factors. The amounts involved may be material.
Cash Flows
The following table summarizes cash activities for the three months ended March 31, 2018 and 2017 (in thousands):

| Three Months Ended March 31,
| 2018 |  | 2017
Net cash provided by operating activities | $ | 12,641 |  |  | $ | 24,994 |
Net cash used in investing activities | (84,292 | ) |  | (7,579 | )
Net cash provided by (used in) financing activities | 18,274 |  |  | (18,976 | )

Net cash provided by operating activities was approximately $12.6 million for the three months ended March 31, 2018, which resulted from net income of approximately $15.2 million, non-cash charges to operations of approximately $9.2 million and net cash used for changes in operating assets and liabilities of approximately $11.7 million. The change in our operating assets and liabilities for the three months ended March 31, 2018 is primarily due to the timing of advances to suppliers for crude oil purchases and an overall decrease in inventory volumes at our Hawaii refinery. Net cash provided by operating activities was approximately $25.0 million for the three months ended March 31, 2017, which resulted from net income of approximately $27.8 million, non-cash charges to operations of approximately $6.8 million, and net cash used for changes in operating assets and liabilities of approximately $9.6 million.
For the three months ended March 31, 2018, net cash used in investing activities was approximately $84.3 million and primarily related to $74.7 million for the Northwest Retail Acquisition and additions to property and equipment totaling approximately $9.6 million. Net cash used in investing activities was approximately $7.6 million for the three months ended March 31, 2017 and related to additions to property and equipment.
Net cash provided by financing activities for the three months ended March 31, 2018 was approximately $18.3 million which consisted primarily of net borrowings of approximately $21.5 million associated with the J. Aron deferred payment. Net cash used in financing activities for the three months ended March 31, 2017 was approximately $19.0 million and consisted primarily of net repayments from borrowings of approximately $18.8 million.
38

Capital Expenditures
Our capital expenditures for the three months ended March 31, 2018 totaled approximately $9.6 million and were primarily related to the first phase of our hydrotreater construction at our Hawaii refinery, other refinery equipment, and scheduled maintenance. Our capital expenditure budget for 2018 ranges from $50 million to $55 million and primarily relates to annual maintenance costs and growth projects at our refining and retail segments, including the first phase of our hydrotreater construction to increase ultra-low sulfur distillate production capacity at our Hawaii refinery and expansion projects at our Wyoming refinery.
We also continue to seek strategic investments in business opportunities, but the amount and timing of those investments are not predictable.
Commitments and Contingencies
Supply and Offtake Agreements. On June 1, 2015, we entered into the Supply and Offtake Agreements with J. Aron to support the operations of our Hawaii refinery. On May 8, 2017, we and J. Aron amended the Supply and Offtake Agreements and extended the term through May 31, 2021 with a one-year extension option upon mutual agreement of the parties. The Supply and Offtake Agreements were amended and restated on December 21, 2017 in connection with the issuance of the 7.75% Senior Secured Notes and the entry into the ABL Credit Facility. Please read Note 8—Inventory Financing Agreements for more information.
Consent Decree. On July 18, 2016, PHR and subsidiaries of Tesoro entered into a consent decree with the EPA, the DOJ, and other state governmental authorities concerning alleged violations of the federal CAA related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (“Consent Decree”), including our Hawaii refinery. As a result of the Consent Decree, PHR expanded its previously-announced 2016 Hawaii refinery turnaround to undertake additional capital improvements to reduce emissions of air pollutants, to provide for certain nitrogen oxide and sulfur dioxide emission controls and monitoring and to install certain leak detection and repair equipment required by the Consent Decree. Although the turnaround was completed during the third quarter of 2016, work related to the Consent Decree is ongoing.
Tesoro is responsible under the Environmental Agreement for directly paying, or reimbursing PHR, for all reasonable third-party capital expenditures incurred pursuant to the Consent Decree to the extent related to acts or omissions prior to the date of the closing of the PHR acquisition. Tesoro is obligated to pay all applicable fines and penalties related to the Consent Decree. Please read Note 12—Commitments and Contingencies for more information.
Wyoming refinery. Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the EPA and/or the Wyoming Department of Environmental Quality, some of which date back to the late 1970s and several of which remain in effect, requiring further actions at the Wyoming refinery. Please read Note 12—Commitments and Contingencies for more information.
39

Forward-Looking Statements
Certain statements in this Quarterly Report on Form 10-Q may constitute “forward-looking” statements as defined in Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), the Private Securities Litigation Reform Act of 1995 (“PSLRA”) or in releases made by the SEC, all as may be amended from time to time. Such forward-looking statements involve known and unknown risks, uncertainties and other important factors including, without limitation, our beliefs with regard to available capital resources, our beliefs regarding the likelihood or impact of any potential fines or penalties and of the fair value of certain assets and our expectations with respect to laws and regulations, including environmental regulations and related compliance costs and any fines or penalties related thereto, including potential fines and penalties related to Wyoming Refining; our expectations regarding the sufficiency of our cash flows and liquidity; our expectations regarding anticipated capital improvements and the timing and cost of work that remains to be completed related to the Consent Decree; our expectations regarding the impact of the adoption of certain accounting standards; our beliefs as to the impact of changes to inputs regarding the valuation of our stock warrants, as well as our estimates regarding the fair value of such warrants and certain indebtedness; the anticipated results of the Mid Pac earn-out and indemnity dispute; estimated costs to settle claims from the Delta bankruptcy; the estimated value of, and our ability to settle, legal claims remaining to be settled against third parties; our expectations regarding certain tax liabilities and debt obligations; our expectations and estimates regarding our Supply and Offtake Agreements; management’s assumptions about future events; our ability to raise additional debt or equity capital; our ability to make strategic investments in business opportunities; and the estimates, assumptions and projections regarding future financial condition, results of operations, liquidity, and cash flows. These and other forward-looking statements could cause the actual results, performance or achievements of Par and its subsidiaries to differ materially from any future results, performance or achievements expressed or implied by such forward-looking statements. Statements that are not historical fact are forward-looking statements. Forward-looking statements can be identified by, among other things, the use of forward-looking language, such as the words “plan,” “believe,” “expect,” “anticipate,” “intend,” “estimate,” “project,” “may,” “will,” “would,” “could,” “should,” “seeks,” or “scheduled to,” or other similar words, or the negative of these terms or other variations of these terms or comparable language, or by discussion of strategy or intentions. These cautionary statements are being made pursuant to the Securities Act, the Exchange Act and the PSLRA with the intention of obtaining the benefits of the “safe harbor” provisions of such laws.
The forward-looking statements contained in this Quarterly Report on Form 10-Q are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control, including those set out in our most recent Annual Report on Form 10-K and this Quarterly Report on Form 10-Q under “Risk Factors.”
In addition, management’s assumptions about future events may prove to be inaccurate. All readers are cautioned that the forward-looking statements contained in this Quarterly Report on Form 10-Q are not guarantees of future performance; and we cannot assure any reader that such statements will be realized or that the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to factors described above and under Critical Accounting Policies and Risk Factors included in our most recent Annual Report on Form 10-K and in this Quarterly Report on Form 10-Q. All forward-looking statements speak only as of the date they are made. We do not intend to update or revise any forward-looking statements as a result of new information, future events or otherwise. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.
Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Commodity Price Risk
Our earnings, cash flow, and liquidity are significantly affected by commodity price volatility. Our Revenues fluctuate with refined product prices and our Cost of revenues (excluding depreciation) fluctuates with movements in crude oil and feedstock prices. Assuming all other factors remain constant, a $1 per barrel change in average gross refining margins, based on our throughput for the three months ended March 31, 2018 of 93 thousand barrels per day, would change annualized operating income by approximately $33.4 million. This analysis may differ from actual results.
In order to manage commodity price risks, we utilize exchange-traded futures, options, and OTC swaps to manage commodity price risks associated with:

• | the price for which we sell our refined products;

• | the price we pay for crude oil and other feedstocks;

• | our crude oil and refined products inventory; and

• | our fuel requirements for our Hawaii refinery.

40

Our Supply and Offtake Agreements with J. Aron require us to hedge our exposure based on the time spread between the crude oil cargo pricing period and the expected delivery month. We manage this exposure by entering into swaps with J. Aron. Please read Note 8—Inventory Financing Agreements for more information.
All of our futures and OTC swaps are executed to economically hedge our physical commodity purchases, sales, and inventory. Our open futures and OTC swaps expire at various dates through December 30, 2018. At March 31, 2018, these open commodity derivative contracts represent:

• | OTC swap purchases of 210 thousand barrels that economically hedge our crude oil and refined products month-end target inventory under our Supply and Offtake Agreements;

• | futures and OTC swap contracts of 30 thousand barrels that economically hedge our purchases of ethanol;

• | futures purchases contracts of 305 thousand barrels that economically hedge our sales of refined products; and

• | option collars of 60 thousand barrels per month and OTC swaps of 15 thousand barrels per month, both through December 2018, that economically hedge our internally consumed fuel.

Based on our net open positions at March 31, 2018, a $1 change in the price of crude oil, assuming all other factors remain constant, would result in a change of approximately $0.5 million to the fair value of these derivative instruments and Cost of revenues (excluding depreciation).
Our predominant variable operating cost is the cost of fuel consumed in the refining process, which is included in Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations. Assuming normal operating conditions, we consume approximately 76 thousand barrels per day of crude oil during the refining process at our Hawaii refinery. We internally consume approximately 3% of this throughput in the refining process, which is accounted for as a fuel cost. We have economically hedged our internally consumed fuel cost at our Hawaii refinery by purchasing option collars and swaps. These option collars have a weighted-average strike price ranging from a floor of $37.49 per barrel to a ceiling of $68.33 per barrel. The OTC swaps have a weighted-average price of $34.84. We do not economically hedge our internally consumed fuel cost at our Wyoming refinery.
Compliance Program Price Risk
We are exposed to market risks related to the volatility in the price of RINs required to comply with the Renewable Fuel Standard. Our overall RINs obligation is based on a percentage of our domestic shipments of on-road fuels as established by the EPA. To the degree we are unable to blend the required amount of biofuels to satisfy our RINs obligation, we must purchase RINs on the open market. To mitigate the impact of this risk on our results of operations and cash flows, we may purchase RINs when the price of these instruments is deemed favorable. Some of these contracts are derivative instruments, however, we elect the normal purchases normal sales exception and do not record these contracts at their fair values.
Interest Rate Risk
As of March 31, 2018, we had no outstanding debt that was subject to floating interest rates. We had interest rate exposure in connection with our liability under the J. Aron Supply and Offtake Agreements for which we pay a charge based on three-month LIBOR. An increase of 1% in the variable rate on our indebtedness, after considering the instruments subject to minimum interest rates, would result in an increase to our Cost of revenues (excluding depreciation) and Interest expense and financing costs, net, of approximately $1.4 million and $0.3 million per year, respectively.
We utilize interest rate swaps to manage our interest rate risk. As of March 31, 2018, we had locked in an average fixed rate of 0.97% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $100 million. The interest rate swap matures in February 2019. In February 2018, we terminated a separate $100 million floating interest rate swap originally maturing in March 2021, which resulted in a realized gain of $3.7 million.
Credit Risk
We are subject to risk of losses resulting from nonpayment or nonperformance by our counterparties. We will continue to closely monitor the creditworthiness of customers to whom we grant credit and establish credit limits in accordance with our credit policy.
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Item 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
In connection with the preparation of this Quarterly Report on Form 10-Q, as of March 31, 2018, an evaluation was performed under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that as of March 31, 2018, these disclosure controls and procedures were effective and designed to ensure that the information required to be disclosed in our reports filed with the SEC is recorded, processed, summarized, and reported on a timely basis and accumulated and reported to management as appropriate to allow timely decisions regarding disclosure.
Changes in Internal Control over Financial Reporting
There were no changes during the quarter ended March 31, 2018 in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financing reporting.
PART II – OTHER INFORMATION
Item 1. LEGAL PROCEEDINGS
From time to time, we may be involved in litigation relating to claims arising out of our operations in the normal course of our business. Please read Note 12—Commitments and Contingencies to our condensed consolidated financial statements for more information.
Item 1A. RISK FACTORS
We are subject to certain risks. For a discussion of these risks, see “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2017. There have been no material changes to the risk factors disclosed in our Annual Report on Form 10-K.
Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Dividends
We have not paid dividends on our common stock and we do not expect to do so in the foreseeable future. In addition, under the ABL Credit Facility and the indenture governing the 7.75% Senior Secured Notes, our subsidiaries are restricted from paying dividends or making other equity distributions, subject to certain exceptions.
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Stock Repurchases
The following table sets forth certain information with respect to repurchases of our common stock during the quarter ended March 31, 2018:

Period | Total number of shares (or units) purchased (1) |  | Average price paid per share (or unit) |  | Total number of shares (or units) purchased as part of publicly announced plans or programs |  | Maximum number (or approximate dollar value) of shares (or units) that may yet be purchased under the plans or programs
January 1 - January 31, 2018 | 1,989 |  |  | $ | 18.83 |  |  | — |  |  | — |
February 1 - February 28, 2018 | 22,388 |  |  | 17.24 |  |  | — |  |  | — |
March 1 - March 31, 2018 | 4,644 |  |  | 18.11 |  |  | — |  |  | — |
Total | 29,021 |  |  | $ | 17.49 |  |  | — |  |  | — |

________________________________________________
(1) All shares repurchased were surrendered by employees to pay taxes withheld upon the vesting of restricted stock awards.
Item 3. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
Item 4. MINE SAFETY DISCLSOURE
Not applicable.
Item 5. OTHER INFORMATION
None.
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Item 6. EXHIBITS

2.1 | Third Amended Joint Chapter 11 Plan of Reorganization of Delta Petroleum Corporation and Its Debtor Affiliates dated August 16, 2012. Incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K filed on September 7, 2012. @
2.2 | Contribution Agreement, dated as of June 4, 2012, among Piceance Energy, LLC, Laramie Energy, LLC and the Company. Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 8, 2012. @
2.3 | Purchase and Sale Agreement dated as of December 31, 2012, by and among the Company, SEACOR Energy Holdings Inc., SEACOR Holdings Inc., and Gateway Terminals LLC. Incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K filed on January 3, 2013. @
2.4 | Membership Interest Purchase Agreement dated as of June17, 2013, by and among Tesoro Corporation, Tesoro Hawaii, LLC and Hawaii Pacific Energy, LLC Incorporated by reference to Exhibit 2.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013, filed on August 14, 2013. @
2.5 | Agreement and Plan of Merger dated as of June 2, 2014, by and among the Company, Bogey, Inc., Koko’oha Investments, Inc., and Bill D. Mills, in his capacity as the Shareholders’ Representative. Incorporated by reference to Exhibit 2.5 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2014, filed on August 11, 2014. @
2.6 | Amendment of Agreement and Plan of Merger dated as of September 9, 2014, by and among the Company, Bogey, Inc., Koko’oha Investments, Inc. and Bill D. Mills, in his capacity as the Shareholders’ Representative. Incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on September 10, 2014. @
2.7 | Second Amendment of Agreement and Plan of Merger dated as of December 31, 2014, by and among Par Petroleum Corporation, Bogey, Inc., Koko’oha Investments, Inc. and Bill D. Mills, in his capacity as the Shareholder’s Representative. Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on January 7, 2015. @
2.8 | Third Amendment to Agreement and Plan of Merger dated as of March 31, 2015, by and among the Company, Bogey, Inc., Koko’oha Investments, Inc. and Bill D. Mills, in his capacity as the Shareholders’ Representative. Incorporated by reference to Exhibit 2.4 to the Company’s Current Report on Form 8-K filed on April 2, 2015. @
2.9 | Unit Purchase Agreement, dated as of June 13, 2016, between Par Wyoming, LLC and Black Elk Refining, LLC. Incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K filed on June 15, 2016. @
2.10 | First Amendment to Unit Purchase Agreement dated as of July 14, 2016, between Par Wyoming, LLC and Black Elk Refining, LLC. Incorporated by reference to Exhibit 2.2 to the Company’s Current Report on Form 8-K filed on July 15, 2016. @
3.1 | Restated Certificate of Incorporation of the Company dated October 20, 2015. Incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on October 20, 2015.
3.2 | Second Amended and Restated Bylaws of the Company dated October 20, 2015. Incorporated by reference to Exhibit 3.3 to the Company’s Current Report on Form 8-K filed on October 20, 2015.
4.1 | Form of the Company’s Common Stock Certificate. Incorporated by reference to Exhibit 4.1 to the Company’s Annual Report on Form 10-K filed on March 31, 2014.
4.2 | Stockholders Agreement dated April 10, 2015. Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on April 13, 2015.
4.3 | Registration Rights Agreement effective as of August 31, 2012, by and among the Company, Zell Credit Opportunities Master Fund, L.P., Waterstone Capital Management, L.P., Pandora Select Partners, LP, Iam Mini-Fund 14 Limited, Whitebox Multi-Strategy Partners, LP, Whitebox Credit Arbitrage Partners, LP, HFR RVA Combined Master Trust, Whitebox Concentrated Convertible Arbitrage Partners, LP and Whitebox Asymmetric Partners, LP. Incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on September 7, 2012.
4.4 | Registration Rights Agreement dated as of September 25, 2013, by and among the Company and the Purchasers party thereto. Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on September 27, 2013.

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4.5 | Warrant Issuance Agreement dated as of August 31, 2012, by and among the Company and WB Delta, Ltd., Waterstone Offshore ER Fund, Ltd., Prime Capital Master SPC, Waterstone Market Neutral MAC51, Ltd., Waterstone Market Neutral Master Fund, Ltd., Waterstone MF Fund, Ltd., Nomura Waterstone Market Neutral Fund, ZCOF Par Petroleum Holdings, L.L.C. and Highbridge International, LLC. Incorporated by reference to Exhibit 4.4 to the Company’s Current Report on Form 8-K filed on September 7, 2012.
4.6 | Form of Common Stock Purchase Warrant dated as of June 4, 2012. Incorporated by reference to Exhibit 4.5 to the Company’s Current Report on Form 8-K filed on September 7, 2012.
4.7 | Indenture, dated June 21, 2016, between Par Pacific Holdings, Inc. and Wilmington Trust, National Association, as Trustee. Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on June 22, 2016.
4.8 | Registration Rights Agreement, dated June 21, 2016, between Par Pacific Holdings, Inc. and Merrill Lynch, Pierce, Fenner & Smith Incorporated, as representative of the Initial Purchasers. Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 22, 2016.
4.9 | Registration Rights Agreement dated as of July 14, 2016, by and among Par Pacific Holdings, Inc. and the purchasers party thereto. Incorporated by Reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on July 15, 2016.
4.10 | First Amendment to Registration Rights Agreement dated as of September 27, 2016, by and among the Company and the purchasers party thereof. Incorporated by reference to Exhibit 4.14 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.11 | Second Amendment to Registration Rights Agreement dated as of September 30, 2016, by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.15 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.12 | Third Amendment to Registration Rights Agreement dated as of October 7, 2016, by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.16 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.13 | Fourth Amendment to Registration Rights Agreement dated as of October 14, 2016, by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.17 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.14 | Fifth Amendment to Registration Rights Agreement dated as of October 21, 2016, by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.18 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.15 | Sixth Amendment to Registration Rights Agreement dated as of October 28, 2016 by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.19 to the Company’s Quarterly Report on Form 10-Q filed on November 4, 2016.
4.16 | Second Amended and Restated Par Pacific Holdings, Inc. 2012 Long Term Incentive Plan. Incorporated by reference to Appendix A to the Company’s Proxy Statement on Schedule 14A filed on March 28, 2018.
4.17 | Par Pacific Holdings, Inc. 2018 Employee Stock Purchase Plan. Incorporated by reference to Appendix B to the Company’s Proxy Statement on Schedule 14A filed on March 28, 2018.
10.1 | First Amendment to Loan and Security Agreement dated as of April 3, 2018 by and among Par Petroleum, LLC, Par Hawaii, Inc., Mid Pac Petroleum, LLC, HIE Retail, LLC, Hermes Consolidated, LLC, and Wyoming Pipeline Company LLC and Bank of America, N.A. *
10.2 | Asset Purchase Agreement dated as of January 9, 2018 by and among CHS Inc., Par Hawaii, Inc., and Par Pacific Holdings, Inc. * #
10.3 | First Amendment to Asset Purchase Agreement dated as of March 23, 2018 by and among CHS Inc., Par Hawaii, Inc., and Par Pacific Holdings, Inc. * #
31.1 | Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. *
31.2 | Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. *
32.1 | Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350.*
32.2 | Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350. *
101.INS | XBRL Instance Document.**
101.SCH | XBRL Taxonomy Extension Schema Documents.**

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101.CAL | XBRL Taxonomy Extension Calculation Linkbase Document.**
101.LAB | XBRL Taxonomy Extension Label Linkbase Document.**
101.PRE | XBRL Taxonomy Extension Presentation Linkbase Document.**
101.DEF | XBRL Taxonomy Extension Definition Linkbase Document.**

* Filed herewith.
** These interactive data files are furnished and deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.
@ Schedules and similar attachments have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The Company will furnish supplementally a copy of any omitted schedule or similar attachment to the Securities and Exchange Commission upon request.
# Confidential treatment has been requested for portions of this exhibit. Omissions are designated with brackets containing asterisks. As part of our confidential treatment request, a complete version of this exhibit has been filed separately with the Securities and Exchange Commission.
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SIGNATURES
Pursuant to the requirements of the Securities Exchange of Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

| PAR PACIFIC HOLDINGS, INC. (Registrant)
| By: | /s/ William Pate |  |
|  | William Pate |  |
|  | President and Chief Executive Officer |  |
| By: | /s/ William Monteleone |  |
|  | William Monteleone |  |
|  | Chief Financial Officer |  |

Date: May 10, 2018
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