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 September 30, 2017

¨ 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

Indicate by check mark whether the registrant has filed all document and reports required to be filed by Sections 12, 13, or 15 (d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.    Yes  ý    No  ¨

45,790,387 shares of common stock, $0.01 par value, were outstanding as of November 6, 2017.

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	24
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	39
Item 4.	Controls and Procedures	40
PART II OTHER INFORMATION
Item 1.	Legal Proceedings	41
Item 1A.	Risk Factors	41
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	41
Item 3.	Defaults Upon Senior Securities	42
Item 4.	Mine Safety Disclosures	42
Item 5.	Other Information	42
Item 6.	Exhibits	43

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)

	September 30, 2017			December 31, 2016
ASSETS
Current assets
Cash and cash equivalents	$	78,300		$	47,772
Restricted cash	744			1,246
Trade accounts receivable	89,665			102,384
Inventories	319,864			198,326
Prepaid and other current assets	8,939			53,380
Total current assets	497,512			403,108
Property and equipment
Property, plant, and equipment	520,464			499,867
Proved oil and gas properties, at cost, successful efforts method of accounting	1,122			1,122
Total property and equipment	521,586			500,989
Less accumulated depreciation and depletion	(72,965		)	(49,727		)
Property and equipment, net	448,621			451,262
Long-term assets
Investment in Laramie Energy, LLC	120,474			108,823
Intangible assets, net	27,431			29,912
Goodwill	107,187			105,732
Other long-term assets	33,957			46,596
Total assets	$	1,235,182		$	1,145,433
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current maturities of long-term debt	$	27,140		$	20,286
Obligations under inventory financing agreements	310,176			225,135
Accounts payable	51,442			65,190
Advances from customers	26,928			23,774
Accrued taxes	14,504			13,194
Other accrued liabilities	28,083			35,186
Total current liabilities	458,273			382,765
Long-term liabilities
Long-term debt, net of current maturities	303,061			350,110
Common stock warrants	7,345			5,134
Long-term capital lease obligations	1,171			1,780
Other liabilities	37,848			36,735
Total liabilities	807,698			776,524
Commitments and contingencies (Note 11)
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 September 30, 2017 and December 31, 2016, 45,778,788 shares and 45,533,913 shares issued at September 30, 2017 and December 31, 2016, respectively	458			455
Additional paid-in capital	592,013			587,057
Accumulated deficit	(167,183		)	(220,799		)
Accumulated other comprehensive income	2,196			2,196
Total stockholders’ equity	427,484			368,909
Total liabilities and stockholders’ equity	$	1,235,182		$	1,145,433

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						Nine Months Ended
	September 30,						September 30,
	2017			2016			2017			2016
Revenues	$	610,506		$	510,305		$	1,780,004		$	1,301,909
Operating expenses
Cost of revenues (excluding depreciation)	509,476			459,296			1,485,118			1,166,347
Operating expense (excluding depreciation)	51,718			51,240			153,741			125,325
Depreciation, depletion, and amortization	11,304			9,643			33,848			19,839
General and administrative expense (excluding depreciation)	11,292			9,863			34,688			31,654
Acquisition and integration expense	—			2,047			253			3,563
Total operating expenses	583,790			532,089			1,707,648			1,346,728
Operating income (loss)	26,716			(21,784		)	72,356			(44,819		)
Other income (expense)
Interest expense and financing costs, net	(7,419		)	(11,232		)	(25,500		)	(21,951		)
Loss on termination of financing agreements	—			—			(1,804		)	—
Other income (expense), net	649			(56		)	886			60
Change in value of common stock warrants	(975		)	657			(2,211		)	3,477
Change in value of contingent consideration	—			1,025			—			10,753
Equity earnings (losses) from Laramie Energy, LLC	553			3,659			11,651			(15,159		)
Total other income (expense), net	(7,192		)	(5,947		)	(16,978		)	(22,820		)
Income (loss) before income taxes	19,524			(27,731		)	55,378			(67,639		)
Income tax benefit (expense)	(700		)	(30		)	(1,762		)	8,117
Net income (loss)	$	18,824		$	(27,761	)	$	53,616		$	(59,522	)
Earnings (loss) per share
Basic	$	0.41		$	(0.67	)	$	1.16		$	(1.44	)
Diluted	$	0.41		$	(0.67	)	$	1.16		$	(1.44	)
Weighted-average number of shares outstanding
Basic	45,561			41,580			45,505			41,309
Diluted	51,992			41,580			45,527			41,309

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)

	Nine Months Ended September 30,
	2017			2016
Cash flows from operating activities:
Net income (loss)	$	53,616		$	(59,522	)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, depletion, and amortization	33,848			19,839
Loss on termination of financing agreements	1,804			—
Non-cash interest expense	6,189			11,426
Change in value of common stock warrants	2,211			(3,477		)
Change in value of contingent consideration	—			(10,753		)
Deferred taxes	462			(8,565		)
Stock-based compensation	5,803			5,103
Unrealized loss (gain) on derivative contracts	557			(5,804		)
Equity (earnings) losses from Laramie Energy, LLC	(11,651		)	15,159
Net changes in operating assets and liabilities:
Trade accounts receivable	12,070			3,233
Prepaid and other assets	46,747			29,258
Inventories	(121,040		)	50,390
Deferred turnaround expenditures	—			(34,969		)
Obligations under inventory financing agreements	89,549			(11,795		)
Accounts payable and other accrued liabilities	(14,709		)	(35,941		)
Contingent consideration	—			(4,830		)
Net cash provided by (used in) operating activities	105,456			(41,248		)
Cash flows from investing activities:
Acquisitions of businesses, net of cash acquired	—			(209,183		)
Capital expenditures	(19,888		)	(19,276		)
Proceeds from sale of assets	19			2,323
Change in restricted cash	502			(10,000		)
Investment in Laramie Energy, LLC	—			(55,000		)
Net cash used in investing activities	(19,367		)	(291,136		)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs	—			49,315
Proceeds from borrowings	239,538			301,782
Repayments of borrowings	(292,684		)	(137,791		)
Net borrowings (repayments) on deferred payment arrangement	(1,493		)	26,654
Payment of deferred loan costs	(50		)	(6,805		)
Contingent consideration settlements	—			(11,980		)
Other financing activities, net	(872		)	(325		)
Net cash provided by (used in) financing activities	(55,561		)	220,850
Net increase (decrease) in cash and cash equivalents	30,528			(111,534		)
Cash and cash equivalents at beginning of period	47,772			167,788
Cash and cash equivalents at end of period	$	78,300		$	56,254
Supplemental cash flow information:
Net cash received (paid) for:
Interest	$	(15,168	)	$	(7,573	)
Taxes	(1,115		)	139
Non-cash investing and financing activities:
Accrued capital expenditures	$	4,469		$	2,583
Value of warrants and debt reclassified to equity	—			3,084

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 September 30, 2017 and 2016

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, 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, ultra-low sulfur diesel, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota.

2) Retail - Our retail outlets sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our retail network includes Hele and “76” branded retail sites, cardlock stations, company-operated convenience stores, sites operated in cooperation with 7-Eleven, and other sites operated by third parties.

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 42.3% 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, our Texadian operations, 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, 2016 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, 2016.

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.

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 Renewable Identification Numbers(“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.

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.

4

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

The following table summarizes depreciation expense excluded from each line item in our consolidated statements of operations (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Cost of revenues	$	1,568	$	1,243	$	4,510	$	3,081
Operating expense	8,226		6,690		24,700		11,624
General and administrative expense	576		512		1,981		1,451

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, 2016, except for the following:

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”). The FASB’s objective was to provide a more robust framework to improve comparability of revenue recognition practices across entities by removing most industry and transaction specific guidance, align GAAP with International Financial Reporting Standards, and provide more useful information to financial statement users. This authoritative guidance changes the way entities recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date (“ASU 2015-14”), which defers the effective date of ASU 2014-09 by one year. ASU 2014-09 is now effective for interim and annual periods beginning after December 15, 2017 and early adoption is permitted for interim and annual periods beginning after December 15, 2016. We have formally established a working group to assess the amended revenue recognition guidance in Topic 606, including its impact on our business processes, accounting systems, controls, and financial statement disclosures. As part of our evaluation, the working group is reviewing existing revenue streams and identifying the types of arrangements where differences may arise in revenue recognition upon adoption of the new standard. Our largest revenue stream consists of revenues generated from the sale of refined products, generally at market prices. These revenues are recognized upon delivery of goods to a customer. Although we currently do not expect the new standard to have a material impact on the amount or timing of revenues recognized for the sale of refined products, we continue to evaluate the impact of this new standard on our consolidated financial statements and related disclosures.

In March 2017, the FASB issued 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 requires 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 requires entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. ASU 2017-07 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted as of the beginning of any annual period for which an entity’s financial statements (interim or annual) have not been issued or made available for issuance. ASU 2017-07 should be applied retrospectively for the presentation of cost components in the income statement and prospectively for the capitalization of the service cost component in assets. We do not expect the adoption of ASU 2017-07 to have a material impact on our financial condition, results of operations, or cash flows.

In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU is 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 guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied prospectively to an award modified on or after the adoption date. We do not expect the adoption of ASU 2017-09 to have a material impact on our financial condition, results of operations, or cash flows.

Accounting Principles Adopted

On January 1, 2017, we adopted ASU No. 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding

5

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

requirements as well as classification in the statement of cash flows. The adoption of this ASU did not have a material impact on our financial condition, results of operations, or cash flows.

On January 1, 2017, we adopted ASU No. 2016-07, Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting (“ASU 2016-07”). ASU 2016-07 simplifies the equity method of accounting by eliminating the requirement to retrospectively apply the equity method to an investment that subsequently qualifies for such accounting as a result of an increase in the level of ownership interest or degree of influence. The adoption of this ASU did not have any impact on our financial condition, results of operations, or cash flows.

Note 3—Investment in Laramie Energy, LLC

We have a 42.3% ownership interest in Laramie Energy. Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado. We acquired our equity interest in Laramie Energy as a result of (1) the contribution of certain natural gas and oil interests to Laramie Energy in conjunction with our corporate reorganization in August 2012 and (2) cash contributions of $27.5 million in 2015 and $55.0 million in 2016.

Laramie Energy has a $400 million revolving credit facility with a borrowing base currently set at $210 million that is secured by a lien on its natural gas and crude oil properties and related assets. As of September 30, 2017, the balance outstanding on the revolving credit facility was approximately $149 million. We are limited recourse guarantors of Laramie Energy’s credit facility, with such 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):

	Nine Months Ended September 30, 2017
Beginning balance	$	108,823
Equity earnings from Laramie Energy	7,657
Accretion of basis difference	3,994
Ending balance	$	120,474

Summarized financial information for Laramie Energy is as follows (in thousands):

	September 30, 2017		December 31, 2016
Current assets	$	12,149	$	12,199
Non-current assets	690,600		655,022
Current liabilities	43,599		58,067
Non-current liabilities	213,517		186,631

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Natural gas and oil revenues	$	38,141		$	31,091		$	114,178		$	68,513
Income (loss) from operations	133			(4,929		)	(162		)	(28,282		)
Net income (loss)	(1,838		)	5,056			18,102			(41,183		)

Laramie Energy's net (loss) income for the three and nine months endedSeptember 30, 2017 includes $12.3 million and $38.1 million of depreciation, depletion, and amortization (“DD&A”) and $2.3 million and $35.2 million of unrealized gain on derivative instruments, respectively. Laramie Energy’s net income (loss) for the three and nine months endedSeptember 30, 2016 includes $13.5 million and $34.1 million of DD&A and $12.7 million of unrealized gain and $16.8 million of unrealized loss on derivative instruments, respectively.

At September 30, 2017 and December 31, 2016, our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $63.8 million and $67.8 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

6

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

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

Wyoming Refining Company Acquisition

On June 14, 2016, Par Wyoming, LLC, a wholly owned subsidiary of Par, entered into a unit purchase agreement (the “Purchase Agreement”) with Black Elk Refining, LLC to purchase all of the issued and outstanding units representing the membership interests in Hermes Consolidated, LLC (d/b/a Wyoming Refining Company) and, indirectly, Wyoming Refining Company’s wholly owned subsidiary, Wyoming Pipeline Company, LLC (collectively, “Wyoming Refining” or “WRC”) (the “WRC Acquisition”). Wyoming Refining owns and operates a refinery and related logistics assets in Newcastle, Wyoming.

On July 14, 2016, we completed the WRC Acquisition for cash consideration of $209.4 million, including a deposit of $5.0 million paid in June 2016, and assumed debt consisting of term loans of $58.0 million and revolving loans of $10.1 million. The consideration was paid with funds received from the issuance of our 2.50% convertible subordinated bridge notes (the “Bridge Notes”), cash on hand, which included the net proceeds from our June 2016 issuance and sale of an aggregate of $115 million principal amount of 5.00% convertible senior notes due 2021 (the “5.00% Convertible Senior Notes”), and the issuance of a $65 million secured term loan by Par Wyoming Holdings, LLC (the “Par Wyoming Holdings Credit Agreement”).

We accounted for the WRC Acquisition 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 the acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Wyoming Refining and utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. Goodwill recognized as a result of the WRC Acquisition is expected to be deductible for income tax reporting purposes.

During the three months ended June 30, 2017, the purchase price allocation was adjusted to record an increase of $2.0 million to our Wyoming refinery’s environmental liability as a result of additional information obtained by management regarding estimated remediation costs at certain locations. The purchase price allocation was also adjusted to record an increase to inventory of $0.5 million related to line fill inventory at our refined product pipelines. Goodwill increased $1.5 million as a result of these adjusting entries recorded during the three months ended June 30, 2017. As of June 30, 2017, we finalized the WRC Acquisition purchase price allocation.

A summary of the fair values of the assets acquired and liabilities assumed is as follows (in thousands):

Cash	$	183
Accounts receivable	16,880
Inventories	28,402
Prepaid and other assets	1,304
Property, plant, and equipment	254,367
Goodwill (1)	66,449
Accounts payable and other current liabilities	(57,861		)
Wyoming Refining Senior Secured Revolver	(10,100		)
Wyoming Refining Senior Secured Term Loan	(58,036		)
Other non-current liabilities	(32,222		)
Total	$	209,366

______________________________________________

(1) We allocated $39.8 million and $26.6 million of goodwill to our refining and logistics segments, respectively.

7

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

The results of operations of Wyoming Refining were included in our results beginning July 14, 2016. The following unaudited pro forma financial information presents our consolidated revenues and net loss as if the WRC Acquisition had been completed on January 1, 2015 (in thousands, except per share amounts):

	Three Months Ended September 30, 2016			Nine Months Ended September 30, 2016
Revenues	$	522,163		$	1,463,101
Net loss	(26,384		)	(64,926		)
Loss per share
Basic	$	(0.58	)	$	(1.43	)
Diluted	$	(0.58	)	$	(1.43	)

Note 5—Inventories

Inventories at September 30, 2017 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements (1)		Total
Crude oil and feedstocks	$	64,208	$	71,371	$	135,579
Refined products and blendstock	52,734		110,222		162,956
Warehouse stock and other	21,329		—		21,329
Total	$	138,271	$	181,593	$	319,864

Inventories at December 31, 2016 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements(1)		Total
Crude oil and feedstocks	$	11,620	$	49,682	$	61,302
Refined products and blendstock	38,916		77,677		116,593
Warehouse stock and other	20,431		—		20,431
Total	$	70,967	$	127,359	$	198,326

________________________________________________________

(1) Please read Note 7—Inventory Financing Agreements for further information.

There was no reserve for the lower of cost or net realizable value of inventory as of September 30, 2017. As of December 31, 2016, the reserve for the lower of cost or net realizable value of inventory was $0.2 million.

Note 6—Prepaid and Other Current Assets

Prepaid and other current assets at September 30, 2017 and December 31, 2016 consisted of the following (in thousands):

	September 30, 2017		December 31, 2016
Advances to suppliers for crude oil purchases	$	—	$	38,300
Collateral posted with broker for derivative instruments	708		2,714
Prepaid insurance	—		7,504
Derivative assets	2,413		161
Other	5,818		4,701
Total	$	8,939	$	53,380

Note 7—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, we also entered into a $30 million forward sale of certain monthly volumes of jet fuel to be delivered to J. Aron over the remaining term of the Supply and Offtake Agreements (“J. Aron Forward Sale”). The obligation associated with this forward sale is recorded as debt in our condensed consolidated balance sheets. Please read Note 8—Debt for additional information regarding this forward sale.

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 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. Our obligations under the Supply and Offtake Agreements are secured by a security interest on substantially all of the assets of our subsidiary Par Hawaii Refining, LLC (“PHR”), a security interest on the equity interests held by our wholly owned subsidiary, Par Petroleum, LLC, in PHR, and a mortgage whereby PHR granted to J. Aron a lien on all real property and improvements owned by PHR, including our Hawaii refinery.

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 and nine months endedSeptember 30, 2017, we incurred approximately $3.4 million and $9.8 million in handling fees related to the Supply and Offtake Agreements, respectively, which is included in Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations. For the three and nine months endedSeptember 30, 2016, we incurred approximately $1.7 million and $5.6 million in handling fees related to the Supply and Offtake Agreements, respectively. For the three and nine months endedSeptember 30, 2017, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.8 million and $2.3 million of expenses related to the Supply and Offtake Agreements, respectively. For the three and nine months endedSeptember 30, 2016, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.9 million and $2.2 million of expenses related to the Supply and Offtake Agreements, respectively.

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 September 30, 2017 and December 31, 2016, the capacity of the Deferred Payment Arrangement was $75.5 million and $59.4 million, respectively. As of September 30, 2017 and December 31, 2016, we had $41.8 million and $43.3 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 September 2015, we entered into an agreement to fix this market fee for the period from October 1, 2015 through November 30, 2016 whereby J. Aron agreed to pay us a total of $18 million to be settled in fourteen equal monthly payments. In February 2016, we fixed the market fee for the period from December 1, 2016 through May 31, 2018 for an additional $14.6 million to be settled in eighteen equal monthly payments. In July and August 2017 we fixed the market fee for the period from June 1, 2018 through April 2021 for an additional aggregate $3.0 million. The receivable from J. Aron was recorded as a reduction to our

8

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Obligations under inventory financing agreements pursuant to our Master Netting Agreement. As of September 30, 2017 and December 31, 2016, the receivable was $10.3 million and $14.6 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 9—Derivatives for further information.

Note 8—Debt

The following table summarizes our outstanding debt (in thousands):

	September 30, 2017			December 31, 2016
Hawaii Retail Credit Facilities	$	85,023		$	95,319
5.00% Convertible Senior Notes due 2021	115,000			115,000
Term Loan	—			60,361
J. Aron Forward Sale	27,855			—
Par Wyoming Holdings Term Loan	67,325			67,325
Wyoming Refining Senior Secured Term Loan	48,752			55,715
Wyoming Refining Senior Secured Revolver	9,502			6,700
Principal amount of long-term debt	353,457			400,420
Less: unamortized discount and deferred financing costs	(23,256		)	(30,024		)
Total debt, net of unamortized discount and deferred financing costs	330,201			370,396
Less: current maturities	(27,140		)	(20,286		)
Long-term debt, net of current maturities	$	303,061		$	350,110

Our debt is subject to various affirmative, negative, and financial covenants. As of September 30, 2017, we were in compliance with all debt covenants. Some of our subsidiaries have restrictions in their respective credit facilities with regard to dividends, distributions, loans, or advances. In certain circumstances, the consent of a third party would be required prior to the transfer of any cash or assets from these subsidiaries to us.

J. Aron Forward Sale

On May 8, 2017, J. Aron and the Company 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, we also entered into a $30 million forward sale of jet fuel to be delivered to J. Aron over the amended term (“J. Aron Forward Sale”). The proceeds from the J. Aron Forward Sale were used to pay a portion of the outstanding balance on the Term Loan.

The $30 million obligation under the J. Aron Forward Sale will be repaid through the monthly delivery of jet fuel at an agreed upon price between the two parties. The jet fuel volumes to be delivered to J. Aron are equivalent to principal payments of $3.9 million in 2017, $7.0 million in 2018, $7.5 million in 2019, $8.1 million in 2020, and $3.5 million in 2021. The cost of the J. Aron Forward Sale is based upon an annual interest rate of 7%.

The obligation associated with the J. Aron Forward Sale is recorded as debt in our condensed consolidated balance sheets. As of September 30, 2017, the outstanding balance of the J. Aron Forward Sale debt obligation was $27.9 million.

Wyoming Refining Credit Facilities

Wyoming Refining Company and its wholly owned subsidiary, Wyoming Pipeline Company, LLC, are borrowers under a Third Amended and Restated Loan Agreement dated as of April 30, 2015 (as amended, the “Wyoming Refining Credit Facilities”), with Bank of America, N.A. as the lender. The Wyoming Refining Credit Facilities provide for (1) a revolving credit facility in the maximum principal amount at any time outstanding of $30 million (“Wyoming Refining Senior Secured Revolver”), subject to a borrowing base, which provides for revolving loans and for the issuance of letters of credit and (2) certain term loans that are fully advanced (“Wyoming Refining Senior Secured Term Loan”). The Wyoming Refining Senior Secured Term Loan requires quarterly principal payments of $2.3 million. On August 7, 2017, we entered into an amendment to the Wyoming Refining Credit Facilities to extend the maturity date from April 30, 2018 until June 30, 2019. All remaining outstanding amounts under the Wyoming Refining Senior Secured Term Loan and the Wyoming Refining Senior Secured Revolver are fully payable on June 30, 2019.

9

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

5.00% Convertible Senior Notes Due 2021

As of September 30, 2017, the outstanding principal amount of the 5.00% Convertible Senior Notes was $115.0 million, the unamortized discount and deferred financing cost was $20.7 million, and the carrying amount of the liability component was $94.3 million.

Term Loan

On June 30, 2017, we fully repaid and terminated the Delayed Draw Term Loan and Bridge Loan Credit Agreement (“Term Loan”). A portion of the proceeds from the J. Aron Forward Sale and cash flows from operations were used to repay the full amount outstanding. We recorded a loss on termination of approximately $1.8 million related to unamortized deferred financing costs associated with the Term Loan in the nine months endedSeptember 30, 2017.

Hawaii Retail Credit Facilities

On June 28, 2017, certain subsidiaries of the Company entered into a second amendment to the Key Bank Credit Agreement dated December 17, 2015 in order to permit a special distribution of cash from such subsidiaries to the Company in an aggregate amount totaling no more than $15 million. The amendment also waived the mandatory excess cash flow prepayment for the quarter ended June 30, 2017.

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 September 30, 2017, we are in compliance with all of our credit 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 9—Derivatives

Commodity Derivatives

We utilize crude oil commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, and future sales of refined products. 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 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.

10

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

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 10—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 September 30, 2017, our open commodity derivative contracts represented:

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

• OTC swap sales of 115 thousand barrels that economically hedge our month-end target volumes related to our Supply and Offtake Agreements; and

• option collars of 52 thousand barrels per month through December 2017 and option collars and OTC swaps of 75 thousand barrels per month 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 September 30, 2017, we had locked in an average fixed rate of 1.1% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $200 million. The interest rate swaps mature in February 2019 and March 2021.

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 September 30, 2017, 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 September 30, 2017 and December 31, 2016 and their placement within our condensed consolidated balance sheets.

	Balance Sheet Location	September 30, 2017			December 31, 2016
		Asset (Liability)
Commodity derivatives (1)	Prepaid and other current assets	$	1,561		$	—
Commodity derivatives (1)	Other long-term assets	571			2,748
Commodity derivatives	Other accrued liabilities	(58		)	(595		)
J. Aron repurchase obligation derivative	Obligations under inventory financing agreements	(24,995		)	(20,000		)
Interest rate derivatives	Prepaid and other current assets	851			161
Interest rate derivatives	Other long-term assets	2,115			3,377
Interest rate derivatives	Other accrued liabilities	—			(94		)

_________________________________________________________

(1) Does not include cash collateral of $0.7 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of September 30, 2017 and December 31, 2016, respectively.

11

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

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 September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2017			2016			2017			2016
Commodity derivatives	Cost of revenues (excluding depreciation)	$	3,657		$	(3,028	)	$	26		$	(3,117	)
J. Aron repurchase obligation derivative	Cost of revenues (excluding depreciation)	(24,041		)	(8,300		)	(4,995		)	(20,356		)
Interest rate derivatives	Interest expense and financing costs, net	148			1,204			(477		)	(1,098		)

Note 10—Fair Value Measurements

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Common Stock Warrants

As of September 30, 2017 and December 31, 2016, 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 September 30, 2017 and December 31, 2016, the warrants had a weighted-average exercise price of $0.09 and $0.10 and a remaining term of 4.92 years and 5.67 years, respectively.

The estimated fair value of the common stock warrants was $20.73 and $14.49 per share as of September 30, 2017 and December 31, 2016, respectively.

Derivative Instruments

We utilize crude oil commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil, and future sales of refined products. 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 September 30, 2017 or December 31, 2016. Please read Note 9—Derivatives for further information on derivatives.

12

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Financial Statement Impact

Fair value amounts by hierarchy level as of September 30, 2017 and December 31, 2016 are presented gross in the tables below (in thousands):

	September 30, 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	$	235		$	28,733		$	—		$	28,968		$	(26,836	)	$	2,132
Interest rate derivatives	—			2,966			—			2,966			—			2,966
Total	$	235		$	31,699		$	—		$	31,934		$	(26,836	)	$	5,098
Liabilities
Common stock warrants	$	—		$	—		$	(7,345	)	$	(7,345	)	$	—		$	(7,345	)
Commodity derivatives	(150		)	(26,744		)	—			(26,894		)	26,836			(58		)
J. Aron repurchase obligation derivative	—			—			(24,995		)	(24,995		)	—			(24,995		)
Total	$	(150	)	$	(26,744	)	$	(32,340	)	$	(59,234	)	$	26,836		$	(32,398	)

	December 31, 2016
	Level 1			Level 2			Level 3			Gross Fair Value			Effect of Counter-Party Netting			Net Carrying Value on Balance Sheet (1)
Assets
Commodity derivatives	$	190		$	26,095		$	—		$	26,285		$	(23,537	)	$	2,748
Interest rate derivatives	—			3,602			—			3,602			(64		)	3,538
Total	$	190		$	29,697		$	—		$	29,887		$	(23,601	)	$	6,286
Liabilities
Common stock warrants	$	—		$	—		$	(5,134	)	$	(5,134	)	$	—		$	(5,134	)
Commodity derivatives	(54		)	(24,078		)	—			(24,132		)	23,537			(595		)
J. Aron repurchase obligation derivative	—			—			(20,000		)	(20,000		)	—			(20,000		)
Interest rate derivatives	—			(158		)	—			(158		)	64			(94		)
Total	$	(54	)	$	(24,236	)	$	(25,134	)	$	(49,424	)	$	23,601		$	(25,823	)

_________________________________________________________

(1) Does not include cash collateral of $7.7 million and $9.7 million as of September 30, 2017 and December 31, 2016, respectively, included within Prepaid and other current assets and Other long-term assets on our condensed consolidated balance sheets.

13

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

A roll forward of Level 3 financial instruments measured at fair value on a recurring basis is as follows (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Balance, at beginning of period	$	(7,324	)	$	(8,564	)	$	(25,134	)	$	(25,867	)
Settlements	—			—			—			16,810
Total unrealized income (loss) included in earnings	(25,016		)	(6,618		)	(7,206		)	(6,125		)
Balance, at end of period	$	(32,340	)	$	(15,182	)	$	(32,340	)	$	(15,182	)

The carrying value and fair value of long-term debt and other financial instruments as of September 30, 2017 and December 31, 2016 are as follows (in thousands):

	September 30, 2017
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	83,773	$	83,773
5.00% Convertible Senior Notes due 2021 (3)	94,328		154,116
J. Aron Forward Sale	27,855		27,523
Par Wyoming Holdings Term Loan (2)	66,091		66,091
Wyoming Refining Senior Secured Term Loan (2)	48,652		48,652
Wyoming Refining Senior Secured Revolver (2)	9,502		9,502
Common stock warrants	7,345		7,345

	December 31, 2016
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	93,853	$	93,853
5.00% Convertible Senior Notes due 2021 (3)	91,029		122,229
Term Loan	57,426		62,367
Par Wyoming Holdings Term Loan (2)	65,908		65,908
Wyoming Refining Senior Secured Term Loan (2)	55,480		55,480
Wyoming Refining Senior Secured Revolver (2)	6,700		6,700
Common stock warrants	5,134		5,134

_________________________________________________________

(1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy with the exception of the fair value measurement of the 5.00% Convertible Senior Notes which is considered a Level 2 measurement as discussed below.

(2) Fair value approximates carrying value due to the debt’s floating rate interest which approximates current market value.

(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.

We estimated the fair value of the J. Aron Forward Sale using a discounted cash flow analysis and an assumed yield of 8.00% as of September 30, 2017 by reference to market interest rates for similar debt instruments of comparable companies.

We estimated the fair value of the Term Loan using a discounted cash flow analysis and an estimate of the current yield of 11.06% as of December 31, 2016 by reference to market interest rates for term debt of comparable companies.

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%

14

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Convertible Senior Notes, and an implied volatility based on market values of options outstanding as of September 30, 2017. 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 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 11—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.

Tesoro Earnout 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 it 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. The cash consideration for the acquisition is subject to an earn-out provision during the years 2014-2016, subject to, among other things, an annual earn-out cap of $20 million. During 2016, we paid Tesoro a total of $16.8 million to settle the 2014 and 2015 earn-out periods. Tesoro has disputed our calculation of the 2015 and 2016 earn-out amounts and has asserted that it is 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.  If we and Tesoro are unable to agree on the calculation of the 2015 and 2016 earn-out amounts, the dispute will be resolved in accordance with the dispute resolution provisions set forth in the membership interest purchase agreement to determine the amounts owed, if any. The Company disputes that any additional amounts are due and intends to vigorously defend itself in connection with the resolution of Tesoro’s claims.

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 Petroleum, LLC (“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 March 19, 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 February 26, 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.

15

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

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.

Wyoming refinery

Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the U.S. Environmental Protection Agency(“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 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. Based on current information, however, estimates we have received for the well-understood components of these efforts suggest total response costs of approximately $20.0 million, approximately one-third of which we expect to incur in the next 5 years, with 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 $0.5 million to modify or close the existing wastewater treatment ponds and 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 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 appears to be declining over time, Wyoming Refining may become subject to new penalty enforcement action in the next several years, which could involve penalties in excess of $100,000. Moreover, in addition to the issues associated with the Wyoming refinery, certain product pipeline assets were acquired in the WRC Acquisition. The Pipeline and Hazardous Materials Safety Administration (“PHMSA”) conducted an integrated inspection of the products pipeline with additional follow-up regarding integrity management planning and general operations and maintenance. Based on preliminary discussions with PHMSA following this inspection, the Wyoming refinery anticipates a civil penalty in excess of $100,000. In connection with our acquisition of, and commencement of operations at, the Wyoming refinery, findings of a past failure to comply with applicable environmental or pipeline safety laws and regulations may trigger a variety of administrative, civil, and criminal enforcement measures, including the assessment of monetary penalties that could be in excess of $100,000, the imposition of investigatory, remedial, or corrective actions, and the issuance of orders enjoining future operations or imposing additional compliance requirements on such operations.

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

16

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

major facility to reduce CO₂ 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 CO₂ 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.

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. Our Hawaii refinery is required to comply with Tier 3 gasoline standards within 30 months of June 21, 2016, the date our Hawaii refinery was disqualified from small volume refinery status. On March 19, 2015, the EPA confirmed the small volume refinery status of our Wyoming refinery.

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 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.

17

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

We estimate the cost of compliance with the Consent Decree to be approximately $30 million. However, Tesoro is responsible under the Environmental Agreement for 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 September 30, 2017, Tesoro has reimbursed us for $11.8 million of the total capital expenditures of $12.5 million incurred in connection with the Consent Decree. Net capital expenditures and reimbursements related to the Consent Decree for the nine months ended September 30, 2017 and 2016 are presented within Capital expenditures on our condensed consolidated statement of cash flows for the related periods.

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.

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 the Debtors hold against third parties.

As of September 30, 2017, two related claims totaling approximately $22.4 million remained to be resolved by the trustee for the General Trust and we have reserved 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 are settled at a ratio of 54.4 shares per $1,000 of claim.

18

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Note 12—Stockholders’ Equity

Incentive Plan

The following table summarizes our compensation costs recognized in General and administrative 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 September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Restricted Stock Awards	$	967	$	791	$	3,482	$	2,241
Restricted Stock Units	127		62		364		1,167
Stock Option Awards	583		756		1,957		1,695

During the three and nine months ended September 30, 2017, we granted 20 thousand and 273 thousand shares of restricted stock and restricted stock units with a fair value of approximately $0.4 million and $4.0 million, respectively. As of September 30, 2017, there were approximately $6.5 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 2.6 years.

During the nine months ended September 30, 2017, we granted 239 thousand stock option awards with a weighted-average exercise price of $15.03 per share and no grants were made for the three months endedSeptember 30, 2017. As of September 30, 2017, there were approximately $4.0 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 2.7 years.

During the nine months ended September 30, 2017, we granted 45 thousand performance restricted stock units to executive officers and no performance restricted stock units were granted for the three months endedSeptember 30, 2017. These performance restricted stock units had a fair value of approximately $0.7 million and are subject to certain annual performance targets as defined by our Board of Directors. As of September 30, 2017, there were approximately $0.5 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 2.4 years.

Note 13—Defined Benefit Plan

We maintain a defined benefit pension plan (the “Benefit Plan”) covering substantially all of our Wyoming Refining employees. Benefits are based on years of service and the employee’s highest average compensation received during five consecutive years of the last 10 years of employment. Our funding policy is to contribute annually an amount equal to the pension expense, subject to the minimum funding requirements of the Employee Retirement Income Security Act of 1974 and the tax deductibility of such contributions. As of September 30, 2017 and December 31, 2016, we had no amounts recorded in Accumulated other comprehensive income that are expected to be amortized into net periodic benefit cost in 2017. The Benefit Plan was assumed in connection with the WRC Acquisition on July 14, 2016.

The net periodic benefit cost (credit) related to our defined benefit plan includes the following components (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Components of net periodic benefit cost (credit):
Service cost	$	153		$	334		$	460		$	334
Interest cost	298			299			894			299
Expected return on plan assets	(297		)	(343		)	(892		)	(343		)
Net periodic benefit cost	$	154		$	290		$	462		$	290

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 each of the three and nine months ended September 30, 2017 and 352 thousand shares during each of

19

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

the three and nine months ended September 30, 2016, 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 September 30,					Nine Months Ended September 30,
	2017		2016			2017		2016
Net income (loss)	$	18,824	$	(27,761	)	$	53,616	$	(59,522	)
Less: Undistributed income allocated to participating securities (1)	238		—			685		—
Net income (loss) attributable to common stockholders	18,586		(27,761		)	52,931		(59,522		)
Plus: Net income effect of convertible securities	2,566		—			—		—
Numerator for diluted income (loss) per common share	$	21,152	$	(27,761	)	$	52,931	$	(59,522	)
Basic weighted-average common stock shares outstanding	45,561		41,580			45,505		41,309
Plus: dilutive effects of common stock equivalents (2)	6,431		—			22		—
Diluted weighted-average common stock shares outstanding	51,992		41,580			45,527		41,309
Basic income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)
Diluted income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)

________________________________________________________

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

(2) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per share for the three and nine months ended September 30, 2016.

For the three and nine months ended September 30, 2017, our calculation of dilutive shares outstanding excluded 31 thousand and 83 thousand shares of unvested restricted stock and 1.3 million and 1.5 million stock options, respectively. For the nine months ended September 30, 2017, our calculation of dilutive shares outstanding also excluded 6.4 million common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on January 1, 2017. For the three and nine months ended September 30, 2016, our calculation of diluted shares outstanding excluded 463 thousand and 448 thousand shares of unvested restricted stock, 1.7 million stock options, and 6.4 million and 2.3 million common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on the date of issuance, respectively.

As discussed in Note 8—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 and nine months ended September 30, 2017, diluted income (loss) per share was determined using the if-converted method.

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 September 30, 2017.

During the three and nine months ended September 30, 2017 and 2016, no adjustments were recognized for uncertain tax positions.

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 net operating loss (“NOL”) carryforwards will not always be available to offset taxable income apportioned

20

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

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.

We will 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.

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 third quarter of 2016, the results of operations of Wyoming Refining are included in our refining and logistics segments.

We have recast the segment information for the three and nine months ended September 30, 2016 to reflect the elimination of the Texadian segment as a reportable segment beginning in the first quarter of 2017. As of September 30, 2017, Texadian ceased its business operations other than the disposal of certain assets and liquidation of inventory. Our Corporate and Other reportable segment now includes administrative costs, our Texadian operations, and several small non-operated oil and gas interests that were owned by our predecessor.

Summarized financial information concerning reportable segments consists of the following (in thousands):

Three Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	578,511	$	31,838	$	83,682	$	(83,525	)	$	610,506
Cost of revenues (excluding depreciation)	513,664		15,857		63,175		(83,220		)	509,476
Operating expense (excluding depreciation)	36,126		4,029		11,563		—			51,718
Depreciation, depletion, and amortization	7,390		1,602		1,471		841			11,304
General and administrative expense (excluding depreciation)	—		—		—		11,292			11,292
Operating income (loss)	$	21,331	$	10,350	$	7,473	$	(12,438	)	$	26,716
Interest expense and financing costs, net										(7,419		)
Other income, net										649
Change in value of common stock warrants										(975		)
Equity earnings from Laramie Energy, LLC										553
Income before income taxes										19,524
Income tax expense										(700		)
Net income										$	18,824
Capital expenditures	$	3,171	$	2,606	$	811	$	1,523		$	8,111

21

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Three Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	462,975		$	28,107	$	75,577	$	(56,354	)	$	510,305
Cost of revenues (excluding depreciation)	439,477			19,334		56,365		(55,880		)	459,296
Operating expense (excluding depreciation)	35,910			4,686		10,461		183			51,240
Depreciation, depletion, and amortization	5,755			1,275		1,898		715			9,643
General and administrative expense (excluding depreciation)	—			—		—		9,863			9,863
Acquisition and integration expense	—			—		—		2,047			2,047
Operating income (loss)	$	(18,167	)	$	2,812	$	6,853	$	(13,282	)	$	(21,784	)
Interest expense and financing costs, net											(11,232		)
Other expense, net											(56		)
Change in value of common stock warrants											657
Change in value of contingent consideration											1,025
Equity earnings from Laramie Energy, LLC											3,659
Loss before income taxes											(27,731		)
Income tax expense											(30		)
Net loss											$	(27,761	)
Capital expenditures	$	3,820		$	266	$	1,636	$	1,863		$	7,585

________________________________________________________

(1) Includes eliminations of intersegment revenues and cost of revenues of $83.4 million and $72.1 million for the three months ended September 30, 2017 and 2016, respectively.

Nine Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,685,341	$	91,456	$	243,711	$	(240,504	)	$	1,780,004
Cost of revenues (excluding depreciation)	1,493,472		46,982		184,916		(240,252		)	1,485,118
Operating expense (excluding depreciation)	107,237		12,675		33,829		—			153,741
Depreciation, depletion, and amortization	22,243		4,613		4,377		2,615			33,848
General and administrative expense (excluding depreciation)	—		—		—		34,688			34,688
Acquisition and integration expense	—		—		—		253			253
Operating income (loss)	$	62,389	$	27,186	$	20,589	$	(37,808	)	$	72,356
Interest expense and financing costs, net										(25,500		)
Loss on termination of financing agreement										(1,804		)
Other income, net										886
Change in value of common stock warrants										(2,211		)
Equity earnings from Laramie Energy, LLC										11,651
Income before income taxes										55,378
Income tax expense										(1,762		)
Net income										$	53,616
Capital expenditures	$	5,495	$	5,345	$	4,434	$	4,614		$	19,888

22

PAR PACIFIC HOLDINGS, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

For the Interim Periods Ended September 30, 2017 and 2016

Nine Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,172,164		$	73,686	$	215,952	$	(159,893	)	$	1,301,909
Cost of revenues (excluding depreciation)	1,112,730			48,707		162,831		(157,921		)	1,166,347
Operating expense (excluding depreciation)	85,053			8,906		31,059		307			125,325
Depreciation, depletion, and amortization	9,649			3,116		4,930		2,144			19,839
General and administrative expense (excluding depreciation)	—			—		—		31,654			31,654
Acquisition and integration expense	—			—		—		3,563			3,563
Operating income (loss)	$	(35,268	)	$	12,957	$	17,132	$	(39,640	)	$	(44,819	)
Interest expense and financing costs, net											(21,951		)
Other income, net											60
Change in value of common stock warrants											3,477
Change in value of contingent consideration											10,753
Equity losses from Laramie Energy, LLC											(15,159		)
Loss before income taxes											(67,639		)
Income tax benefit											8,117
Net loss											$	(59,522	)
Capital expenditures	$	10,947		$	1,151	$	3,699	$	3,479		$	19,276

________________________________________________________ 

(1) Includes eliminations of intersegment revenues and cost of revenues of $241.5 million and $198.0 million for the nine months ended September 30,2017 and 2016, 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 and nine months ended September 30, 2017 or 2016.

Term Loan

On June 30, 2017, we fully repaid and terminated the Term Loan. An affiliate of Whitebox Advisors, LLC (“Whitebox”), which owns 10% or more of our common stock directly or through affiliates, had been a lender under the Term Loan.

23

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 owns, 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 ultra-low sulfur diesel, gasoline, jet fuel, marine fuel, LSFO, and other associated refined products primarily for consumption in Hawaii. Our refinery in Newcastle, Wyoming, produces gasoline, ultra-low sulfur diesel, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota.

2) Retail - Our retail outlets sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our retail network includes Hele and “76” branded retail sites, cardlock stations, company-operated convenience stores, sites operated in cooperation with 7-Eleven, and other sites operated by third parties.

3) Logistics - We own and operate terminals, pipelines, a 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 42.3% 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 third quarter of 2016, the results of operations of Wyoming Refining are included in our refining and logistics segments. Our Corporate and Other reportable segment includes administrative costs, our Texadian operations, 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 September 30, 2017 compared to the three months ended September 30, 2016

Net Income (Loss). Our financial performance for the third quarter 2017 was primarily impacted by improved crack spreads, which is reflected in a change in our net income (loss) from a net loss of $27.8 million for the three months ended September 30, 2016 to net income of $18.8 million for the three months ended September 30, 2017. Other factors impacting our results period over period include decreases in interest expense and financing costs, net, and acquisition and integration expense, partially offset by a decrease in Equity earnings from Laramie Energy.

Adjusted EBITDA and Adjusted Net Income (Loss). For the three months ended September 30, 2017, Adjusted EBITDA was $45.1 million compared to a loss of $1.6 million for the three months ended September 30, 2016. The change was primarily related to improved crack spreads.

For the three months ended September 30, 2017, Adjusted Net Income (Loss) was $26.2 million compared to a loss of $18.9 million for the three months ended September 30, 2016. The change was primarily related to improved crack spreads, and a decrease in interest expense and financing costs, net, partially offset by a decrease in Equity earnings from Laramie Energy.

Nine months endedSeptember 30, 2017 compared to the nine months ended September 30, 2016

Net Income (Loss). During 2017, our financial performance was primarily driven by improved crack spreads, which is reflected in the change in our net income (loss) from a net loss of $59.5 million for the nine months ended September 30, 2016 to net income of $53.6 million for the nine months ended September 30, 2017. Other factors impacting our results period over period include the contribution provided by Wyoming Refining during 2017 and an improvement in our Equity earnings (losses) from Laramie Energy, partially offset by the change in value of the contingent consideration obligation during 2016.

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Adjusted EBITDA and Adjusted Net Income (Loss). For the nine months ended September 30, 2017, Adjusted EBITDA was $107.0 million compared to a loss of $3.0 million for the nine months ended September 30, 2016. The change was primarily related to improved crack spreads and the contribution provided by Wyoming Refining during 2017.

For the nine months ended September 30, 2017, Adjusted Net Income (Loss) was$57.6 million compared to a loss of$60.4 million for the nine months ended September 30, 2016. The change was primarily related to improved crack spreads and the contribution provided by Wyoming Refining during 2017.

The following tables summarize our consolidated results of operations for the three and nine months ended September 30, 2017 compared to the three and nine months ended September 30, 2016 (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 September 30,
	2017			2016			$ Change			% Change
Revenues	$	610,506		$	510,305		$	100,201		20	%
Cost of revenues (excluding depreciation)	509,476			459,296			50,180			11	%
Operating expense (excluding depreciation)	51,718			51,240			478			1	%
Depreciation, depletion, and amortization	11,304			9,643			1,661			17	%
General and administrative expense (excluding depreciation)	11,292			9,863			1,429			14	%
Acquisition and integration expense	—			2,047			(2,047		)	(100	)%
Total operating expenses	583,790			532,089
Operating income (loss)	26,716			(21,784		)
Other income (expense)
Interest expense and financing costs, net	(7,419		)	(11,232		)	3,813			34	%
Other income (expense), net	649			(56		)	705			1,259	%
Change in value of common stock warrants	(975		)	657			(1,632		)	(248	)%
Change in value of contingent consideration	—			1,025			(1,025		)	(100	)%
Equity earnings from Laramie Energy, LLC	553			3,659			(3,106		)	(85	)%
Total other income (expense), net	(7,192		)	(5,947		)
Income (loss) before income taxes	19,524			(27,731		)
Income tax expense	(700		)	(30		)	(670		)	(2,233	)%
Net income (loss)	$	18,824		$	(27,761	)

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	Nine Months Ended September 30,
	2017			2016			$ Change			% Change
Revenues	$	1,780,004		$	1,301,909		$	478,095		37	%
Cost of revenues (excluding depreciation)	1,485,118			1,166,347			318,771			27	%
Operating expense (excluding depreciation)	153,741			125,325			28,416			23	%
Depreciation, depletion, and amortization	33,848			19,839			14,009			71	%
General and administrative expense (excluding depreciation)	34,688			31,654			3,034			10	%
Acquisition and integration expense	253			3,563			(3,310		)	(93	)%
Total operating expenses	1,707,648			1,346,728
Operating income (loss)	72,356			(44,819		)
Other income (expense)
Interest expense and financing costs, net	(25,500		)	(21,951		)	(3,549		)	(16	)%
Loss on termination of financing agreements	(1,804		)	—			(1,804		)	NM
Other income, net	886			60			826			1,377	%
Change in value of common stock warrants	(2,211		)	3,477			(5,688		)	(164	)%
Change in value of contingent consideration	—			10,753			(10,753		)	(100	)%
Equity earnings (losses) from Laramie Energy, LLC	11,651			(15,159		)	26,810			177	%
Total other income (expense), net	(16,978		)	(22,820		)
Income (loss) before income taxes	55,378			(67,639		)
Income tax benefit (expense)	(1,762		)	8,117			(9,879		)	(122	)%
Net income (loss)	$	53,616		$	(59,522	)

The following tables summarize our operating income (loss) by segment for the three and nine months ended September 30, 2017 and 2016 (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 September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	578,511	$	31,838	$	83,682	$	(83,525	)	$	610,506
Cost of revenues (excluding depreciation)	513,664		15,857		63,175		(83,220		)	509,476
Operating expense (excluding depreciation)	36,126		4,029		11,563		—			51,718
Depreciation, depletion, and amortization	7,390		1,602		1,471		841			11,304
General and administrative expense (excluding depreciation)	—		—		—		11,292			11,292
Operating income (loss)	$	21,331	$	10,350	$	7,473	$	(12,438	)	$	26,716

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Three months ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	462,975		$	28,107	$	75,577	$	(56,354	)	$	510,305
Cost of revenues (excluding depreciation)	439,477			19,334		56,365		(55,880		)	459,296
Operating expense (excluding depreciation)	35,910			4,686		10,461		183			51,240
Depreciation, depletion, and amortization	5,755			1,275		1,898		715			9,643
General and administrative expense (excluding depreciation)	—			—		—		9,863			9,863
Acquisition and integration expense	—			—		—		2,047			2,047
Operating income (loss)	$	(18,167	)	$	2,812	$	6,853	$	(13,282	)	$	(21,784	)

________________________________________________________

(1) Includes eliminations of intersegment Revenues and Cost of revenues (excluding depreciation) of $83.4 million and $72.1 million for the three months endedSeptember 30, 2017 and 2016, respectively.

Nine months ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,685,341	$	91,456	$	243,711	$	(240,504	)	$	1,780,004
Cost of revenues (excluding depreciation)	1,493,472		46,982		184,916		(240,252		)	1,485,118
Operating expense (excluding depreciation)	107,237		12,675		33,829		—			153,741
Depreciation, depletion, and amortization	22,243		4,613		4,377		2,615			33,848
General and administrative expense (excluding depreciation)	—		—		—		34,688			34,688
Acquisition and integration expense	—		—		—		253			253
Operating income (loss)	$	62,389	$	27,186	$	20,589	$	(37,808	)	$	72,356

Nine months ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,172,164		$	73,686	$	215,952	$	(159,893	)	$	1,301,909
Cost of revenues (excluding depreciation)	1,112,730			48,707		162,831		(157,921		)	1,166,347
Operating expense (excluding depreciation)	85,053			8,906		31,059		307			125,325
Depreciation, depletion, and amortization	9,649			3,116		4,930		2,144			19,839
General and administrative expense (excluding depreciation)	—			—		—		31,654			31,654
Acquisition and integration expense	—			—		—		3,563			3,563
Operating income (loss)	$	(35,268	)	$	12,957	$	17,132	$	(39,640	)	$	(44,819	)

________________________________________________________

(1) Includes eliminations of intersegment Revenues and Cost of revenues (excluding depreciation) of $241.5 million and $198.0 million for the nine months ended September 30, 2017 and 2016, respectively.

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Below is a summary of key operating statistics for the refining segment for the three and nine months ended September 30, 2017 and 2016:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Total Refining Segment
Feedstocks Throughput (Mbpd) (1)	90.3			70.5			90.1			84.8
Refined product sales volume (Mbpd) (1)	91.8			87.5			91.2			90.8
Hawaii Refinery
Feedstocks Throughput (Mbpd)	73.8			54.3			74.4			68.6
Source of Crude Oil:
North America	14.8		%	18.6		%	24.4		%	38.1		%
Latin America	—		%	—		%	0.1		%	2.9		%
Africa	29.1		%	14.8		%	23.1		%	13.2		%
Asia	23.6		%	32.4		%	24.3		%	32.5		%
Middle East	32.5		%	34.2		%	28.1		%	13.3		%
Total	100.0		%	100.0		%	100.0		%	100.0		%
Yield (% of total throughput)
Gasoline and gasoline blendstocks	28.8		%	25.2		%	27.9		%	26.4		%
Distillate	47.2		%	45.8		%	47.1		%	44.6		%
Fuel oils	15.6		%	17.4		%	16.1		%	19.2		%
Other products	5.1		%	7.3		%	5.7		%	6.1		%
Total yield	96.7		%	95.7		%	96.8		%	96.3		%
Refined product sales volume (Mbpd)
On-island sales volume	63.7			62.1			62.1			61.3
Exports sale volume	11.2			8.6			12.7			12.7
Total refined product sales volume	74.9			70.7			74.8			74.0
4-1-2-1 Singapore Crack Spread (2) ($ per barrel)	$	8.20		$	3.08		$	7.30		$	2.97
4-1-2-1 Mid Pacific Crack Spread (2) ($ per barrel)	9.94			4.45			8.67			4.29
Mid Pacific Crude Oil Differential(3) ($ per barrel)	(0.33		)	(2.42		)	(0.71		)	(2.19		)
Operating income (loss) per bbl ($/throughput bbl)	0.91			(2.71		)	2.05			(0.84		)
Adjusted Gross Margin per bbl ($/throughput bbl) (4)	6.32			3.32			6.39			3.49
Production costs per bbl ($/throughput bbl) (5)	3.69			5.42			3.66			3.96
DD&A per bbl ($/throughput bbl)	0.63			0.61			0.64			0.37

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	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Wyoming Refinery
Feedstocks Throughput (Mbpd) (1)	16.5			16.2			15.7			16.2
Yield (% of total throughput)
Gasoline and gasoline blendstocks	50.5		%	55.8		%	51.2		%	55.8		%
Distillate	43.4		%	39.4		%	43.1		%	39.4		%
Fuel oil	2.7		%	1.7		%	2.6		%	1.7		%
Other products	1.6		%	1.0		%	1.6		%	1.0		%
Total yield	98.2		%	97.9		%	98.5		%	97.9		%
Refined product sales volume (Mbpd) (1)	16.9			16.8			16.4			16.8
Wyoming 3-2-1 Index (6)	$	25.29		$	19.12		$	21.11		$	16.91
Operating income (loss) per bbl ($/throughput bbl)	9.97			4.55			4.82			4.55
Adjusted Gross Margin per bbl ($/throughput bbl) (4)	18.67			12.20			14.03			12.20
Production costs per bbl ($/throughput bbl) (5)	6.67			5.52			7.07			5.52
DD&A per bbl ($/throughput bbl)	2.03			2.13			2.13			2.13

________________________________________________________

(1) Feedstocks throughput and refined product sales volumes per day are calculated based on the 79 day period for which we owned Wyoming Refining in 2016. As such, the 2016 amounts for the total refining segment represent the sum of the Hawaii refinery's throughput or sales volumes averaged over the respective period plus the Wyoming refinery's throughput or sales volumes averaged over the period from July 14, 2016 to September 30, 2016. The 2017 amounts for the total refining segment represent the sum of the Hawaii and Wyoming refineries’ throughput or sales volumes averaged over the three and nine months endedSeptember 30, 2017, respectively.

(2) 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.

(3) 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.

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

(5) 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.

(6) 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.

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Below is a summary of key operating statistics for the retail and logistics segments for the three and nine months ended September 30, 2017 and 2016:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2017	2016	2017	2016
Retail Segment
Retail sales volumes (thousands of gallons)	24,064	23,567	69,868	68,851
Logistics Segment
Pipeline throughput (Mbpd) (1)
Crude oil pipelines	82.3	74.1	86.5	87.7
Refined product pipelines	85.0	87.0	86.7	86.5
Total pipeline throughput	167.3	161.1	173.2	174.2

________________________________________________________

(1) Pipeline throughput per day represents the sum of the pipeline throughput in Hawaii averaged over the respective period plus the pipeline throughput in Wyoming averaged over the 79 day period from July 14, 2016 to September 30, 2016. The 2017 amounts for the total logistics segment represent the sum of the pipeline throughput in Hawaii and Wyoming averaged over the three and nine months endedSeptember 30, 2017, respectively.

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) plus 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.

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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 September 30, 2017	Refining			Logistics		Retail
Operating income	$	21,331		$	10,350	$	7,473
Operating expense (excluding depreciation)	36,126			4,029		11,563
Depreciation, depletion, and amortization	7,390			1,602		1,471
Inventory valuation adjustment	9,423			—		—
Unrealized gain on derivatives	(3,033		)	—		—
Adjusted Gross Margin	$	71,237		$	15,981	$	20,507

Three months ended September 30, 2016	Refining			Logistics		Retail
Operating income (loss)	$	(18,167	)	$	2,812	$	6,853
Operating expense (excluding depreciation)	35,910			4,686		10,461
Depreciation, depletion, and amortization	5,755			1,275		1,898
Inventory valuation adjustment	7,780			—		—
Unrealized loss on derivatives	895			—		—
Adjusted Gross Margin	$	32,173		$	8,773	$	19,212

Nine months ended September 30, 2017	Refining			Logistics		Retail
Operating income	$	62,389		$	27,186	$	20,589
Operating expense (excluding depreciation)	107,237			12,675		33,829
Depreciation, depletion, and amortization	22,243			4,613		4,377
Inventory valuation adjustment	(1,989		)	—		—
Unrealized loss on derivatives	79			—		—
Adjusted Gross Margin	$	189,959		$	44,474	$	58,795

Nine months ended September 30, 2016	Refining			Logistics		Retail
Operating income (loss)	$	(35,268	)	$	12,957	$	17,132
Operating expense (excluding depreciation)	85,053			8,906		31,059
Depreciation, depletion, and amortization	9,649			3,116		4,930
Inventory valuation adjustment	28,540			—		—
Unrealized gain on derivatives	(7,039		)	—		—
Adjusted Gross Margin	$	80,935		$	24,979	$	53,121

Adjusted Net Income (Loss) and Adjusted EBITDA

Adjusted Net Income (Loss) is defined as Net income (loss) 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, and inventory valuation adjustment. Beginning with the first quarter of 2017, Adjusted Net Income (Loss) also excludes severance costs. We have recast the non-GAAP information for the three and nine months endedSeptember 30, 2016 to conform with the current period presentation.

Adjusted EBITDA is Adjusted Net Income (Loss) excluding interest expense and financing costs, taxes, DD&A, and equity losses (earnings) from Laramie Energy. 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.

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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.

The following table presents a reconciliation of Adjusted Net Income (Loss) and 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 September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Net income (loss)	$	18,824		$	(27,761	)	$	53,616		$	(59,522	)
Inventory valuation adjustment	9,423			7,324			(1,989		)	24,585
Unrealized loss (gain) on derivatives	(3,033		)	1,117			79			(6,297		)
Acquisition and integration expense	—			2,047			253			3,563
Loss on termination of financing agreement	—			—			1,804			—
Release of tax valuation allowance	—			—			—			(8,573		)
Change in value of common stock warrants	975			(657		)	2,211			(3,477		)
Change in value of contingent consideration	—			(1,025		)	—			(10,753		)
Severance costs	—			105			1,595			105
Adjusted Net Income (Loss)	26,189			(18,850		)	57,569			(60,369		)
Depreciation, depletion, and amortization	11,304			9,643			33,848			19,839
Interest expense and financing costs, net	7,419			11,232			25,500			21,951
Equity losses (earnings) from Laramie Energy, LLC	(553		)	(3,659		)	(11,651		)	15,159
Income tax expense	700			30			1,762			456
Adjusted EBITDA	$	45,059		$	(1,604	)	$	107,028		$	(2,964	)

Factors Impacting Segment Results

Three months ended September 30, 2017 compared to the three months ended September 30, 2016

Refining. Operating income for our refining segment was $21.3 million for the three months ended September 30, 2017, an increase of $39.5 million compared to operating loss of $18.2 million for the three months ended September 30, 2016. The increase in profitability was primarily driven by higher crack spreads and the acquisition of Wyoming Refining. The 4-1-2-1 Mid Pacific crack spread increased from $4.45 per barrel in the third quarter of 2016 to $9.94 per barrel in the third quarter of 2017. The increase in crack spreads was partially offset by the change in crude oil differentials. The Mid Pacific crude oil differential decreased from $2.42 per barrel in the third quarter of 2016 to $0.33 per barrel in the third quarter of 2017. Wyoming Refining contributed approximately $15.1 million of operating income to the refining segment for the three months ended September 30, 2017. The Wyoming 3-2-1 Index increased from $19.12 per barrel in the third quarter of 2016 to $25.29 per barrel in the third quarter of 2017.

Logistics. Operating income for our logistics segment was $10.4 million for the three months ended September 30, 2017, an increase of $7.6 million compared to operating income of $2.8 million for the three months ended September 30, 2016. Profitability of the logistics business increased primarily due higher throughput and on-island sales volumes in Hawaii, and the acquisition of Wyoming Refining, which contributed approximately $2.3 million of operating income to the logistics segment for the three months ended September 30, 2017.

Retail. Operating income for our retail segment was $7.5 million for the three months ended September 30, 2017, an increase of $0.6 million compared to operating income of $6.9 million for the three months ended September 30, 2016. The increase in operating income was primarily due to an increase in sales prices of 10% and an increase in sales volumes of 2%, partially offset by a 10%increase in fuel costs and higher operating expenses.

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Factors Impacting Segment Results

Nine months endedSeptember 30, 2017 compared to the nine months ended September 30, 2016

Refining. Operating income for our refining segment was $62.4 million for the nine months ended September 30, 2017, an increase of $97.7 million compared to an operating loss of $35.3 million for the nine months ended September 30, 2016. The increase in profitability was primarily driven by higher crack spreads and the acquisition of Wyoming Refining. The 4-1-2-1 Mid Pacific crack spread increased102% from $4.29 per barrel for the nine months ended September 30, 2016 to $8.67 per barrel for the nine months ended September 30, 2017. The increase in crack spreads was partially offset by decreased crude oil differentials. The Mid Pacific crude oil differential decreased68% from $2.19 per barrel for the nine months ended September 30, 2016 to $0.71 per barrel for the nine months ended September 30, 2017. Wyoming Refining contributed operating income of approximately $20.7 million to the refining segment for the nine months ended September 30, 2017.

Logistics. Operating income for our logistics segment was $27.2 million for the nine months ended September 30, 2017, an increase of $14.2 million compared to operating income of $13.0 million for the nine months ended September 30, 2016. The increase in profitability is primarily due to the acquisition of Wyoming Refining and higher transportation and logistics services revenue. Wyoming Refining contributed approximately $5.4 million of operating income to the logistics segment for the nine months ended September 30, 2017 as compared to approximately $0.7 million for the nine months ended September 30, 2016.

Retail. Operating income for our retail segment was $20.6 million for the nine months ended September 30, 2017, an increase of $3.5 million compared to operating income of $17.1 million for the nine months ended September 30, 2016. The increase was driven by a 13%increase in sales prices. This increase in sales prices was partially offset by a 12%increase in fuel costs and higher operating expenses.

Adjusted Gross Margin

Three months ended September 30, 2017 compared to the three months ended September 30, 2016

Refining. For the three months ended September 30, 2017, our refining Adjusted Gross Margin was approximately $71.2 million, an increase of $39.0 million compared to $32.2 million for the three months ended September 30, 2016. The increase was primarily due to higher crack spreads and refined volumes. The 4-1-2-1 Mid Pacific crack spread increased123% from $4.45 per barrel during the three months ended September 30, 2016 to $9.94 per barrel during the three months ended September 30, 2017. The Wyoming 3-2-1 Index increased from $19.12 per barrel in the third quarter of 2016 to $25.29 per barrel in the third quarter of 2017. The increase in crack spreads resulted in an increase of approximately $29.6 million in Adjusted Gross Margin for the refining segment. The remaining increase was due to an increase of 6% in sales volumes at the Hawaii refinery during the three months ended September 30, 2017 compared to the same period in 2016, which was related to our Hawaii refinery turnaround completed during the third quarter of 2016.

Logistics.For the three months ended September 30, 2017, our logistics Adjusted Gross Margin was approximately $16.0 million, an increase of $7.2 million compared to $8.8 million for the three months ended September 30, 2016. The increase was primarily driven by the WRC Acquisition and deregulation of pipelines owned by Wyoming Refining, which contributed approximately $5.2 million of Adjusted Gross Margin to the logistics segment for the three months ended September 30, 2017, as well as higher throughput and on-island sales volumes in Hawaii.

Retail. For the three months ended September 30, 2017, our retail Adjusted Gross Margin was approximately $20.5 million, an increase of $1.3 million when compared to $19.2 million for the three months ended September 30, 2016. The increase was primarily due to an increase in sales prices of 10% and an increase in sales volumes of 2%, partially offset by a 10%increase in fuel costs.

Nine months endedSeptember 30, 2017 compared to the nine months ended September 30, 2016

Refining.For the nine months ended September 30, 2017, our refining Adjusted Gross Margin was approximately $190.0 million, an increase of $109.1 million compared to $80.9 million for the nine months ended September 30, 2016. The increase was primarily due to higher crack spreads and the acquisition of Wyoming Refining. The 4-1-2-1 Mid Pacific crack spread increased102% from $4.29 per barrel for the nine months ended September 30, 2016 to $8.67 per barrel for the nine months ended September 30, 2017. The increase in crack spreads was partially offset by the change in crude oil differentials. The Mid Pacific crude oil differential decreased68% from $2.19 per barrel for the nine months ended September 30, 2016 to $0.71 per barrel for the nine months ended September 30, 2017. Wyoming Refining contributed approximately $60.1 million and $15.6 million of Adjusted Gross Margin to the refining segment for the nine months ended September 30, 2017 and September 30, 2016, respectively.

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Logistics.For the nine months ended September 30, 2017, our logistics Adjusted Gross Margin was approximately $44.5 million, an increase of $19.5 million compared to $25.0 million for the nine months ended September 30, 2016. The increase was primarily driven by the acquisition of Wyoming Refining and higher transportation and logistics services revenue. Wyoming Refining contributed approximately $15.3 million and $2.2 million of Adjusted Gross Margin to the logistics segment for the nine months ended September 30, 2017 and September 30, 2016, respectively.

Retail.For the nine months ended September 30, 2017, our retail Adjusted Gross Margin was approximately $58.8 million, an increase of $5.7 million when compared to approximately $53.1 million for the nine months ended September 30, 2016. The increase was primarily due to an increase in sales prices of 13%, partially offset by a 12%increase in fuel costs.

Discussion of Consolidated Results

Three months ended September 30, 2017 compared to the three months ended September 30, 2016

Revenues. For the three months ended September 30, 2017, revenues were $610.5 million, a $100.2 millionincrease compared to $510.3 million for the three months ended September 30, 2016. The increase was primarily due to an increase of $107.2 million in third party refining segment revenue, which was primarily the result of higher crude oil prices and the WRC Acquisition. Brent crude oil prices averaged $52.14 per barrel during the third quarter of 2017 compared to $47.01 per barrel during the third quarter of 2016. Wyoming Refining contributed revenues of $111.4 million and $80.9 million to the refining segment for the three months endedSeptember 30, 2017 and 2016, respectively. Revenues in our retail segment increased $8.1 million primarily driven by an increase of 10% in sales prices.

Cost of Revenues (Excluding Depreciation). For the three months ended September 30, 2017, cost of revenues (excluding depreciation), was $509.5 million, a $50.2 millionincrease compared to $459.3 million for the three months ended September 30, 2016. The increase was primarily driven by the WRC Acquisition and higher crude prices. Brent crude oil prices averaged $52.14 per barrel during the third quarter of 2017 compared to $47.01 per barrel during the third quarter of 2016. Wyoming Refining contributed cost of revenues (excluding depreciation) of $83.1 million and $66.7 million to the refining segment for the three months endedSeptember 30, 2017 and 2016, respectively. Cost of revenues (excluding depreciation) in our retail segment increased $6.8 million primarily driven by an increase of 10% in fuel costs.

Operating Expense (Excluding Depreciation).For the three months ended September 30, 2017, operating expense (excluding depreciation) was approximately $51.7 million, an increase of $0.5 million when compared to $51.2 million for the three months ended September 30, 2016.

Depreciation, Depletion, and Amortization.For the three months ended September 30, 2017, DD&A was approximately $11.3 million, an increase of $1.7 million compared to $9.6 million for the three months ended September 30, 2016. The increase was primarily due to a $1.6 million increase in amortization of deferred turnaround expenditures during the three months ended September 30, 2017 compared to the same period in 2016. These deferred turnaround expenditures are related to our Hawaii refinery turnaround completed during the third quarter of 2016.

General and Administrative Expense (Excluding Depreciation).For the three months ended September 30, 2017, general and administrative expense (excluding depreciation) was approximately $11.3 million, an increase of $1.4 million when compared to $9.9 million for the three months ended September 30, 2016. The increase was primarily due to higher payroll and employee benefit costs driven by increased headcount.

Acquisition and Integration Expense.For the three months ended September 30, 2016, acquisition and integration expense was approximately $2.0 million. The acquisition and integration expense was incurred in connection with the WRC Acquisition completed in July 2016. No such expense was incurred during the three months ended September 30, 2017.

Interest Expense and Financing Costs, Net. For the three months ended September 30, 2017, our interest expense and financing costs were approximately $7.4 million, a decrease of $3.8 million when compared to $11.2 million for the three months ended September 30, 2016. The decrease was primarily due to lower interest expense and financing costs of approximately $3.0 million due to the issuance and full repayment and termination of the Bridge Notes in the third quarter of 2016 and lower interest expense of $2.6 million due to the full repayment and termination of the Term Loan during the second quarter of 2017. These decreases were partially offset by lower unrealized gains on interest rate swaps of $1.4 million during the three months ended September 30, 2017 compared to the same period in 2016.

Change in Value of Common Stock Warrants. For the three months ended September 30, 2017, the change in value of common stock warrants resulted in a loss of approximately $1.0 million, a decrease of $1.7 million when compared to income of approximately $0.7 million for the three months ended September 30, 2016. For the three months ended September 30, 2017, our

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stock price increased from $18.04 per share as of June 30, 2017 to $20.80 per share as of September 30, 2017, which resulted in an increase in the fair value of the common stock warrants. During the three months ended September 30, 2016, our stock price decreased from $15.34 per share as of June 30, 2016 to $13.08 per share as of September 30, 2016, which resulted in a decrease in the fair value of the common stock warrants.

Change in Value of Contingent Consideration. For the three months ended September 30, 2017, there was no change in value of our contingent consideration liability. For the three months ended September 30, 2016, the change in value of our contingent consideration liability resulted in income of $1.0 million due to a decrease in our expected cash flows related to PHR for 2016 as a result of lower crack spreads. At December 31, 2016, the earn-out measurement period related to the contingent consideration for the acquisition of PHR was complete. Please read Note 11—Commitments and Contingencies for more information related to the earn-out.

Equity Earnings (Losses) From Laramie Energy. For the three months ended September 30, 2017, equity earnings from Laramie Energy were approximately $0.6 million, a decrease in equity earnings of $3.1 million compared to equity earnings of $3.7 million for the three months ended September 30, 2016. The decrease in equity earnings was primarily due to a decrease in Laramie Energy’s gain from derivative instruments of $10.8 million for three months ended September 30, 2017 compared to the same period in 2016.

Income Taxes. For the three months ended September 30, 2017, we recorded an income tax expense of $700 thousand related primarily to alternative minimum tax. For the three months ended September 30, 2016, we recorded income tax expense of $30 thousand.

Nine months endedSeptember 30, 2017 compared to the nine months ended September 30, 2016

Revenues. For the nine months ended September 30, 2017, revenues were $1.8 billion, a $0.5 billionincrease compared to $1.3 billion for the nine months ended September 30, 2016. The increase was primarily due to an increase of $0.5 billion in third-party revenues at our refining segment primarily the result of higher crude oil prices and the WRC Acquisition. Average Brent prices increased from $43.06 per barrel in the nine months ended September 30, 2016 to $52.56 per barrel in the nine months ended September 30, 2017. Wyoming Refining contributed revenues of $304.6 million and $80.9 million to the refining segment for the nine months ended September 30, 2017 and 2016, respectively.

Cost of Revenues (Excluding Depreciation). For the nine months ended September 30, 2017, cost of revenues (excluding depreciation), was $1.5 billion, a $0.3 billionincrease compared to $1.2 billion for the nine months ended September 30, 2016. The increase was primarily due to the WRC Acquisition and higher crude prices. Average Brent pricing increased 22% from $43.06 per barrel in the nine months ended September 30, 2016 to $52.56 per barrel in the nine months ended September 30, 2017. Wyoming Refining contributed cost of revenues (excluding depreciation) of $244.4 million and $66.7 million to the refining segment for the nine months ended September 30, 2017 and 2016, respectively.

Operating Expense (Excluding Depreciation).For the nine months ended September 30, 2017, operating expense (excluding depreciation) was approximately $153.7 million, an increase of $28.4 million compared to $125.3 million for the nine months ended September 30, 2016. The increase was primarily due to the WRC Acquisition, which contributed $37.7 million and $9.1 million to the increase in operating expense (excluding depreciation) for the nine months ended September 30, 2017 and 2016, respectively.

Depreciation, Depletion, and Amortization.For the nine months ended September 30, 2017, DD&A was approximately $33.8 million, an increase of $14.0 million when compared to $19.8 million for the nine months ended September 30, 2016. The increase was primarily due to DD&A related to assets acquired as part of the WRC Acquisition on July 14, 2016. Wyoming Refining contributed $11.4 million and $3.1 million of DD&A for the nine months ended September 30, 2017 and 2016, respectively. Additionally, amortization of deferred turnaround expenditures increased $6.9 million during the nine months ended September 30, 2017 compared to the same period in 2016.

General and Administrative Expense (Excluding Depreciation).For the nine months ended September 30, 2017, general and administrative expense (excluding depreciation) was approximately $34.7 million, an increase of $3.0 million when compared to $31.7 million for the nine months ended September 30, 2016. The increase was primarily due to higher payroll and employee benefit costs driven by increased headcount and severance costs incurred during the first quarter of 2017.

Acquisition and Integration Expense.For the nine months ended September 30, 2017, we incurred approximately $0.3 million of integration costs related to the WRC Acquisition. For the nine months ended September 30, 2016, we incurred approximately $3.6 million of acquisition and integration costs related to the WRC Acquisition completed in July 2016.

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Interest Expense and Financing Costs, Net. For the nine months ended September 30, 2017, our interest expense and financing costs were approximately $25.5 million, an increase of $3.5 million when compared to $22.0 million for the nine months ended September 30, 2016. The increase was primarily due to higher interest expense of $5.4 million related to the Wyoming Refining Credit Facilities and the Par Wyoming Holdings Term Loan, entered into during the third quarter of 2016 in conjunction with the WRC Acquisition, higher interest expense of $4.9 million related to our 5.00% Convertible Senior Notes, and interest expense of $0.7 million on the J. Aron Forward Agreement entered into during the second quarter of 2017. These increases were partially offset by lower interest expense of $3.4 million due to the full repayment and termination of the Term Loan during the the second quarter of 2017 and lower interest expense and financing costs of approximately $3.0 million due to the full repayment and termination of the Bridge Notes in the third quarter of 2016.

Change in Value of Common Stock Warrants. For the nine months ended September 30, 2017, the change in value of common stock warrants resulted in a loss of approximately $2.2 million, a change of $5.7 million when compared to a gain of $3.5 million for the nine months ended September 30, 2016. For the nine months ended September 30, 2017, our stock price increased from $14.54 per share as of December 31, 2016 to $20.80 per share as of September 30, 2017, which resulted in an increase in the fair value of the common stock warrants. During the nine months ended September 30, 2016, our stock price decreased from $23.54 per share on December 31, 2015 to $13.08 per share on September 30, 2016, which resulted in a decrease in the value of the common stock warrants.

Change in Value of Contingent Consideration. For the nine months ended September 30, 2017, there was no change in the fair value of our contingent consideration liability. For the nine months ended September 30, 2016, the change in value of our contingent consideration liability resulted in a gain of $10.8 million due to a decrease in our expected cash flows related to PHR for 2016 as a result of lower crack spreads. As of December 31, 2016, the earn-out measurement period related to the contingent consideration for the acquisition of PHR was complete. Please read Note 11—Commitments and Contingencies for more information.

Loss on Termination of Financing Agreements. For the nine months ended September 30, 2017, our loss on termination of financing agreements was approximately $1.8 million and represents the acceleration of deferred amortization costs in connection with the termination of the Term Loan during the second quarter of 2017. No such loss was incurred in the 2016 period.

Equity Earnings (Losses) From Laramie Energy. For the nine months ended September 30, 2017, equity earnings from Laramie Energy were approximately $11.7 million, a change of $26.9 million compared to equity losses of $15.2 million for the nine months ended September 30, 2016. The change was primarily due to an increase in natural gas prices and an increase in gains on derivative instruments of $34.0 million during the nine months ended September 30, 2017 compared to the same period in 2016.

Income Taxes. For the nine months ended September 30, 2017, we recorded income tax expense of $1.8 million primarily due to alternative minimum tax expense for the period. For the nine months ended September 30, 2016, we recorded income tax benefit of $8.1 million primarily due to the release of $8.6 million of our valuation allowance as we expect to be able to utilize a portion of our NOL carryforwards to offset future taxable income associated with the reversal of the deferred tax liability recognized upon issuance of the 5.00% Convertible Senior Notes.

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.

The following table summarizes our liquidity position as of September 30, 2017 (in thousands):

September 30, 2017	Par Hawaii Refining		Wyoming Refining		Hawaii Retail (2)		Corporate and Other		Total
Cash and cash equivalents	$	37,509	$	—	$	14,674	$	26,117	$	78,300
Revolver availability	—		—		$	5,000	—		5,000
Wyoming Refining availability	—		20,360		—		—		20,360
Deferred Payment Arrangement availability (1)	33,633		—		—		—		33,633
Total available liquidity	$	71,142	$	20,360	$	19,674	$	26,117	$	137,293

________________________________________________________

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(1) Please read Note 7—Inventory Financing Agreements to our condensed consolidated financial statements for further discussion.

(2) Includes HIE Retail, LLC and Mid Pac, which are parties to the Hawaii Retail Credit Facilities.

Our liquidity position as of November 6, 2017 was $124.4 million. The change in our liquidity position from September 30, 2017 to November 6, 2017 was primarily attributable to changes in working capital.

As of September 30, 2017, we had access to the J. Aron Deferred Payment Arrangement, the Hawaii Retail Credit Facilities, a revolving credit facility under the Wyoming Refining Credit Facilities, and cash on hand of $78.3 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 segment and our retail segment, payments related to acquisitions, 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 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 nine months ended September 30, 2017 and 2016 (in thousands):

	Nine Months Ended September 30,
	2017			2016
Net cash provided by (used in) operating activities	$	105,456		$	(41,248	)
Net cash used in investing activities	(19,367		)	(291,136		)
Net cash provided by (used in) financing activities	(55,561		)	220,850

Net cash provided by operating activities was approximately $105.5 million for the nine months ended September 30, 2017, which resulted from net income of approximately $53.6 million, non-cash charges to operations of approximately $39.2 million and net cash provided by changes in operating assets and liabilities of approximately $12.6 million. The change in our operating assets and liabilities for the nine months ended September 30, 2017 is primarily due to an increase in crude oil and refined products inventory at our Hawaii refinery driven by higher volumes and prices, partially offset by a decrease in our obligations under inventory financing agreements. Net cash used in operating activities was approximately $41.2 million for the nine months ended September 30, 2016, which resulted from a net loss of approximately $59.5 million, non-cash charges to operations of approximately $22.9 million, and net cash used for changes in operating assets and liabilities of approximately $4.7 million, including deferred turnaround expenditures of $35.0 million.

For the nine months ended September 30, 2017, net cash used in investing activities was approximately $19.4 millionand primarily related to additions to property and equipment. Net cash used in investing activities was approximately $291.1 million for the nine months ended September 30, 2016 and primarily related to $209.2 million for the WRC Acquisition, an investment in Laramie Energy of $55.0 million in connection with its acquisition of additional natural gas and oil properties, and additions to property and equipment of approximately $19.3 million.

Net cash used in financing activities for the nine months ended September 30, 2017 was approximately $55.6 millionwhich consisted primarily of net debt repayments of approximately $53.2 million and net repayments of the J. Aron deferred payment arrangement of $1.5 million. Net cash provided by financing activities for the nine months ended September 30, 2016 was approximately $220.9 million and consisted primarily of net proceeds from borrowings of approximately $157.2 million, net proceeds from our rights offering of $49.3 million, and net proceeds from the J. Aron deferred payment arrangement of $26.7 million. These outflows were partially offset by a $16.8 million payment related to contingent consideration for the PHR acquisition, $12.0 million of which was classified as a financing activity.

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Capital Expenditures

Our capital expenditures for the nine months ended September 30, 2017 totaled approximately $19.9 million and were primarily related to our retail segment, our Wyoming refining and logistics operations, and information technology systems. Our capital expenditure budget for 2017, including major maintenance costs, ranges from $38 million to $42 million and primarily relates to profit improvement projects related to our retail segment, expansion projects at our Wyoming refinery, and upgrades to our information technology systems.

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. The Supply and Offtake Agreements had a term of three years with two one-year extension options upon mutual agreement of the parties. On May 8, 2017, the Supply and Offtake Agreements were amended to, among other things, extend the term through May 31, 2021, and provide for a $30 million forward sale to J. Aron of jet fuel to be delivered over the extended term of the Supply and Offtake Agreements. Please read Note 7—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.

We estimate the cost of compliance with the Consent Decree to be approximately $30 million. However, Tesoro is responsible under the Environmental Agreement for 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 11—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 11—Commitments and Contingencies for more information.

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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 penaltiesand 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 Tesoro earn-out dispute and the Mid Pac earn-out and indemnity dispute; estimated costs to settle claims remaining in the General Trust; 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 nine months endedSeptember 30, 2017 of 90 thousand barrels per day, would change annualized operating income by approximately $32.4 million. This estimate 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.

39

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 7—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 31, 2017. At September 30, 2017, these open commodity derivative contracts represented futures purchases of 305 thousand barrels and OTC swaps of 115 thousand barrels that economically hedge our sales of refined products.

Based on our net open positions at September 30, 2017, a $1 change in the price of crude oil, assuming all other factors remain constant, would result in a change of approximately $190 thousand 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 74 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 executing option collars and swaps at a rate of 52 thousand barrels per month through December 2017 and 75 thousand barrels per month through December 2018. These option collars have a weighted-average strike price ranging from a floor of $40.72 per barrel to a ceiling of $67.26 per barrel. The OTC swaps have a weighted-average price of $46.45. 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 qualified RINs required to comply with the Renewable Fuel Standard, which grants the EPA authority to establish our overall RINs obligation for each compliance year. We purchase biofuels from third parties and blend those biofuels into our products. For the majority of gallons of biofuel purchased, we receive the associated RINs. 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 September 30, 2017, $210.6 million of outstanding debt was subject to floating interest rates. We have 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 $2.4 million and $2.4 million per year, respectively.

We utilize interest rate swaps to manage our interest rate risk. As of September 30, 2017, we had locked in an average fixed rate of 1.1% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $200 million. The interest rate swaps mature in February 2019 and March 2021.

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.

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 September 30, 2017, 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 September 30, 2017, 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.

40

Changes in Internal Control over Financial Reporting

There were no changes during the quarter ended September 30, 2017 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 11—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, 2016. Except as set forth below, there have been no material changes to the risk factors disclosed in our Annual Report on Form 10-K.

Changes in tax laws and other policies could have a material adverse effect on our results of operations and financial condition.

The new presidential administration has called for substantial changes to tax, trade, and other policies, which may include comprehensive tax reform or a border adjustment tax. We cannot predict the impact, if any, of these changes on our business. However, any significant changes to tax, trade, or other policies could have a material adverse effect on our results of operations and financial condition.

Tesoro has disputed our calculation of the 2015 and 2016 earn-out amounts with respect to our acquisition of Par Hawaii Refining, LLC and it is possible that we may be required to pay Tesoro additional amounts for such periods.

The contingent earn-out payments with respect to our acquisition of PHR from Tesoro are calculated annually for each of the years ended 2014, 2015 and 2016 with an annual limit of $20 million and an overall limit of $40 million. During 2016, we paid Tesoro a total of $16.8 million to settle the 2014 and 2015 earn-out payments. Tesoro has disputed our calculation of the 2015 and 2016 earn-out amounts and has asserted that it is 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. If we and Tesoro are unable to agree on the calculation of the 2015 and 2016 earn-out amounts, the dispute will be resolved in accordance with the dispute resolution provisions set forth in the membership interest purchase agreement to determine the amounts owed, if any. It is possible that we may be required to pay Tesoro additional amounts for the disputed earn-out periods, subject to the annual and overall limits.

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. Our current debt agreements restrict the payment of dividends.

Stock Repurchases    

The following table sets forth certain information with respect to repurchases of our common stock during the quarter ended September 30, 2017:

41

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
July 1 - July 31, 2017	4,915	$	18.15	—	—
August 1 - August 31, 2017	1,153	17.11		—	—
September 1 - September 30, 2017	15,062	20.24		—	—
Total	21,130	$	19.58	—	—

________________________________________________

(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.

42

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.

43

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	Par Pacific Holdings, Inc. Amended and Restated 2012 Long Term Incentive Plan. Incorporated by reference to Appendix A to the Company’s Proxy Statement on Schedule 14A filed on April 21, 2016.+
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.**
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.

44

**    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.

+    Management contract or compensatory plan or arrangement.

45

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: November 8, 2017

46

EX-31.1

Exhibit 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER PURSUANT TO RULE 13a-14(a)/15d-14(a) PROMULGATED UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, William Pate, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Par Pacific Holdings, Inc.;

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

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

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

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

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

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

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

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

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

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

Date: November 8, 2017

/s/ William Pate

William Pate

President and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER PURSUANT TO RULE 13a-14(a)/15d-14(a) PROMULGATED UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, William Monteleone, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Par Pacific Holdings, Inc.;

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

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

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

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

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

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

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

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

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

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

Date: November 8, 2017

/s/ William Monteleone

William Monteleone

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Par Pacific Holdings, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2017 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William Pate, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

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

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

/s/ William Pate

William Pate

President and Chief Executive Officer

November 8, 2017

EX-32.2

Exhibit 32.2

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Par Pacific Holdings, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2017 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William Monteleone, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

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

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

/s/ William Monteleone

William Monteleone

Chief Financial Officer

November 8, 2017

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Nov. 06, 2017
Document and Entity Information:
Entity Registrant Name	PAR PACIFIC HOLDINGS, INC.
Document Type	10-Q
Document Period End Date	Sep. 30, 2017
Amendment Flag	false
Entity Central Index Key	0000821483
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding (in shares)		45,790,387
Entity Filer Category	Accelerated Filer
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 78,300	$ 47,772
Restricted cash	744	1,246
Trade accounts receivable	89,665	102,384
Inventories	319,864	198,326
Prepaid and other current assets	8,939	53,380
Total current assets	497,512	403,108
Property and equipment
Property, plant, and equipment	520,464	499,867
Proved oil and gas properties, at cost, successful efforts method of accounting	1,122	1,122
Total property and equipment	521,586	500,989
Less accumulated depreciation and depletion	(72,965)	(49,727)
Property and equipment, net	448,621	451,262
Long-term assets
Investment in Laramie Energy, LLC	120,474	108,823
Intangible assets, net	27,431	29,912
Goodwill	107,187	105,732
Other long-term assets	33,957	46,596
Total assets	1,235,182	1,145,433
Current liabilities
Current maturities of long-term debt	27,140	20,286
Obligations under inventory financing agreements	310,176	225,135
Accounts payable	51,442	65,190
Advances from customers	26,928	23,774
Accrued taxes	14,504	13,194
Other accrued liabilities	28,083	35,186
Total current liabilities	458,273	382,765
Long-term liabilities
Long-term debt, net of current maturities	303,061	350,110
Common stock warrants	7,345	5,134
Long-term capital lease obligations	1,171	1,780
Other liabilities	37,848	36,735
Total liabilities	807,698	776,524
Commitments and contingencies (Note 11)
Stockholders’ equity
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued	0	0
Common stock, $0.01 par value; 500,000,000 shares authorized at September 30, 2017 and December 31, 2016, 45,778,788 shares and 45,533,913 shares issued at September 30, 2017 and December 31, 2016, respectively	458	455
Additional paid-in capital	592,013	587,057
Accumulated deficit	(167,183)	(220,799)
Accumulated other comprehensive income	2,196	2,196
Total stockholders’ equity	427,484	368,909
Total liabilities and stockholders’ equity	$ 1,235,182	$ 1,145,433

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	3,000,000	3,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	45,778,788	45,533,913

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Statement [Abstract]
Revenues	$ 610,506	$ 510,305	$ 1,780,004	$ 1,301,909
Operating expenses
Cost of revenues (excluding depreciation)	509,476	459,296	1,485,118	1,166,347
Operating expense (excluding depreciation)	51,718	51,240	153,741	125,325
Depreciation, depletion, and amortization	11,304	9,643	33,848	19,839
General and administrative expense (excluding depreciation)	11,292	9,863	34,688	31,654
Acquisition and integration expense	0	2,047	253	3,563
Total operating expenses	583,790	532,089	1,707,648	1,346,728
Operating income (loss)	26,716	(21,784)	72,356	(44,819)
Other income (expense)
Interest expense and financing costs, net	(7,419)	(11,232)	(25,500)	(21,951)
Loss on termination of financing agreements	0	0	(1,804)	0
Other income (expense), net	649	(56)	886	60
Change in value of common stock warrants	(975)	657	(2,211)	3,477
Change in value of contingent consideration	0	1,025	0	10,753
Equity earnings (losses) from Laramie Energy, LLC	553	3,659	11,651	(15,159)
Total other income (expense), net	(7,192)	(5,947)	(16,978)	(22,820)
Income (loss) before income taxes	19,524	(27,731)	55,378	(67,639)
Income tax benefit (expense)	(700)	(30)	(1,762)	8,117
Net income (loss)	$ 18,824	$ (27,761)	$ 53,616	$ (59,522)
Earnings (loss) per share
Basic (USD per share)	$ 0.41	$ (0.67)	$ 1.16	$ (1.44)
Diluted (USD per share)	$ 0.41	$ (0.67)	$ 1.16	$ (1.44)
Weighted-average number of shares outstanding
Basic (in shares)	45,561	41,580	45,505	41,309
Diluted (in shares)	51,992	41,580	45,527	41,309

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Cash flows from operating activities:
Net income (loss)	$ 53,616	$ (59,522)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, depletion, and amortization	33,848	19,839
Loss on termination of financing agreements	1,804	0
Non-cash interest expense	6,189	11,426
Change in value of common stock warrants	2,211	(3,477)
Change in value of contingent consideration	0	(10,753)
Deferred taxes	462	(8,565)
Stock-based compensation	5,803	5,103
Unrealized loss (gain) on derivative contracts	557	(5,804)
Equity (earnings) losses from Laramie Energy, LLC	(11,651)	15,159
Net changes in operating assets and liabilities:
Trade accounts receivable	12,070	3,233
Prepaid and other assets	46,747	29,258
Inventories	(121,040)	50,390
Deferred turnaround expenditures	0	(34,969)
Obligations under inventory financing agreements	89,549	(11,795)
Accounts payable and other accrued liabilities	(14,709)	(35,941)
Contingent consideration	0	(4,830)
Net cash provided by (used in) operating activities	105,456	(41,248)
Cash flows from investing activities:
Acquisitions of businesses, net of cash acquired	0	(209,183)
Capital expenditures	(19,888)	(19,276)
Proceeds from sale of assets	19	2,323
Change in restricted cash	502	(10,000)
Investment in Laramie Energy, LLC	0	(55,000)
Net cash used in investing activities	(19,367)	(291,136)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs	0	49,315
Proceeds from borrowings	239,538	301,782
Repayments of borrowings	(292,684)	(137,791)
Net borrowings (repayments) on deferred payment arrangement	(1,493)	26,654
Payment of deferred loan costs	(50)	(6,805)
Contingent consideration settlements	0	(11,980)
Other financing activities, net	(872)	(325)
Net cash provided by (used in) financing activities	(55,561)	220,850
Net increase (decrease) in cash and cash equivalents	30,528	(111,534)
Cash and cash equivalents at beginning of period	47,772	167,788
Cash and cash equivalents at end of period	78,300	56,254
Net cash received (paid) for:
Interest	(15,168)	(7,573)
Taxes	(1,115)	139
Non-cash investing and financing activities:
Accrued capital expenditures	4,469	2,583
Value of warrants and debt reclassified to equity	$ 0	$ 3,084

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Overview

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Overview

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, 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, ultra-low sulfur diesel, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota.

2) Retail - Our retail outlets sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our retail network includes Hele and “76” branded retail sites, cardlock stations, company-operated convenience stores, sites operated in cooperation with 7-Eleven, and other sites operated by third parties.

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 42.3% 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, our Texadian operations, and several small non-operated oil and gas interests that were owned by our predecessor.

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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, 2016 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, 2016.

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.

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 Renewable Identification Numbers(“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.

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 September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Cost of revenues	$	1,568	$	1,243	$	4,510	$	3,081
Operating expense	8,226		6,690		24,700		11,624
General and administrative expense	576		512		1,981		1,451

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, 2016, except for the following:

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”). The FASB’s objective was to provide a more robust framework to improve comparability of revenue recognition practices across entities by removing most industry and transaction specific guidance, align GAAP with International Financial Reporting Standards, and provide more useful information to financial statement users. This authoritative guidance changes the way entities recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date (“ASU 2015-14”), which defers the effective date of ASU 2014-09 by one year. ASU 2014-09 is now effective for interim and annual periods beginning after December 15, 2017 and early adoption is permitted for interim and annual periods beginning after December 15, 2016. We have formally established a working group to assess the amended revenue recognition guidance in Topic 606, including its impact on our business processes, accounting systems, controls, and financial statement disclosures. As part of our evaluation, the working group is reviewing existing revenue streams and identifying the types of arrangements where differences may arise in revenue recognition upon adoption of the new standard. Our largest revenue stream consists of revenues generated from the sale of refined products, generally at market prices. These revenues are recognized upon delivery of goods to a customer. Although we currently do not expect the new standard to have a material impact on the amount or timing of revenues recognized for the sale of refined products, we continue to evaluate the impact of this new standard on our consolidated financial statements and related disclosures.

In March 2017, the FASB issued 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 requires 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 requires entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. ASU 2017-07 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted as of the beginning of any annual period for which an entity’s financial statements (interim or annual) have not been issued or made available for issuance. ASU 2017-07 should be applied retrospectively for the presentation of cost components in the income statement and prospectively for the capitalization of the service cost component in assets. We do not expect the adoption of ASU 2017-07 to have a material impact on our financial condition, results of operations, or cash flows.

In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU is 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 guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied prospectively to an award modified on or after the adoption date. We do not expect the adoption of ASU 2017-09 to have a material impact on our financial condition, results of operations, or cash flows.

Accounting Principles Adopted

On January 1, 2017, we adopted ASU No. 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements as well as classification in the statement of cash flows. The adoption of this ASU did not have a material impact on our financial condition, results of operations, or cash flows.

On January 1, 2017, we adopted ASU No. 2016-07, Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting (“ASU 2016-07”). ASU 2016-07 simplifies the equity method of accounting by eliminating the requirement to retrospectively apply the equity method to an investment that subsequently qualifies for such accounting as a result of an increase in the level of ownership interest or degree of influence. The adoption of this ASU did not have any impact on our financial condition, results of operations, or cash flows.

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Investment in Laramie Energy, LLC

9 Months Ended

Sep. 30, 2017

Equity Method Investments and Joint Ventures [Abstract]

Investment in Laramie Energy, LLC

Investment in Laramie Energy, LLC

We have a 42.3% ownership interest in Laramie Energy. Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado. We acquired our equity interest in Laramie Energy as a result of (1) the contribution of certain natural gas and oil interests to Laramie Energy in conjunction with our corporate reorganization in August 2012 and (2) cash contributions of $27.5 million in 2015 and $55.0 million in 2016.

Laramie Energy has a $400 million revolving credit facility with a borrowing base currently set at $210 million that is secured by a lien on its natural gas and crude oil properties and related assets. As of September 30, 2017, the balance outstanding on the revolving credit facility was approximately $149 million. We are limited recourse guarantors of Laramie Energy’s credit facility, with such 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):

	Nine Months Ended September 30, 2017
Beginning balance	$	108,823
Equity earnings from Laramie Energy	7,657
Accretion of basis difference	3,994
Ending balance	$	120,474

Summarized financial information for Laramie Energy is as follows (in thousands):

	September 30, 2017		December 31, 2016
Current assets	$	12,149	$	12,199
Non-current assets	690,600		655,022
Current liabilities	43,599		58,067
Non-current liabilities	213,517		186,631

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Natural gas and oil revenues	$	38,141		$	31,091		$	114,178		$	68,513
Income (loss) from operations	133			(4,929		)	(162		)	(28,282		)
Net income (loss)	(1,838		)	5,056			18,102			(41,183		)

Laramie Energy's net (loss) income for the three and nine months endedSeptember 30, 2017 includes $12.3 million and $38.1 million of depreciation, depletion, and amortization (“DD&A”) and $2.3 million and $35.2 million of unrealized gain on derivative instruments, respectively. Laramie Energy’s net income (loss) for the three and nine months endedSeptember 30, 2016 includes $13.5 million and $34.1 million of DD&A and $12.7 million of unrealized gain and $16.8 million of unrealized loss on derivative instruments, respectively.

At September 30, 2017 and December 31, 2016, our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $63.8 million and $67.8 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.

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Acquisitions

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Acquisitions

Acquisitions

Wyoming Refining Company Acquisition

On June 14, 2016, Par Wyoming, LLC, a wholly owned subsidiary of Par, entered into a unit purchase agreement (the “Purchase Agreement”) with Black Elk Refining, LLC to purchase all of the issued and outstanding units representing the membership interests in Hermes Consolidated, LLC (d/b/a Wyoming Refining Company) and, indirectly, Wyoming Refining Company’s wholly owned subsidiary, Wyoming Pipeline Company, LLC (collectively, “Wyoming Refining” or “WRC”) (the “WRC Acquisition”). Wyoming Refining owns and operates a refinery and related logistics assets in Newcastle, Wyoming.

On July 14, 2016, we completed the WRC Acquisition for cash consideration of $209.4 million, including a deposit of $5.0 million paid in June 2016, and assumed debt consisting of term loans of $58.0 million and revolving loans of $10.1 million. The consideration was paid with funds received from the issuance of our 2.50% convertible subordinated bridge notes (the “Bridge Notes”), cash on hand, which included the net proceeds from our June 2016 issuance and sale of an aggregate of $115 million principal amount of 5.00% convertible senior notes due 2021 (the “5.00% Convertible Senior Notes”), and the issuance of a $65 million secured term loan by Par Wyoming Holdings, LLC (the “Par Wyoming Holdings Credit Agreement”).

We accounted for the WRC Acquisition 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 the acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Wyoming Refining and utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. Goodwill recognized as a result of the WRC Acquisition is expected to be deductible for income tax reporting purposes.

During the three months ended June 30, 2017, the purchase price allocation was adjusted to record an increase of $2.0 million to our Wyoming refinery’s environmental liability as a result of additional information obtained by management regarding estimated remediation costs at certain locations. The purchase price allocation was also adjusted to record an increase to inventory of $0.5 million related to line fill inventory at our refined product pipelines. Goodwill increased $1.5 million as a result of these adjusting entries recorded during the three months ended June 30, 2017. As of June 30, 2017, we finalized the WRC Acquisition purchase price allocation.

A summary of the fair values of the assets acquired and liabilities assumed is as follows (in thousands):

Cash	$	183
Accounts receivable	16,880
Inventories	28,402
Prepaid and other assets	1,304
Property, plant, and equipment	254,367
Goodwill (1)	66,449
Accounts payable and other current liabilities	(57,861		)
Wyoming Refining Senior Secured Revolver	(10,100		)
Wyoming Refining Senior Secured Term Loan	(58,036		)
Other non-current liabilities	(32,222		)
Total	$	209,366

______________________________________________

(1) We allocated $39.8 million and $26.6 million of goodwill to our refining and logistics segments, respectively.

The results of operations of Wyoming Refining were included in our results beginning July 14, 2016. The following unaudited pro forma financial information presents our consolidated revenues and net loss as if the WRC Acquisition had been completed on January 1, 2015 (in thousands, except per share amounts):

	Three Months Ended September 30, 2016			Nine Months Ended September 30, 2016
Revenues	$	522,163		$	1,463,101
Net loss	(26,384		)	(64,926		)
Loss per share
Basic	$	(0.58	)	$	(1.43	)
Diluted	$	(0.58	)	$	(1.43	)

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Inventories

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Inventories

Inventories

Inventories at September 30, 2017 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements (1)		Total
Crude oil and feedstocks	$	64,208	$	71,371	$	135,579
Refined products and blendstock	52,734		110,222		162,956
Warehouse stock and other	21,329		—		21,329
Total	$	138,271	$	181,593	$	319,864

Inventories at December 31, 2016 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements(1)		Total
Crude oil and feedstocks	$	11,620	$	49,682	$	61,302
Refined products and blendstock	38,916		77,677		116,593
Warehouse stock and other	20,431		—		20,431
Total	$	70,967	$	127,359	$	198,326

________________________________________________________

(1) Please read Note 7—Inventory Financing Agreements for further information.

There was no reserve for the lower of cost or net realizable value of inventory as of September 30, 2017. As of December 31, 2016, the reserve for the lower of cost or net realizable value of inventory was $0.2 million.

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Prepaid and Other Current Assets

9 Months Ended

Sep. 30, 2017

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Prepaid and Other Current Assets

Prepaid and Other Current Assets

Prepaid and other current assets at September 30, 2017 and December 31, 2016 consisted of the following (in thousands):

	September 30, 2017		December 31, 2016
Advances to suppliers for crude oil purchases	$	—	$	38,300
Collateral posted with broker for derivative instruments	708		2,714
Prepaid insurance	—		7,504
Derivative assets	2,413		161
Other	5,818		4,701
Total	$	8,939	$	53,380

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Inventory Financing Agreements

9 Months Ended

Sep. 30, 2017

Other Commitments [Abstract]

Inventory Financing Agreements

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, we also entered into a $30 million forward sale of certain monthly volumes of jet fuel to be delivered to J. Aron over the remaining term of the Supply and Offtake Agreements (“J. Aron Forward Sale”). The obligation associated with this forward sale is recorded as debt in our condensed consolidated balance sheets. Please read Note 8—Debt for additional information regarding this forward sale.

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 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. Our obligations under the Supply and Offtake Agreements are secured by a security interest on substantially all of the assets of our subsidiary Par Hawaii Refining, LLC (“PHR”), a security interest on the equity interests held by our wholly owned subsidiary, Par Petroleum, LLC, in PHR, and a mortgage whereby PHR granted to J. Aron a lien on all real property and improvements owned by PHR, including our Hawaii refinery.

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 and nine months endedSeptember 30, 2017, we incurred approximately $3.4 million and $9.8 million in handling fees related to the Supply and Offtake Agreements, respectively, which is included in Cost of revenues (excluding depreciation) on our condensed consolidated statements of operations. For the three and nine months endedSeptember 30, 2016, we incurred approximately $1.7 million and $5.6 million in handling fees related to the Supply and Offtake Agreements, respectively. For the three and nine months endedSeptember 30, 2017, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.8 million and $2.3 million of expenses related to the Supply and Offtake Agreements, respectively. For the three and nine months endedSeptember 30, 2016, Interest expense and financing costs, net on our condensed consolidated statements of operations includes approximately $0.9 million and $2.2 million of expenses related to the Supply and Offtake Agreements, respectively.

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 September 30, 2017 and December 31, 2016, the capacity of the Deferred Payment Arrangement was $75.5 million and $59.4 million, respectively. As of September 30, 2017 and December 31, 2016, we had $41.8 million and $43.3 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 September 2015, we entered into an agreement to fix this market fee for the period from October 1, 2015 through November 30, 2016 whereby J. Aron agreed to pay us a total of $18 million to be settled in fourteen equal monthly payments. In February 2016, we fixed the market fee for the period from December 1, 2016 through May 31, 2018 for an additional $14.6 million to be settled in eighteen equal monthly payments. In July and August 2017 we fixed the market fee for the period from June 1, 2018 through April 2021 for an additional aggregate $3.0 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 September 30, 2017 and December 31, 2016, the receivable was $10.3 million and $14.6 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 9—Derivatives for further information.

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Debt

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Debt

Debt

The following table summarizes our outstanding debt (in thousands):

	September 30, 2017			December 31, 2016
Hawaii Retail Credit Facilities	$	85,023		$	95,319
5.00% Convertible Senior Notes due 2021	115,000			115,000
Term Loan	—			60,361
J. Aron Forward Sale	27,855			—
Par Wyoming Holdings Term Loan	67,325			67,325
Wyoming Refining Senior Secured Term Loan	48,752			55,715
Wyoming Refining Senior Secured Revolver	9,502			6,700
Principal amount of long-term debt	353,457			400,420
Less: unamortized discount and deferred financing costs	(23,256		)	(30,024		)
Total debt, net of unamortized discount and deferred financing costs	330,201			370,396
Less: current maturities	(27,140		)	(20,286		)
Long-term debt, net of current maturities	$	303,061		$	350,110

Our debt is subject to various affirmative, negative, and financial covenants. As of September 30, 2017, we were in compliance with all debt covenants. Some of our subsidiaries have restrictions in their respective credit facilities with regard to dividends, distributions, loans, or advances. In certain circumstances, the consent of a third party would be required prior to the transfer of any cash or assets from these subsidiaries to us.

J. Aron Forward Sale

On May 8, 2017, J. Aron and the Company 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, we also entered into a $30 million forward sale of jet fuel to be delivered to J. Aron over the amended term (“J. Aron Forward Sale”). The proceeds from the J. Aron Forward Sale were used to pay a portion of the outstanding balance on the Term Loan.

The $30 million obligation under the J. Aron Forward Sale will be repaid through the monthly delivery of jet fuel at an agreed upon price between the two parties. The jet fuel volumes to be delivered to J. Aron are equivalent to principal payments of $3.9 million in 2017, $7.0 million in 2018, $7.5 million in 2019, $8.1 million in 2020, and $3.5 million in 2021. The cost of the J. Aron Forward Sale is based upon an annual interest rate of 7%.

The obligation associated with the J. Aron Forward Sale is recorded as debt in our condensed consolidated balance sheets. As of September 30, 2017, the outstanding balance of the J. Aron Forward Sale debt obligation was $27.9 million.

Wyoming Refining Credit Facilities

Wyoming Refining Company and its wholly owned subsidiary, Wyoming Pipeline Company, LLC, are borrowers under a Third Amended and Restated Loan Agreement dated as of April 30, 2015 (as amended, the “Wyoming Refining Credit Facilities”), with Bank of America, N.A. as the lender. The Wyoming Refining Credit Facilities provide for (1) a revolving credit facility in the maximum principal amount at any time outstanding of $30 million (“Wyoming Refining Senior Secured Revolver”), subject to a borrowing base, which provides for revolving loans and for the issuance of letters of credit and (2) certain term loans that are fully advanced (“Wyoming Refining Senior Secured Term Loan”). The Wyoming Refining Senior Secured Term Loan requires quarterly principal payments of $2.3 million. On August 7, 2017, we entered into an amendment to the Wyoming Refining Credit Facilities to extend the maturity date from April 30, 2018 until June 30, 2019. All remaining outstanding amounts under the Wyoming Refining Senior Secured Term Loan and the Wyoming Refining Senior Secured Revolver are fully payable on June 30, 2019.

5.00% Convertible Senior Notes Due 2021

As of September 30, 2017, the outstanding principal amount of the 5.00% Convertible Senior Notes was $115.0 million, the unamortized discount and deferred financing cost was $20.7 million, and the carrying amount of the liability component was $94.3 million.

Term Loan

On June 30, 2017, we fully repaid and terminated the Delayed Draw Term Loan and Bridge Loan Credit Agreement (“Term Loan”). A portion of the proceeds from the J. Aron Forward Sale and cash flows from operations were used to repay the full amount outstanding. We recorded a loss on termination of approximately $1.8 million related to unamortized deferred financing costs associated with the Term Loan in the nine months endedSeptember 30, 2017.

Hawaii Retail Credit Facilities

On June 28, 2017, certain subsidiaries of the Company entered into a second amendment to the Key Bank Credit Agreement dated December 17, 2015 in order to permit a special distribution of cash from such subsidiaries to the Company in an aggregate amount totaling no more than $15 million. The amendment also waived the mandatory excess cash flow prepayment for the quarter ended June 30, 2017.

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 September 30, 2017, we are in compliance with all of our credit 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.

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Derivatives

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

Derivatives

Commodity Derivatives

We utilize crude oil commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, and future sales of refined products. 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 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 10—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 September 30, 2017, our open commodity derivative contracts represented:

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

• OTC swap sales of 115 thousand barrels that economically hedge our month-end target volumes related to our Supply and Offtake Agreements; and

• option collars of 52 thousand barrels per month through December 2017 and option collars and OTC swaps of 75 thousand barrels per month 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 September 30, 2017, we had locked in an average fixed rate of 1.1% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $200 million. The interest rate swaps mature in February 2019 and March 2021.

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 September 30, 2017, 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 September 30, 2017 and December 31, 2016 and their placement within our condensed consolidated balance sheets.

	Balance Sheet Location	September 30, 2017			December 31, 2016
		Asset (Liability)
Commodity derivatives (1)	Prepaid and other current assets	$	1,561		$	—
Commodity derivatives (1)	Other long-term assets	571			2,748
Commodity derivatives	Other accrued liabilities	(58		)	(595		)
J. Aron repurchase obligation derivative	Obligations under inventory financing agreements	(24,995		)	(20,000		)
Interest rate derivatives	Prepaid and other current assets	851			161
Interest rate derivatives	Other long-term assets	2,115			3,377
Interest rate derivatives	Other accrued liabilities	—			(94		)

_________________________________________________________

(1) Does not include cash collateral of $0.7 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of September 30, 2017 and December 31, 2016, respectively.

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 September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2017			2016			2017			2016
Commodity derivatives	Cost of revenues (excluding depreciation)	$	3,657		$	(3,028	)	$	26		$	(3,117	)
J. Aron repurchase obligation derivative	Cost of revenues (excluding depreciation)	(24,041		)	(8,300		)	(4,995		)	(20,356		)
Interest rate derivatives	Interest expense and financing costs, net	148			1,204			(477		)	(1,098		)

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Fair Value Measurements

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Common Stock Warrants

As of September 30, 2017 and December 31, 2016, 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 September 30, 2017 and December 31, 2016, the warrants had a weighted-average exercise price of $0.09 and $0.10 and a remaining term of 4.92 years and 5.67 years, respectively.

The estimated fair value of the common stock warrants was $20.73 and $14.49 per share as of September 30, 2017 and December 31, 2016, respectively.

Derivative Instruments

We utilize crude oil commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil, and future sales of refined products. 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 September 30, 2017 or December 31, 2016. Please read Note 9—Derivatives for further information on derivatives.

Financial Statement Impact

Fair value amounts by hierarchy level as of September 30, 2017 and December 31, 2016 are presented gross in the tables below (in thousands):

	September 30, 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	$	235		$	28,733		$	—		$	28,968		$	(26,836	)	$	2,132
Interest rate derivatives	—			2,966			—			2,966			—			2,966
Total	$	235		$	31,699		$	—		$	31,934		$	(26,836	)	$	5,098
Liabilities
Common stock warrants	$	—		$	—		$	(7,345	)	$	(7,345	)	$	—		$	(7,345	)
Commodity derivatives	(150		)	(26,744		)	—			(26,894		)	26,836			(58		)
J. Aron repurchase obligation derivative	—			—			(24,995		)	(24,995		)	—			(24,995		)
Total	$	(150	)	$	(26,744	)	$	(32,340	)	$	(59,234	)	$	26,836		$	(32,398	)

	December 31, 2016
	Level 1			Level 2			Level 3			Gross Fair Value			Effect of Counter-Party Netting			Net Carrying Value on Balance Sheet (1)
Assets
Commodity derivatives	$	190		$	26,095		$	—		$	26,285		$	(23,537	)	$	2,748
Interest rate derivatives	—			3,602			—			3,602			(64		)	3,538
Total	$	190		$	29,697		$	—		$	29,887		$	(23,601	)	$	6,286
Liabilities
Common stock warrants	$	—		$	—		$	(5,134	)	$	(5,134	)	$	—		$	(5,134	)
Commodity derivatives	(54		)	(24,078		)	—			(24,132		)	23,537			(595		)
J. Aron repurchase obligation derivative	—			—			(20,000		)	(20,000		)	—			(20,000		)
Interest rate derivatives	—			(158		)	—			(158		)	64			(94		)
Total	$	(54	)	$	(24,236	)	$	(25,134	)	$	(49,424	)	$	23,601		$	(25,823	)

_________________________________________________________

(1) Does not include cash collateral of $7.7 million and $9.7 million as of September 30, 2017 and December 31, 2016, respectively, included within Prepaid and other current assets and Other long-term assets on our condensed consolidated balance sheets.

A roll forward of Level 3 financial instruments measured at fair value on a recurring basis is as follows (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Balance, at beginning of period	$	(7,324	)	$	(8,564	)	$	(25,134	)	$	(25,867	)
Settlements	—			—			—			16,810
Total unrealized income (loss) included in earnings	(25,016		)	(6,618		)	(7,206		)	(6,125		)
Balance, at end of period	$	(32,340	)	$	(15,182	)	$	(32,340	)	$	(15,182	)

The carrying value and fair value of long-term debt and other financial instruments as of September 30, 2017 and December 31, 2016 are as follows (in thousands):

	September 30, 2017
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	83,773	$	83,773
5.00% Convertible Senior Notes due 2021 (3)	94,328		154,116
J. Aron Forward Sale	27,855		27,523
Par Wyoming Holdings Term Loan (2)	66,091		66,091
Wyoming Refining Senior Secured Term Loan (2)	48,652		48,652
Wyoming Refining Senior Secured Revolver (2)	9,502		9,502
Common stock warrants	7,345		7,345

	December 31, 2016
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	93,853	$	93,853
5.00% Convertible Senior Notes due 2021 (3)	91,029		122,229
Term Loan	57,426		62,367
Par Wyoming Holdings Term Loan (2)	65,908		65,908
Wyoming Refining Senior Secured Term Loan (2)	55,480		55,480
Wyoming Refining Senior Secured Revolver (2)	6,700		6,700
Common stock warrants	5,134		5,134

_________________________________________________________

(1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy with the exception of the fair value measurement of the 5.00% Convertible Senior Notes which is considered a Level 2 measurement as discussed below.

(2) Fair value approximates carrying value due to the debt’s floating rate interest which approximates current market value.

(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.

We estimated the fair value of the J. Aron Forward Sale using a discounted cash flow analysis and an assumed yield of 8.00% as of September 30, 2017 by reference to market interest rates for similar debt instruments of comparable companies.

We estimated the fair value of the Term Loan using a discounted cash flow analysis and an estimate of the current yield of 11.06% as of December 31, 2016 by reference to market interest rates for term debt of comparable companies.

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 September 30, 2017. 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 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.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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.

Tesoro Earnout 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 it 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. The cash consideration for the acquisition is subject to an earn-out provision during the years 2014-2016, subject to, among other things, an annual earn-out cap of $20 million. During 2016, we paid Tesoro a total of $16.8 million to settle the 2014 and 2015 earn-out periods. Tesoro has disputed our calculation of the 2015 and 2016 earn-out amounts and has asserted that it is 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.  If we and Tesoro are unable to agree on the calculation of the 2015 and 2016 earn-out amounts, the dispute will be resolved in accordance with the dispute resolution provisions set forth in the membership interest purchase agreement to determine the amounts owed, if any. The Company disputes that any additional amounts are due and intends to vigorously defend itself in connection with the resolution of Tesoro’s claims.

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 Petroleum, LLC (“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 March 19, 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 February 26, 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.

Wyoming refinery

Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the U.S. Environmental Protection Agency(“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 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. Based on current information, however, estimates we have received for the well-understood components of these efforts suggest total response costs of approximately $20.0 million, approximately one-third of which we expect to incur in the next 5 years, with 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 $0.5 million to modify or close the existing wastewater treatment ponds and 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 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 appears to be declining over time, Wyoming Refining may become subject to new penalty enforcement action in the next several years, which could involve penalties in excess of $100,000. Moreover, in addition to the issues associated with the Wyoming refinery, certain product pipeline assets were acquired in the WRC Acquisition. The Pipeline and Hazardous Materials Safety Administration (“PHMSA”) conducted an integrated inspection of the products pipeline with additional follow-up regarding integrity management planning and general operations and maintenance. Based on preliminary discussions with PHMSA following this inspection, the Wyoming refinery anticipates a civil penalty in excess of $100,000. In connection with our acquisition of, and commencement of operations at, the Wyoming refinery, findings of a past failure to comply with applicable environmental or pipeline safety laws and regulations may trigger a variety of administrative, civil, and criminal enforcement measures, including the assessment of monetary penalties that could be in excess of $100,000, the imposition of investigatory, remedial, or corrective actions, and the issuance of orders enjoining future operations or imposing additional compliance requirements on such operations.

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 CO₂ 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 CO₂ 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.

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. Our Hawaii refinery is required to comply with Tier 3 gasoline standards within 30 months of June 21, 2016, the date our Hawaii refinery was disqualified from small volume refinery status. On March 19, 2015, the EPA confirmed the small volume refinery status of our Wyoming refinery.

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 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.

We estimate the cost of compliance with the Consent Decree to be approximately $30 million. However, Tesoro is responsible under the Environmental Agreement for 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 September 30, 2017, Tesoro has reimbursed us for $11.8 million of the total capital expenditures of $12.5 million incurred in connection with the Consent Decree. Net capital expenditures and reimbursements related to the Consent Decree for the nine months ended September 30, 2017 and 2016 are presented within Capital expenditures on our condensed consolidated statement of cash flows for the related periods.

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.

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 the Debtors hold against third parties.

As of September 30, 2017, two related claims totaling approximately $22.4 million remained to be resolved by the trustee for the General Trust and we have reserved 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 are settled at a ratio of 54.4 shares per $1,000 of claim.

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Stockholders' Equity

9 Months Ended

Sep. 30, 2017

Equity [Abstract]

Stockholders' Equity

Stockholders’ Equity

Incentive Plan

The following table summarizes our compensation costs recognized in General and administrative 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 September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Restricted Stock Awards	$	967	$	791	$	3,482	$	2,241
Restricted Stock Units	127		62		364		1,167
Stock Option Awards	583		756		1,957		1,695

During the three and nine months ended September 30, 2017, we granted 20 thousand and 273 thousand shares of restricted stock and restricted stock units with a fair value of approximately $0.4 million and $4.0 million, respectively. As of September 30, 2017, there were approximately $6.5 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 2.6 years.

During the nine months ended September 30, 2017, we granted 239 thousand stock option awards with a weighted-average exercise price of $15.03 per share and no grants were made for the three months endedSeptember 30, 2017. As of September 30, 2017, there were approximately $4.0 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 2.7 years.

During the nine months ended September 30, 2017, we granted 45 thousand performance restricted stock units to executive officers and no performance restricted stock units were granted for the three months endedSeptember 30, 2017. These performance restricted stock units had a fair value of approximately $0.7 million and are subject to certain annual performance targets as defined by our Board of Directors. As of September 30, 2017, there were approximately $0.5 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 2.4 years.

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Defined Benefit Plan

9 Months Ended

Sep. 30, 2017

Compensation and Retirement Disclosure [Abstract]

Defined Benefit Plan

Defined Benefit Plan

We maintain a defined benefit pension plan (the “Benefit Plan”) covering substantially all of our Wyoming Refining employees. Benefits are based on years of service and the employee’s highest average compensation received during five consecutive years of the last 10 years of employment. Our funding policy is to contribute annually an amount equal to the pension expense, subject to the minimum funding requirements of the Employee Retirement Income Security Act of 1974 and the tax deductibility of such contributions. As of September 30, 2017 and December 31, 2016, we had no amounts recorded in Accumulated other comprehensive income that are expected to be amortized into net periodic benefit cost in 2017. The Benefit Plan was assumed in connection with the WRC Acquisition on July 14, 2016.

The net periodic benefit cost (credit) related to our defined benefit plan includes the following components (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Components of net periodic benefit cost (credit):
Service cost	$	153		$	334		$	460		$	334
Interest cost	298			299			894			299
Expected return on plan assets	(297		)	(343		)	(892		)	(343		)
Net periodic benefit cost	$	154		$	290		$	462		$	290

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Income (Loss) per Share

9 Months Ended

Sep. 30, 2017

Earnings Per Share [Abstract]

Income (Loss) per Share

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 each of the three and nine months ended September 30, 2017 and 352 thousand shares during each of the three and nine months ended September 30, 2016, 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 September 30,					Nine Months Ended September 30,
	2017		2016			2017		2016
Net income (loss)	$	18,824	$	(27,761	)	$	53,616	$	(59,522	)
Less: Undistributed income allocated to participating securities (1)	238		—			685		—
Net income (loss) attributable to common stockholders	18,586		(27,761		)	52,931		(59,522		)
Plus: Net income effect of convertible securities	2,566		—			—		—
Numerator for diluted income (loss) per common share	$	21,152	$	(27,761	)	$	52,931	$	(59,522	)
Basic weighted-average common stock shares outstanding	45,561		41,580			45,505		41,309
Plus: dilutive effects of common stock equivalents (2)	6,431		—			22		—
Diluted weighted-average common stock shares outstanding	51,992		41,580			45,527		41,309
Basic income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)
Diluted income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)

________________________________________________________

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

(2) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per share for the three and nine months ended September 30, 2016.

For the three and nine months ended September 30, 2017, our calculation of dilutive shares outstanding excluded 31 thousand and 83 thousand shares of unvested restricted stock and 1.3 million and 1.5 million stock options, respectively. For the nine months ended September 30, 2017, our calculation of dilutive shares outstanding also excluded 6.4 million common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on January 1, 2017. For the three and nine months ended September 30, 2016, our calculation of diluted shares outstanding excluded 463 thousand and 448 thousand shares of unvested restricted stock, 1.7 million stock options, and 6.4 million and 2.3 million common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on the date of issuance, respectively.

As discussed in Note 8—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 and nine months ended September 30, 2017, diluted income (loss) per share was determined using the if-converted method.

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Income Taxes

9 Months Ended

Sep. 30, 2017

Income Tax Disclosure [Abstract]

Income Taxes

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 September 30, 2017.

During the three and nine months ended September 30, 2017 and 2016, no adjustments were recognized for uncertain tax positions.

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 net operating loss (“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.

We will 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.

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Segment Information

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Segment Information

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 third quarter of 2016, the results of operations of Wyoming Refining are included in our refining and logistics segments.

We have recast the segment information for the three and nine months ended September 30, 2016 to reflect the elimination of the Texadian segment as a reportable segment beginning in the first quarter of 2017. As of September 30, 2017, Texadian ceased its business operations other than the disposal of certain assets and liquidation of inventory. Our Corporate and Other reportable segment now includes administrative costs, our Texadian operations, and several small non-operated oil and gas interests that were owned by our predecessor.

Summarized financial information concerning reportable segments consists of the following (in thousands):

Three Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	578,511	$	31,838	$	83,682	$	(83,525	)	$	610,506
Cost of revenues (excluding depreciation)	513,664		15,857		63,175		(83,220		)	509,476
Operating expense (excluding depreciation)	36,126		4,029		11,563		—			51,718
Depreciation, depletion, and amortization	7,390		1,602		1,471		841			11,304
General and administrative expense (excluding depreciation)	—		—		—		11,292			11,292
Operating income (loss)	$	21,331	$	10,350	$	7,473	$	(12,438	)	$	26,716
Interest expense and financing costs, net										(7,419		)
Other income, net										649
Change in value of common stock warrants										(975		)
Equity earnings from Laramie Energy, LLC										553
Income before income taxes										19,524
Income tax expense										(700		)
Net income										$	18,824
Capital expenditures	$	3,171	$	2,606	$	811	$	1,523		$	8,111

Three Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	462,975		$	28,107	$	75,577	$	(56,354	)	$	510,305
Cost of revenues (excluding depreciation)	439,477			19,334		56,365		(55,880		)	459,296
Operating expense (excluding depreciation)	35,910			4,686		10,461		183			51,240
Depreciation, depletion, and amortization	5,755			1,275		1,898		715			9,643
General and administrative expense (excluding depreciation)	—			—		—		9,863			9,863
Acquisition and integration expense	—			—		—		2,047			2,047
Operating income (loss)	$	(18,167	)	$	2,812	$	6,853	$	(13,282	)	$	(21,784	)
Interest expense and financing costs, net											(11,232		)
Other expense, net											(56		)
Change in value of common stock warrants											657
Change in value of contingent consideration											1,025
Equity earnings from Laramie Energy, LLC											3,659
Loss before income taxes											(27,731		)
Income tax expense											(30		)
Net loss											$	(27,761	)
Capital expenditures	$	3,820		$	266	$	1,636	$	1,863		$	7,585

________________________________________________________

(1) Includes eliminations of intersegment revenues and cost of revenues of $83.4 million and $72.1 million for the three months ended September 30, 2017 and 2016, respectively.

Nine Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,685,341	$	91,456	$	243,711	$	(240,504	)	$	1,780,004
Cost of revenues (excluding depreciation)	1,493,472		46,982		184,916		(240,252		)	1,485,118
Operating expense (excluding depreciation)	107,237		12,675		33,829		—			153,741
Depreciation, depletion, and amortization	22,243		4,613		4,377		2,615			33,848
General and administrative expense (excluding depreciation)	—		—		—		34,688			34,688
Acquisition and integration expense	—		—		—		253			253
Operating income (loss)	$	62,389	$	27,186	$	20,589	$	(37,808	)	$	72,356
Interest expense and financing costs, net										(25,500		)
Loss on termination of financing agreement										(1,804		)
Other income, net										886
Change in value of common stock warrants										(2,211		)
Equity earnings from Laramie Energy, LLC										11,651
Income before income taxes										55,378
Income tax expense										(1,762		)
Net income										$	53,616
Capital expenditures	$	5,495	$	5,345	$	4,434	$	4,614		$	19,888

Nine Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,172,164		$	73,686	$	215,952	$	(159,893	)	$	1,301,909
Cost of revenues (excluding depreciation)	1,112,730			48,707		162,831		(157,921		)	1,166,347
Operating expense (excluding depreciation)	85,053			8,906		31,059		307			125,325
Depreciation, depletion, and amortization	9,649			3,116		4,930		2,144			19,839
General and administrative expense (excluding depreciation)	—			—		—		31,654			31,654
Acquisition and integration expense	—			—		—		3,563			3,563
Operating income (loss)	$	(35,268	)	$	12,957	$	17,132	$	(39,640	)	$	(44,819	)
Interest expense and financing costs, net											(21,951		)
Other income, net											60
Change in value of common stock warrants											3,477
Change in value of contingent consideration											10,753
Equity losses from Laramie Energy, LLC											(15,159		)
Loss before income taxes											(67,639		)
Income tax benefit											8,117
Net loss											$	(59,522	)
Capital expenditures	$	10,947		$	1,151	$	3,699	$	3,479		$	19,276

________________________________________________________ 

(1) Includes eliminations of intersegment revenues and cost of revenues of $241.5 million and $198.0 million for the nine months ended September 30,2017 and 2016, respectively.

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Related Party Transactions

9 Months Ended

Sep. 30, 2017

Related Party Transactions [Abstract]

Related Party Transactions

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 and nine months ended September 30, 2017 or 2016.

Term Loan

On June 30, 2017, we fully repaid and terminated the Term Loan. An affiliate of Whitebox Advisors, LLC (“Whitebox”), which owns 10% or more of our common stock directly or through affiliates, had been a lender under the Term Loan.

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Principles of Consolidation and Basis of Presentation

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, 2016 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, 2016.

Use Of Estimates

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.

Cost of revenues

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 Renewable Identification Numbers(“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.

Operating expenses

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.

Recent Accounting Pronouncements

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, 2016, except for the following:

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”). The FASB’s objective was to provide a more robust framework to improve comparability of revenue recognition practices across entities by removing most industry and transaction specific guidance, align GAAP with International Financial Reporting Standards, and provide more useful information to financial statement users. This authoritative guidance changes the way entities recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date (“ASU 2015-14”), which defers the effective date of ASU 2014-09 by one year. ASU 2014-09 is now effective for interim and annual periods beginning after December 15, 2017 and early adoption is permitted for interim and annual periods beginning after December 15, 2016. We have formally established a working group to assess the amended revenue recognition guidance in Topic 606, including its impact on our business processes, accounting systems, controls, and financial statement disclosures. As part of our evaluation, the working group is reviewing existing revenue streams and identifying the types of arrangements where differences may arise in revenue recognition upon adoption of the new standard. Our largest revenue stream consists of revenues generated from the sale of refined products, generally at market prices. These revenues are recognized upon delivery of goods to a customer. Although we currently do not expect the new standard to have a material impact on the amount or timing of revenues recognized for the sale of refined products, we continue to evaluate the impact of this new standard on our consolidated financial statements and related disclosures.

In March 2017, the FASB issued 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 requires 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 requires entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. ASU 2017-07 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted as of the beginning of any annual period for which an entity’s financial statements (interim or annual) have not been issued or made available for issuance. ASU 2017-07 should be applied retrospectively for the presentation of cost components in the income statement and prospectively for the capitalization of the service cost component in assets. We do not expect the adoption of ASU 2017-07 to have a material impact on our financial condition, results of operations, or cash flows.

In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU is 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 guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied prospectively to an award modified on or after the adoption date. We do not expect the adoption of ASU 2017-09 to have a material impact on our financial condition, results of operations, or cash flows.

Accounting Principles Adopted

On January 1, 2017, we adopted ASU No. 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements as well as classification in the statement of cash flows. The adoption of this ASU did not have a material impact on our financial condition, results of operations, or cash flows.

On January 1, 2017, we adopted ASU No. 2016-07, Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting (“ASU 2016-07”). ASU 2016-07 simplifies the equity method of accounting by eliminating the requirement to retrospectively apply the equity method to an investment that subsequently qualifies for such accounting as a result of an increase in the level of ownership interest or degree of influence. The adoption of this ASU did not have any impact on our financial condition, results of operations, or cash flows.

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Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Depreciation Expense Excluded From Each Line Item in Consolidated Statements of Operations

The following table summarizes depreciation expense excluded from each line item in our consolidated statements of operations (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Cost of revenues	$	1,568	$	1,243	$	4,510	$	3,081
Operating expense	8,226		6,690		24,700		11,624
General and administrative expense	576		512		1,981		1,451

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Investment in Laramie Energy, LLC (Tables)

9 Months Ended

Sep. 30, 2017

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

The change in our equity investment in Laramie Energy is as follows (in thousands):

	Nine Months Ended September 30, 2017
Beginning balance	$	108,823
Equity earnings from Laramie Energy	7,657
Accretion of basis difference	3,994
Ending balance	$	120,474

Equity Method Investees Financial Information

Summarized financial information for Laramie Energy is as follows (in thousands):

	September 30, 2017		December 31, 2016
Current assets	$	12,149	$	12,199
Non-current assets	690,600		655,022
Current liabilities	43,599		58,067
Non-current liabilities	213,517		186,631

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Natural gas and oil revenues	$	38,141		$	31,091		$	114,178		$	68,513
Income (loss) from operations	133			(4,929		)	(162		)	(28,282		)
Net income (loss)	(1,838		)	5,056			18,102			(41,183		)

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Acquisitions (Tables)

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Fair Value of Assets Acquired and Liabilities Assumed

A summary of the fair values of the assets acquired and liabilities assumed is as follows (in thousands):

Cash	$	183
Accounts receivable	16,880
Inventories	28,402
Prepaid and other assets	1,304
Property, plant, and equipment	254,367
Goodwill (1)	66,449
Accounts payable and other current liabilities	(57,861		)
Wyoming Refining Senior Secured Revolver	(10,100		)
Wyoming Refining Senior Secured Term Loan	(58,036		)
Other non-current liabilities	(32,222		)
Total	$	209,366

______________________________________________

(1) We allocated $39.8 million and $26.6 million of goodwill to our refining and logistics segments, respectively.

Business Acquisition, Pro Forma Information

The following unaudited pro forma financial information presents our consolidated revenues and net loss as if the WRC Acquisition had been completed on January 1, 2015 (in thousands, except per share amounts):

	Three Months Ended September 30, 2016			Nine Months Ended September 30, 2016
Revenues	$	522,163		$	1,463,101
Net loss	(26,384		)	(64,926		)
Loss per share
Basic	$	(0.58	)	$	(1.43	)
Diluted	$	(0.58	)	$	(1.43	)

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Inventories (Tables)

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Schedule of inventories

Inventories at September 30, 2017 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements (1)		Total
Crude oil and feedstocks	$	64,208	$	71,371	$	135,579
Refined products and blendstock	52,734		110,222		162,956
Warehouse stock and other	21,329		—		21,329
Total	$	138,271	$	181,593	$	319,864

Inventories at December 31, 2016 consisted of the following (in thousands):

	Titled Inventory		Supply and Offtake Agreements(1)		Total
Crude oil and feedstocks	$	11,620	$	49,682	$	61,302
Refined products and blendstock	38,916		77,677		116,593
Warehouse stock and other	20,431		—		20,431
Total	$	70,967	$	127,359	$	198,326

________________________________________________________

(1) Please read Note 7—Inventory Financing Agreements for further information.

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Prepaid and Other Current Assets (Tables)

9 Months Ended

Sep. 30, 2017

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Prepaid and Other Current Assets

Prepaid and other current assets at September 30, 2017 and December 31, 2016 consisted of the following (in thousands):

	September 30, 2017		December 31, 2016
Advances to suppliers for crude oil purchases	$	—	$	38,300
Collateral posted with broker for derivative instruments	708		2,714
Prepaid insurance	—		7,504
Derivative assets	2,413		161
Other	5,818		4,701
Total	$	8,939	$	53,380

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Debt (Tables)

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Summary of Outstanding Debt

The following table summarizes our outstanding debt (in thousands):

	September 30, 2017			December 31, 2016
Hawaii Retail Credit Facilities	$	85,023		$	95,319
5.00% Convertible Senior Notes due 2021	115,000			115,000
Term Loan	—			60,361
J. Aron Forward Sale	27,855			—
Par Wyoming Holdings Term Loan	67,325			67,325
Wyoming Refining Senior Secured Term Loan	48,752			55,715
Wyoming Refining Senior Secured Revolver	9,502			6,700
Principal amount of long-term debt	353,457			400,420
Less: unamortized discount and deferred financing costs	(23,256		)	(30,024		)
Total debt, net of unamortized discount and deferred financing costs	330,201			370,396
Less: current maturities	(27,140		)	(20,286		)
Long-term debt, net of current maturities	$	303,061		$	350,110

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Derivatives (Tables)

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value Amounts of Derivatives and Placement in Consolidated Balance Sheets

The following table provides information on the fair value amounts (in thousands) of these derivatives as of September 30, 2017 and December 31, 2016 and their placement within our condensed consolidated balance sheets.

	Balance Sheet Location	September 30, 2017			December 31, 2016
		Asset (Liability)
Commodity derivatives (1)	Prepaid and other current assets	$	1,561		$	—
Commodity derivatives (1)	Other long-term assets	571			2,748
Commodity derivatives	Other accrued liabilities	(58		)	(595		)
J. Aron repurchase obligation derivative	Obligations under inventory financing agreements	(24,995		)	(20,000		)
Interest rate derivatives	Prepaid and other current assets	851			161
Interest rate derivatives	Other long-term assets	2,115			3,377
Interest rate derivatives	Other accrued liabilities	—			(94		)

_________________________________________________________

(1) Does not include cash collateral of $0.7 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of September 30, 2017 and December 31, 2016, respectively.

Pre-Tax Gain (Loss) Recognized in the Statement of Operations

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 September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2017			2016			2017			2016
Commodity derivatives	Cost of revenues (excluding depreciation)	$	3,657		$	(3,028	)	$	26		$	(3,117	)
J. Aron repurchase obligation derivative	Cost of revenues (excluding depreciation)	(24,041		)	(8,300		)	(4,995		)	(20,356		)
Interest rate derivatives	Interest expense and financing costs, net	148			1,204			(477		)	(1,098		)

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Amounts by Hierarchy Level

Fair value amounts by hierarchy level as of September 30, 2017 and December 31, 2016 are presented gross in the tables below (in thousands):

	September 30, 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	$	235		$	28,733		$	—		$	28,968		$	(26,836	)	$	2,132
Interest rate derivatives	—			2,966			—			2,966			—			2,966
Total	$	235		$	31,699		$	—		$	31,934		$	(26,836	)	$	5,098
Liabilities
Common stock warrants	$	—		$	—		$	(7,345	)	$	(7,345	)	$	—		$	(7,345	)
Commodity derivatives	(150		)	(26,744		)	—			(26,894		)	26,836			(58		)
J. Aron repurchase obligation derivative	—			—			(24,995		)	(24,995		)	—			(24,995		)
Total	$	(150	)	$	(26,744	)	$	(32,340	)	$	(59,234	)	$	26,836		$	(32,398	)

	December 31, 2016
	Level 1			Level 2			Level 3			Gross Fair Value			Effect of Counter-Party Netting			Net Carrying Value on Balance Sheet (1)
Assets
Commodity derivatives	$	190		$	26,095		$	—		$	26,285		$	(23,537	)	$	2,748
Interest rate derivatives	—			3,602			—			3,602			(64		)	3,538
Total	$	190		$	29,697		$	—		$	29,887		$	(23,601	)	$	6,286
Liabilities
Common stock warrants	$	—		$	—		$	(5,134	)	$	(5,134	)	$	—		$	(5,134	)
Commodity derivatives	(54		)	(24,078		)	—			(24,132		)	23,537			(595		)
J. Aron repurchase obligation derivative	—			—			(20,000		)	(20,000		)	—			(20,000		)
Interest rate derivatives	—			(158		)	—			(158		)	64			(94		)
Total	$	(54	)	$	(24,236	)	$	(25,134	)	$	(49,424	)	$	23,601		$	(25,823	)

_________________________________________________________

(1) Does not include cash collateral of $7.7 million and $9.7 million as of September 30, 2017 and December 31, 2016, respectively, included within Prepaid and other current assets and Other long-term assets on our condensed consolidated balance sheets.

Roll Forward of Level 3 Financial Instruments Measured at Fair Value on a Recurring Basis

A roll forward of Level 3 financial instruments measured at fair value on a recurring basis is as follows (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Balance, at beginning of period	$	(7,324	)	$	(8,564	)	$	(25,134	)	$	(25,867	)
Settlements	—			—			—			16,810
Total unrealized income (loss) included in earnings	(25,016		)	(6,618		)	(7,206		)	(6,125		)
Balance, at end of period	$	(32,340	)	$	(15,182	)	$	(32,340	)	$	(15,182	)

Carrying Value and Fair Value of Long-term Debt and Other Financial Instruments

The carrying value and fair value of long-term debt and other financial instruments as of September 30, 2017 and December 31, 2016 are as follows (in thousands):

	September 30, 2017
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	83,773	$	83,773
5.00% Convertible Senior Notes due 2021 (3)	94,328		154,116
J. Aron Forward Sale	27,855		27,523
Par Wyoming Holdings Term Loan (2)	66,091		66,091
Wyoming Refining Senior Secured Term Loan (2)	48,652		48,652
Wyoming Refining Senior Secured Revolver (2)	9,502		9,502
Common stock warrants	7,345		7,345

	December 31, 2016
	Carrying Value		Fair Value (1)
Hawaii Retail Credit Agreement (2)	$	93,853	$	93,853
5.00% Convertible Senior Notes due 2021 (3)	91,029		122,229
Term Loan	57,426		62,367
Par Wyoming Holdings Term Loan (2)	65,908		65,908
Wyoming Refining Senior Secured Term Loan (2)	55,480		55,480
Wyoming Refining Senior Secured Revolver (2)	6,700		6,700
Common stock warrants	5,134		5,134

_________________________________________________________

(1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy with the exception of the fair value measurement of the 5.00% Convertible Senior Notes which is considered a Level 2 measurement as discussed below.

(2) Fair value approximates carrying value due to the debt’s floating rate interest which approximates current market value.

(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.

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Stockholders' Equity (Tables)

9 Months Ended

Sep. 30, 2017

Equity [Abstract]

Compensation Costs Recognized

The following table summarizes our compensation costs recognized in General and administrative 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 September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
Restricted Stock Awards	$	967	$	791	$	3,482	$	2,241
Restricted Stock Units	127		62		364		1,167
Stock Option Awards	583		756		1,957		1,695

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Defined Benefit Plan (Tables)

9 Months Ended

Sep. 30, 2017

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Cost (Credit)

The net periodic benefit cost (credit) related to our defined benefit plan includes the following components (in thousands):

	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Components of net periodic benefit cost (credit):
Service cost	$	153		$	334		$	460		$	334
Interest cost	298			299			894			299
Expected return on plan assets	(297		)	(343		)	(892		)	(343		)
Net periodic benefit cost	$	154		$	290		$	462		$	290

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Income (Loss) per Share (Tables)

9 Months Ended

Sep. 30, 2017

Earnings Per Share [Abstract]

Schedule of Computation of Basic and Diluted Income (Loss) Per Share

The following table sets forth the computation of basic and diluted income (loss) per share (in thousands, except per share amounts):

	Three Months Ended September 30,					Nine Months Ended September 30,
	2017		2016			2017		2016
Net income (loss)	$	18,824	$	(27,761	)	$	53,616	$	(59,522	)
Less: Undistributed income allocated to participating securities (1)	238		—			685		—
Net income (loss) attributable to common stockholders	18,586		(27,761		)	52,931		(59,522		)
Plus: Net income effect of convertible securities	2,566		—			—		—
Numerator for diluted income (loss) per common share	$	21,152	$	(27,761	)	$	52,931	$	(59,522	)
Basic weighted-average common stock shares outstanding	45,561		41,580			45,505		41,309
Plus: dilutive effects of common stock equivalents (2)	6,431		—			22		—
Diluted weighted-average common stock shares outstanding	51,992		41,580			45,527		41,309
Basic income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)
Diluted income (loss) per common share	$	0.41	$	(0.67	)	$	1.16	$	(1.44	)

________________________________________________________

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

(2) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per share for the three and nine months ended September 30, 2016.

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Schedule of Segment Summarized Financial Information

Summarized financial information concerning reportable segments consists of the following (in thousands):

Three Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	578,511	$	31,838	$	83,682	$	(83,525	)	$	610,506
Cost of revenues (excluding depreciation)	513,664		15,857		63,175		(83,220		)	509,476
Operating expense (excluding depreciation)	36,126		4,029		11,563		—			51,718
Depreciation, depletion, and amortization	7,390		1,602		1,471		841			11,304
General and administrative expense (excluding depreciation)	—		—		—		11,292			11,292
Operating income (loss)	$	21,331	$	10,350	$	7,473	$	(12,438	)	$	26,716
Interest expense and financing costs, net										(7,419		)
Other income, net										649
Change in value of common stock warrants										(975		)
Equity earnings from Laramie Energy, LLC										553
Income before income taxes										19,524
Income tax expense										(700		)
Net income										$	18,824
Capital expenditures	$	3,171	$	2,606	$	811	$	1,523		$	8,111

Three Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	462,975		$	28,107	$	75,577	$	(56,354	)	$	510,305
Cost of revenues (excluding depreciation)	439,477			19,334		56,365		(55,880		)	459,296
Operating expense (excluding depreciation)	35,910			4,686		10,461		183			51,240
Depreciation, depletion, and amortization	5,755			1,275		1,898		715			9,643
General and administrative expense (excluding depreciation)	—			—		—		9,863			9,863
Acquisition and integration expense	—			—		—		2,047			2,047
Operating income (loss)	$	(18,167	)	$	2,812	$	6,853	$	(13,282	)	$	(21,784	)
Interest expense and financing costs, net											(11,232		)
Other expense, net											(56		)
Change in value of common stock warrants											657
Change in value of contingent consideration											1,025
Equity earnings from Laramie Energy, LLC											3,659
Loss before income taxes											(27,731		)
Income tax expense											(30		)
Net loss											$	(27,761	)
Capital expenditures	$	3,820		$	266	$	1,636	$	1,863		$	7,585

________________________________________________________

(1) Includes eliminations of intersegment revenues and cost of revenues of $83.4 million and $72.1 million for the three months ended September 30, 2017 and 2016, respectively.

Nine Months Ended September 30, 2017	Refining		Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,685,341	$	91,456	$	243,711	$	(240,504	)	$	1,780,004
Cost of revenues (excluding depreciation)	1,493,472		46,982		184,916		(240,252		)	1,485,118
Operating expense (excluding depreciation)	107,237		12,675		33,829		—			153,741
Depreciation, depletion, and amortization	22,243		4,613		4,377		2,615			33,848
General and administrative expense (excluding depreciation)	—		—		—		34,688			34,688
Acquisition and integration expense	—		—		—		253			253
Operating income (loss)	$	62,389	$	27,186	$	20,589	$	(37,808	)	$	72,356
Interest expense and financing costs, net										(25,500		)
Loss on termination of financing agreement										(1,804		)
Other income, net										886
Change in value of common stock warrants										(2,211		)
Equity earnings from Laramie Energy, LLC										11,651
Income before income taxes										55,378
Income tax expense										(1,762		)
Net income										$	53,616
Capital expenditures	$	5,495	$	5,345	$	4,434	$	4,614		$	19,888

Nine Months Ended September 30, 2016	Refining			Logistics		Retail		Corporate, Eliminations and Other (1)			Total
Revenues	$	1,172,164		$	73,686	$	215,952	$	(159,893	)	$	1,301,909
Cost of revenues (excluding depreciation)	1,112,730			48,707		162,831		(157,921		)	1,166,347
Operating expense (excluding depreciation)	85,053			8,906		31,059		307			125,325
Depreciation, depletion, and amortization	9,649			3,116		4,930		2,144			19,839
General and administrative expense (excluding depreciation)	—			—		—		31,654			31,654
Acquisition and integration expense	—			—		—		3,563			3,563
Operating income (loss)	$	(35,268	)	$	12,957	$	17,132	$	(39,640	)	$	(44,819	)
Interest expense and financing costs, net											(21,951		)
Other income, net											60
Change in value of common stock warrants											3,477
Change in value of contingent consideration											10,753
Equity losses from Laramie Energy, LLC											(15,159		)
Loss before income taxes											(67,639		)
Income tax benefit											8,117
Net loss											$	(59,522	)
Capital expenditures	$	10,947		$	1,151	$	3,699	$	3,479		$	19,276

________________________________________________________ 

(1) Includes eliminations of intersegment revenues and cost of revenues of $241.5 million and $198.0 million for the nine months ended September 30,2017 and 2016, respectively.

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Overview (Detail)	9 Months Ended
	Sep. 30, 2017 segment
Schedule of Equity Method Investments [Line Items]
Operating segments	3
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Ownership interest in Laramie Energy, LLC	42.30%

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Summary of Significant Accounting Policies (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Accounting Policies [Abstract]
Cost of revenues	$ 1,568	$ 1,243	$ 4,510	$ 3,081
Operating expense	8,226	6,690	24,700	11,624
General and administrative expense	$ 576	$ 512	$ 1,981	$ 1,451

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Investment in Laramie Energy, LLC - Additional Information (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Cash contributions			$ 0	$ 55,000,000
Depreciation, depletion, and amortization	$ 11,304,000	$ 9,643,000	33,848,000	19,839,000
Unrealized gain (loss) on derivative contracts			$ (557,000)	5,804,000
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Ownership interest in Laramie Energy, LLC	42.30%		42.30%
Cash contributions					$ 55,000,000	$ 27,500,000
Depreciation, depletion, and amortization	$ 12,300,000	13,500,000	$ 38,100,000	34,100,000
Unrealized gain (loss) on derivative contracts	2,300,000	$ 12,700,000	35,200,000	$ (16,800,000)
Amount of equity in underlying assets exceeding carrying value by	63,800,000		$ 63,800,000		$ 67,800,000
Amortization of natural gas and oil properties			15 years
Revolving Credit Facility | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Credit facility, maximum borrowing amount	400,000,000		$ 400,000,000
Asset borrowing base	210,000,000		210,000,000
Balance outstanding on the revolving credit facility	$ 149,000,000		$ 149,000,000

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Investment in Laramie Energy, LLC - Change in Equity Investment (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance			$ 108,823
Equity earnings from Laramie Energy	$ 553	$ 3,659	11,651	$ (15,159)
Ending balance	120,474		120,474
Laramie Energy Company
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance			108,823
Equity earnings from Laramie Energy			7,657
Accretion of basis difference			3,994
Ending balance	$ 120,474		$ 120,474

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Investment in Laramie Energy, LLC - Summarized Financial Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
ASSETS
Current assets	$ 497,512		$ 497,512		$ 403,108
Current liabilities	458,273		458,273		382,765
REVENUE
Income (loss) from operations	26,716	$ (21,784)	72,356	$ (44,819)
Net income (loss)	18,824	(27,761)	53,616	(59,522)
Laramie Energy Company
ASSETS
Current assets	12,149		12,149		12,199
Non-current assets	690,600		690,600		655,022
Current liabilities	43,599		43,599		58,067
Non-current liabilities	213,517		213,517		$ 186,631
REVENUE
Natural gas and oil revenues	38,141	31,091	114,178	68,513
Income (loss) from operations	133	(4,929)	(162)	(28,282)
Net income (loss)	$ (1,838)	$ 5,056	$ 18,102	$ (41,183)

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Acquisitions - Additional Information (Details) - USD ($)		1 Months Ended	3 Months Ended
	Jul. 14, 2016	Jun. 30, 2016	Jun. 30, 2017	Sep. 30, 2017
Wyoming Refining Company
Business Acquisition [Line Items]
Consideration transferred	$ 209,400,000
Adjustment to WRC environmental liability (other non-current liabilities)			$ 2,000,000
Adjustment to inventory			500,000
Adjustments to goodwill			$ 1,500,000
Other Long Term Assets | Wyoming Refining Company
Business Acquisition [Line Items]
Acquisition deposit		$ 5,000,000
Secured Debt | Wyoming Refining Company
Business Acquisition [Line Items]
Aggregate principal amount	65,000,000
Wyoming Refining Senior Secured Term Loan | Secured Debt | Wyoming Refining Company
Business Acquisition [Line Items]
Long-term debt	58,036,000
Wyoming Refining Senior Secured Revolver | Revolving Credit Facility | Wyoming Refining Company
Business Acquisition [Line Items]
Long-term debt	$ 10,100,000
Convertible Subordinated Bridge Notes
Business Acquisition [Line Items]
Debt instrument, interest rate	2.50%
5.00% Convertible Senior Notes due 2021
Business Acquisition [Line Items]
Debt instrument, interest rate	5.00%			5.00%
5.00% Convertible Senior Notes due 2021 | Convertible Debt
Business Acquisition [Line Items]
Debt instrument, interest rate				5.00%
Aggregate principal amount	$ 115,000,000

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Acquisitions - Fair Value of Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Jul. 14, 2016
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Goodwill	$ 107,187	$ 105,732
Wyoming Refining Company
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Cash			$ 183
Accounts receivable			16,880
Inventories			28,402
Prepaid and other assets			1,304
Property, plant, and equipment			254,367
Goodwill			66,449
Accounts payable and other current liabilities			(57,861)
Other non-current liabilities			(32,222)
Total			209,366
Wyoming Refining Company | Refining
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Goodwill			39,800
Wyoming Refining Company | Logistics
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Goodwill			26,600
Wyoming Refining Company | Revolving Credit Facility | Wyoming Refining Senior Secured Revolver
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Long-term debt			(10,100)
Wyoming Refining Company | Secured Debt | Wyoming Refining Senior Secured Term Loan
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment [Abstract]
Long-term debt			$ (58,036)

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Acquisitions - Pro Forma Financial Information (Details) - Wyoming Refining Company - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016
Business Acquisition [Line Items]
Revenues	$ 522,163	$ 1,463,101
Net loss	$ (26,384)	$ (64,926)
Loss per share
Basic (in dollars per shares)	$ (0.58)	$ (1.43)
Diluted (in dollars per shares)	$ (0.58)	$ (1.43)

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Inventories (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Inventory [Line Items]
Crude oil and feedstocks	$ 135,579	$ 61,302
Refined products and blendstock	162,956	116,593
Warehouse stock and other	21,329	20,431
Total	319,864	198,326
Reserves for the lower of cost or market value of inventory	0	200
Titled Inventory
Inventory [Line Items]
Crude oil and feedstocks	64,208	11,620
Refined products and blendstock	52,734	38,916
Warehouse stock and other	21,329	20,431
Total	138,271	70,967
Supply and Offtake Agreements
Inventory [Line Items]
Crude oil and feedstocks	71,371	49,682
Refined products and blendstock	110,222	77,677
Warehouse stock and other	0	0
Total	$ 181,593	$ 127,359

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Prepaid and Other Current Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Advances to suppliers for crude oil purchases	$ 0	$ 38,300
Collateral posted with broker for derivative instruments	708	2,714
Prepaid insurance	0	7,504
Derivative assets	2,413	161
Other	5,818	4,701
Total	$ 8,939	$ 53,380

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Inventory Financing Agreements (Details) barrel / d in Thousands			3 Months Ended		9 Months Ended
	May 08, 2017 USD ($)	Jun. 01, 2015 USD ($) barrel / d	Sep. 30, 2017 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($)	Sep. 30, 2016 USD ($)	Jul. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Feb. 29, 2016 USD ($) installment	Sep. 30, 2015 USD ($) payment
Supply Commitment [Line Items]
Supply and exchange agreement expenses			$ 7,419,000	$ 11,232,000	$ 25,500,000	$ 21,951,000
Supply and Offtake Agreements
Supply Commitment [Line Items]
Agreement extension term	1 year
Forward sale liability	$ 30,000,000
Barrels of crude per day provided (up to) | barrel / d		94
Handling fees			3,400,000	1,700,000	9,800,000	5,600,000
Supply and exchange agreement expenses			800,000	$ 900,000	2,300,000	$ 2,200,000
Amount of deferred payment arrangement		$ 125,000,000
Percentage of receivables and inventory for deferred payment arrangement		85.00%
Deferral arrangement fee		$ 1,300,000
Variable interest rate basis		P3M
Capacity of deferred payment arrangement			75,500,000		75,500,000			$ 59,400,000
Outstanding amount of deferred payment arrangement			41,800,000		41,800,000			43,300,000
Fee agreement receivable			$ (10,300,000)		$ (10,300,000)		$ (3,000,000)	$ (14,600,000)	$ (14,600,000)	$ (18,000,000)
Number of fee agreement payments									18	14
Supply and Offtake Agreements | London Interbank Offered Rate (LIBOR)
Supply Commitment [Line Items]
Margin on LIBOR rate		3.75%
Deferred payment availability fee		0.75%

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Debt - Schedule of Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Jul. 14, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 353,457	$ 400,420
Less: unamortized discount and deferred financing costs	(23,256)	(30,024)
Total debt, net of unamortized discount and deferred financing costs	330,201	370,396
Less: current maturities	(27,140)	(20,286)
Long-term debt, net of current maturities	303,061	350,110
Hawaii Retail Credit Facilities
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 85,023	95,319
5.00% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%		5.00%
Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 0	60,361
J. Aron Forward Sale
Debt Instrument [Line Items]
Principal amount of long-term debt	27,855	0
Par Wyoming Holdings Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	67,325	67,325
Wyoming Refining Senior Secured Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	48,752	55,715
Wyoming Refining Senior Secured Revolver
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 9,502	6,700
Convertible Debt | 5.00% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%
Principal amount of long-term debt	$ 115,000	$ 115,000
Less: unamortized discount and deferred financing costs	$ (20,700)

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Debt - J. Aron Forward Sale (Details) - USD ($) $ in Thousands		8 Months Ended	9 Months Ended
	May 08, 2017	Dec. 31, 2017	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt			$ 353,457		$ 400,420
Principal payments - 2017			292,684	$ 137,791
Supply and Offtake Agreements
Debt Instrument [Line Items]
Agreement extension term	1 year
Forward sale liability	$ 30,000
Debt instrument, interest rate	7.00%
J. Aron Forward Sale
Debt Instrument [Line Items]
Principal amount of long-term debt			$ 27,855		$ 0
Principal payments - 2018	$ 7,000
Principal payments - 2019	7,500
Principal payments - 2020	8,100
Principal payments - 2021	$ 3,500
Scenario, Forecast | J. Aron Forward Sale
Debt Instrument [Line Items]
Principal payments - 2017		$ 3,900

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Debt - Wyoming Refining Credit Facilities (Details)	Apr. 30, 2015 USD ($)
Term Loan | Wyoming Refining Senior Secured Term Loan
Debt Instrument [Line Items]
Periodic payment, principal	$ 2,300,000
Revolving Credit Facility | Wyoming Refining Senior Secured Revolver
Debt Instrument [Line Items]
Maximum borrowing amount	$ 30,000,000

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Debt - Convertible Senior Note (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Jul. 14, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 353,457	$ 400,420
Unamortized discount and deferred financing costs	$ 23,256	30,024
5.00% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Interest rate	5.00%		5.00%
5.00% Convertible Senior Notes due 2021 | Carrying Value
Debt Instrument [Line Items]
Long-term debt, fair value	$ 94,328	91,029
Convertible Debt | 5.00% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Interest rate	5.00%
Principal amount of long-term debt	$ 115,000	$ 115,000
Unamortized discount and deferred financing costs	$ 20,700

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Debt - Term Loan (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Debt Instrument [Line Items]
Write off of financing costs	$ 0	$ 0	$ 1,804	$ 0
Delayed Draw Term Loan and Bridge Loan Agreement
Debt Instrument [Line Items]
Write off of financing costs			$ 1,800

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Debt - Hawaii Retail Credit Facilities (Details)	Jun. 28, 2017 USD ($)
Hawaii Retail Credit Facilities | Revolving Credit Facility | Subsidiaries
Line of Credit Facility [Line Items]
Maximum allowed dividend (no more than)	$ 15,000,000

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Debt - Guarantors (Details)	Sep. 16, 2016 USD ($)
Debt Disclosure [Abstract]
Debt instruments, initial offering price	$ 750,000,000

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Derivatives - Narrative (Details) bbl in Thousands	9 Months Ended
	Sep. 30, 2017 USD ($) bbl	Jul. 14, 2016
5.00% Convertible Senior Notes due 2021
Credit Derivatives [Line Items]
Debt instrument, interest rate	5.00%	5.00%
5.00% Convertible Senior Notes due 2021 | Convertible Debt
Credit Derivatives [Line Items]
Debt instrument, interest rate	5.00%
Options Collar | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	52
Option Collars and Swap | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	75
Interest Rate Swap
Credit Derivatives [Line Items]
Fixed interest rate	1.10%
Notional amount | $	$ 200,000,000
Long | Commodity derivatives | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	305
Long | Energy Related Derivative | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	115

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Derivatives - Fair Value Amounts of Derivatives and Placement in Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	$ 700	$ 2,700
Other long-term assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	7,000	7,000
Commodity derivatives | Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	1,561	0
Commodity derivatives | Other long-term assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	571	2,748
Commodity derivatives | Other accrued liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(58)	(595)
J. Aron repurchase obligation derivative | Over the Counter
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(24,995)	(20,000)
Interest rate derivatives | Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	851	161
Interest rate derivatives | Other long-term assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	2,115	3,377
Interest rate derivatives | Other accrued liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	$ 0	$ (94)

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Derivatives - Schedule of Pre-Tax Gain (Loss) Recognized in the Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Commodity derivatives | Cost of revenues (excluding depreciation)
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses)	$ 3,657	$ (3,028)	$ 26	$ (3,117)
J. Aron repurchase obligation derivative | Cost of revenues (excluding depreciation)
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses)	(24,041)	(8,300)	(4,995)	(20,356)
Interest rate derivatives | Interest expense and financing costs, net
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax gains (losses)	$ 148	$ 1,204	$ (477)	$ (1,098)

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Fair Value Measurements - Common Stock Warrants (Details) - $ / shares	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Weighted average exercise price (in usd per share)	$ 0.09	$ 0.10
Term (years)	4 years 11 months	5 years 8 months
Fair value of common stock warrants (in usd per share)	$ 20.73	$ 14.49
Warrant
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Common stock warrants outstanding (in shares)	354,350	354,350

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Fair Value Measurements - Fair Value Amounts by Hierarchy Level (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Liabilities
Gross Fair Value and Nat Carrying Value on Balance Sheet	$ (7,345)	$ (5,134)
Fair Value, Measurements, Recurring
Assets
Gross Fair Value	31,934	29,887
Effect of Counter-Party Netting	(26,836)	(23,601)
Net Carrying Value on Balance Sheet	5,098	6,286
Liabilities
Gross Fair Value	(59,234)	(49,424)
Effect of Counter-Party Netting	26,836	23,601
Net Carrying Value on Balance Sheet	(32,398)	(25,823)
Cash collateral	7,700	9,700
Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	2,966	3,602
Effect of Counter-Party Netting	0	(64)
Net Carrying Value on Balance Sheet	2,966	3,538
Liabilities
Gross Fair Value		(158)
Effect of Counter-Party Netting		64
Net Carrying Value on Balance Sheet		(94)
Level 1 | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	235	190
Liabilities
Gross Fair Value	(150)	(54)
Level 1 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	0	0
Liabilities
Gross Fair Value		0
Level 2 | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	31,699	29,697
Liabilities
Gross Fair Value	(26,744)	(24,236)
Level 2 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	2,966	3,602
Liabilities
Gross Fair Value		(158)
Level 3 | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	0	0
Liabilities
Gross Fair Value	(32,340)	(25,134)
Level 3 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	0	0
Liabilities
Gross Fair Value		0
Over the Counter | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value and Nat Carrying Value on Balance Sheet	(7,345)	(5,134)
Effect of Counter-Party Netting	0	0
Over the Counter | Level 1 | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value and Nat Carrying Value on Balance Sheet	0	0
Over the Counter | Level 2 | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value and Nat Carrying Value on Balance Sheet	0	0
Over the Counter | Level 3 | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value and Nat Carrying Value on Balance Sheet	(7,345)	(5,134)
Exchange Traded | Future | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	28,968	26,285
Effect of Counter-Party Netting	(26,836)	(23,537)
Net Carrying Value on Balance Sheet	2,132	2,748
Liabilities
Gross Fair Value	(26,894)	(24,132)
Effect of Counter-Party Netting	26,836	23,537
Net Carrying Value on Balance Sheet	(58)	(595)
Exchange Traded | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value	(24,995)	(20,000)
Effect of Counter-Party Netting	0	0
Net Carrying Value on Balance Sheet	(24,995)	(20,000)
Exchange Traded | Level 1 | Future | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	235	190
Liabilities
Gross Fair Value	(150)	(54)
Exchange Traded | Level 1 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value	0	0
Exchange Traded | Level 2 | Future | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	28,733	26,095
Liabilities
Gross Fair Value	(26,744)	(24,078)
Exchange Traded | Level 2 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value	0	0
Exchange Traded | Level 3 | Future | Fair Value, Measurements, Recurring
Assets
Gross Fair Value	0	0
Liabilities
Gross Fair Value	0	0
Exchange Traded | Level 3 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Gross Fair Value	$ (24,995)	$ (20,000)

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Fair Value Measurements - Roll Forward of Level 3 Financial Instruments Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, at beginning of period	$ (7,324)	$ (8,564)	$ (25,134)	$ (25,867)
Settlements	0	0	0	16,810
Total unrealized income (loss) included in earnings	(25,016)	(6,618)	(7,206)	(6,125)
Balance, at end of period	$ (32,340)	$ (15,182)	$ (32,340)	$ (15,182)

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Fair Value Measurements - Carrying Value and Fair Value of Long-Term Debt and Other Financial Instruments (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Jul. 14, 2016
5.00% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate	5.00%		5.00%
J. Aron Forward Sale
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current yield used for long-term debt fair value estimate	8.00%
Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current yield used for long-term debt fair value estimate		11.06%
Carrying Value | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	$ 7,345	$ 5,134
Carrying Value | Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt		57,426
Carrying Value | Wyoming Refining Senior Secured Revolver
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	9,502	6,700
Carrying Value | Hawaii Retail Credit Facilities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	83,773	93,853
Carrying Value | 5.00% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	94,328	91,029
Carrying Value | J. Aron Forward Sale
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	27,855
Carrying Value | Par Wyoming Holdings Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	66,091	65,908
Carrying Value | Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	48,652	55,480
Fair Value | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	7,345	5,134
Fair Value | Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt		62,367
Fair Value | Wyoming Refining Senior Secured Revolver
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	9,502	6,700
Fair Value | Hawaii Retail Credit Facilities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	83,773	93,853
Fair Value | 5.00% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	154,116	122,229
Fair Value | J. Aron Forward Sale
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	27,523
Fair Value | Par Wyoming Holdings Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	66,091	65,908
Fair Value | Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 48,652	$ 55,480

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Commitments and Contingencies (Details)		9 Months Ended	12 Months Ended		14 Months Ended
	Mar. 23, 2015	Sep. 30, 2017 USD ($) claim	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Sep. 30, 2017 USD ($) claim	Jun. 17, 2013 USD ($)
Long-term Purchase Commitment [Line Items]
Loss contingency, damages sought		$ 4,500,000
Multiplier for earnout payment before EBITDA		4			4
Minimum EBITDA benchmark		$ 3,500,000.0			$ 3,500,000.0
Maximum earnout payment amount		$ 4,500,000.0			4,500,000.0
Site contingency, recovery from third party of environmental remediation cost					11,800,000
Environmental costs recognized, capitalized in period					$ 12,500,000
Number of remaining claim to be resolved | claim		2			2
Bankruptcy claims amount of claims to be settled		$ 22,400,000			$ 22,400,000
Estimated value of claims remaining to be settled		500,000			500,000
Maximum bankruptcy claims remaining		$ 22,400,000			$ 22,400,000
Predecessor working ownership percentage		3.40%			3.40%
Allowed claims, settlement ratio		0.0544
Indemnification Agreement | Tesoros
Long-term Purchase Commitment [Line Items]
Deductible for indemnification obligation		$ 1,000,000			$ 1,000,000
Indemnification obligation cap		15,000,000			15,000,000
Clear Air Act Violation
Long-term Purchase Commitment [Line Items]
Final decree high estimate		30,000,000
Pending Litigation
Long-term Purchase Commitment [Line Items]
Claim amount for environmental losses (more than)		1,000,000			1,000,000
Wyoming Refinery One
Long-term Purchase Commitment [Line Items]
Environmental remediation expense		$ 20,000,000			20,000,000
Environmental costs recognized, period for recognition of one third costs		5 years
Environmental costs recognized, remainder, period for recognition		30 years
Wyoming Refinery Two | Wastewater Treatment Pond
Long-term Purchase Commitment [Line Items]
Environmental remediation expense		$ 500,000			500,000
Wyoming Refinery Two | Waste Water Treatment System
Long-term Purchase Commitment [Line Items]
Environmental remediation expense		11,600,000			11,600,000
Wyoming Refinery
Long-term Purchase Commitment [Line Items]
Loss contingency, range of possible loss		$ 100,000			$ 100,000
United Steelworkers Union
Long-term Purchase Commitment [Line Items]
Collective bargaining arrangement, extension term	4 years
Tesoro
Long-term Purchase Commitment [Line Items]
Contingent consideration (up to)						$ 20,000,000
Loss contingency, damages paid			$ 16,800,000.0
Loss contingency, damages sought			$ 8,300,000	$ 4,300,000

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Stockholders' Equity - Compensation Costs Recognized (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Restricted Stock Awards
Class of Stock [Line Items]
Compensation cost	$ 967	$ 791	$ 3,482	$ 2,241
Restricted Stock Units
Class of Stock [Line Items]
Compensation cost	127	62	364	1,167
Stock Option Awards
Class of Stock [Line Items]
Compensation cost	$ 583	$ 756	$ 1,957	$ 1,695

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Stockholders' Equity - Additional Information (Details) $ / shares in Units, $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2017 USD ($) shares	Sep. 30, 2017 USD ($) $ / shares shares
Restricted Stock Awards
Class of Stock [Line Items]
Restricted stock and restricted stock units granted (in shares) | shares	20,000	273,000
Grants in the period, aggregate fair value	$ 0.4	$ 4.0
Unrecognized compensation costs related to restricted stock awards	$ 6.5	$ 6.5
Weighted average period of recognition		2 years 6 months 29 days
Stock Option Awards
Class of Stock [Line Items]
Weighted average period of recognition		2 years 8 months 1 day
Options, granted (in shares) | shares	0	239,000
Weighted average exercise price (in dollars per share) | $ / shares		$ 15.03
Unrecognized compensation costs related to options	$ 4.0	$ 4.0
Performance Restricted Stock Units
Class of Stock [Line Items]
Restricted stock and restricted stock units granted (in shares) | shares	0	45,000
Grants in the period, aggregate fair value		$ 0.7
Unrecognized compensation costs related to restricted stock awards	$ 0.5	$ 0.5
Weighted average period of recognition		2 years 4 months 27 days

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Defined Benefit Plan - Additional Information (Details)	9 Months Ended
	Sep. 30, 2017
Compensation and Retirement Disclosure [Abstract]
Consecutive years of service	5 years
Years of employment	10 years

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Defined Benefit Plan - Net Periodic Benefit Cost (Credit) (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Amount to be amortized from accumulated other comprehensive income			$ 0		$ 0
Components of net periodic benefit cost (credit):
Service cost	$ 153,000	$ 334,000	460,000	$ 334,000
Interest cost	298,000	299,000	894,000	299,000
Expected return on plan assets	(297,000)	(343,000)	(892,000)	(343,000)
Net periodic benefit cost	$ 154,000	$ 290,000	$ 462,000	$ 290,000

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Income (Loss) per Share - Basic and Diluted Loss Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Jul. 14, 2016
Earnings Per Share Reconciliation [Abstract]
Net income (loss)	$ 18,824	$ (27,761)	$ 53,616	$ (59,522)
Undistributed income allocated to participating securities	238	0	685	0
Net income (loss) attributable to common stockholders	18,586	(27,761)	52,931	(59,522)
Plus: Net income effect of convertible securities	2,566	0	0	0
Numerator for diluted income (loss) per common share	$ 21,152	$ (27,761)	$ 52,931	$ (59,522)
Basic weighted-average common stock shares outstanding (in shares)	45,561	41,580	45,505	41,309
Dilutive effects of common stock equivalents (in shares)	6,431	0	22	0
Diluted weighted-average common stock shares outstanding (in shares)	51,992	41,580	45,527	41,309
Basic income (loss) per share (USD per share)	$ 0.41	$ (0.67)	$ 1.16	$ (1.44)
Diluted income (loss) per share (USD per share)	$ 0.41	$ (0.67)	$ 1.16	$ (1.44)
5.00% Convertible Senior Notes due 2021
Earnings Per Share Reconciliation [Abstract]
Debt instrument, interest rate	5.00%		5.00%		5.00%
Warrant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average number of shares issuable under the common stock warrants (in shares)	354	352	354	352
Restricted Stock Awards
Earnings Per Share Reconciliation [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	31	463	83	448
Stock Option Awards
Earnings Per Share Reconciliation [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	1,300	1,700	1,500	1,700
Convertible Debt Securities
Earnings Per Share Reconciliation [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)		6,400	6,400	2,300

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Income Taxes (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Adjustments recognized for uncertain tax positions	$ 0	$ 0	$ 0	$ 0

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Segment Information (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($) segment	Sep. 30, 2016 USD ($)
Segment Reporting [Abstract]
Reporting segments | segment			4
Segment Reporting Information [Line Items]
Revenues	$ 610,506	$ 510,305	$ 1,780,004	$ 1,301,909
Cost of revenues (excluding depreciation)	509,476	459,296	1,485,118	1,166,347
Operating expense (excluding depreciation)	51,718	51,240	153,741	125,325
Depreciation, depletion, and amortization	11,304	9,643	33,848	19,839
General and administrative expense (excluding depreciation)	11,292	9,863	34,688	31,654
Acquisition and integration expense	0	2,047	253	3,563
Operating income (loss)	26,716	(21,784)	72,356	(44,819)
Interest expense and financing costs, net	(7,419)	(11,232)	(25,500)	(21,951)
Loss on termination of financing agreement	0	0	(1,804)	0
Other income (expense), net	649	(56)	886	60
Change in value of common stock warrants	(975)	657	(2,211)	3,477
Change in value of contingent consideration	0	1,025	0	10,753
Equity earnings (losses) from Laramie Energy, LLC	553	3,659	11,651	(15,159)
Income (loss) before income taxes	19,524	(27,731)	55,378	(67,639)
Income tax benefit (expense)	(700)	(30)	(1,762)	8,117
Net income (loss)	18,824	(27,761)	53,616	(59,522)
Capital expenditures	8,111	7,585	19,888	19,276
Operating Segments | Refining
Segment Reporting Information [Line Items]
Revenues	578,511	462,975	1,685,341	1,172,164
Cost of revenues (excluding depreciation)	513,664	439,477	1,493,472	1,112,730
Operating expense (excluding depreciation)	36,126	35,910	107,237	85,053
Depreciation, depletion, and amortization	7,390	5,755	22,243	9,649
General and administrative expense (excluding depreciation)	0	0	0	0
Acquisition and integration expense		0	0	0
Operating income (loss)	21,331	(18,167)	62,389	(35,268)
Capital expenditures	3,171	3,820	5,495	10,947
Operating Segments | Logistics
Segment Reporting Information [Line Items]
Revenues	31,838	28,107	91,456	73,686
Cost of revenues (excluding depreciation)	15,857	19,334	46,982	48,707
Operating expense (excluding depreciation)	4,029	4,686	12,675	8,906
Depreciation, depletion, and amortization	1,602	1,275	4,613	3,116
General and administrative expense (excluding depreciation)	0	0	0	0
Acquisition and integration expense		0	0	0
Operating income (loss)	10,350	2,812	27,186	12,957
Capital expenditures	2,606	266	5,345	1,151
Operating Segments | Retail
Segment Reporting Information [Line Items]
Revenues	83,682	75,577	243,711	215,952
Cost of revenues (excluding depreciation)	63,175	56,365	184,916	162,831
Operating expense (excluding depreciation)	11,563	10,461	33,829	31,059
Depreciation, depletion, and amortization	1,471	1,898	4,377	4,930
General and administrative expense (excluding depreciation)	0	0	0	0
Acquisition and integration expense		0	0	0
Operating income (loss)	7,473	6,853	20,589	17,132
Capital expenditures	811	1,636	4,434	3,699
Corporate, Eliminations and Other
Segment Reporting Information [Line Items]
Revenues	(83,525)	(56,354)	(240,504)	(159,893)
Cost of revenues (excluding depreciation)	(83,220)	(55,880)	(240,252)	(157,921)
Operating expense (excluding depreciation)	0	183	0	307
Depreciation, depletion, and amortization	841	715	2,615	2,144
General and administrative expense (excluding depreciation)	11,292	9,863	34,688	31,654
Acquisition and integration expense		2,047	253	3,563
Operating income (loss)	(12,438)	(13,282)	(37,808)	(39,640)
Capital expenditures	1,523	1,863	4,614	3,479
Gross profit	$ 83,400	$ 72,100	$ 241,500	$ 198,000

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Related Party Transactions (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2017 USD ($)
Related Party Transaction [Line Items]
Travel and out of pocket expenses	$ 50
Investor
Related Party Transaction [Line Items]
Initial term of service agreements	1 year
Renewal term for service agreements	1 year
Termination period between extension date	60 days
EGI
Related Party Transaction [Line Items]
Percentage ownership of Par common stock (or more)	10.00%
Whitebox
Related Party Transaction [Line Items]
Percentage ownership of Par common stock (or more)	10.00%