10-K/A

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-K/A

Amendment No. 2

(Mark One)

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

For the fiscal year ended December 31, 2013

OR

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

Commission File No. 0-16203

PAR PETROLEUM CORPORATION

(Exact name of registrant as specified in its charter)

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

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

Registrant’s telephone number, including area code: (281) 899-4800

Securities registered under Section 12(b) of the Act: None

Securities registered under to Section 12(g) of the Act: Common stock, par value $0.01 per share

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  ¨    No  x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.    Yes  ¨    No  x

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  x    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  x    No  ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ¨

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

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

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

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  x    No  ¨

The aggregate market value of voting common equity held by non-affiliates of the registrant was approximately $55,000,000 based on the closing price of the common stock on the OTCQB Marketplace of $16.30 per share as of June 28, 2013. As of March 26, 2014, 30,159,039 shares of registrant’s Common Stock, $0.01 par value, were issued and outstanding.

Documents Incorporated By Reference

None.

PAR PETROLEUM CORPORATION FORM 10-K/A

EXPLANATORY NOTE

Par Petroleum Corporation (the “Company,” “we,” “our,” and “us”) is filing this Amendment No. 2 on Form 10-K/A (this “Amendment No. 2”) to amend its Annual Report on Form 10-K for the fiscal year ended December 31, 2013, as originally filed with the U.S. Securities and Exchange Commission (the “SEC”) on March 31, 2014, and amended by Amendment No. 1 on Form 10-K/A filed with the SEC on April 29, 2014 (collectively, the “Original Form 10-K”), to correct an $8.6 million understatement of its cost of revenues and net loss ($0.44 per common share) for the year ended December 31, 2013 due to miscalculating its crude inventory volumes on hand as of December 31, 2013. See the Introductory Note to the accompanying consolidated financial statements beginning on page F-9 for additional information.

As a result of the miscalculation and resulting understatement, the Company’s management reassessed its evaluation of the effectiveness of its internal control over financial reporting as of December 31, 2013. As a result of that assessment, management identified additional control deficiencies that constituted an additional material weakness and, accordingly, has concluded that the Company did not maintain effective internal control over financial reporting as of December 31, 2013. For a description of the material weaknesses identified by management and management’s plan to remediate the material weaknesses, see “Item 9A - Controls and Procedures.”

In accordance with Rule 12b-15 under the Securities and Exchange Act of 1934, as amended, the following items of the Original Form 10-K are hereby amended and restated in their entirety:

Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations
Item 8.	Financial Statements and Supplementary Data
Item 9A.	Controls and Procedures
Item 15.	Exhibits, Financial Statement Schedules

This Amendment No. 2 does not amend or otherwise update any other information in the Original Form 10-K. Accordingly, this Amendment No. 2 should be read in conjunction with the Original Form 10-K and with our subsequent filings with the SEC. All capitalized terms used but not defined herein shall have the meanings ascribed to them in the Original Form 10-K. The Company’s Chief Executive Officer and Chief Financial Officer are providing currently dated certifications in connection with this Amendment No. 2; the certifications are filed as Exhibits 31.1, 31.2, 32.1 and 32.2.

TABLE OF CONTENTS

	PAGE
PART II
Item 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		2
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA		21
Item 9A. CONTROLS AND PROCEDURES		21
PART IV
Item 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES		22

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Item 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

As disclosed in the Explanatory Note to this Amendment No. 2 and in the Introductory Note to our consolidated financial statements, we have restated our consolidated financial statements for the year ended December 31, 2013 for a miscalculation of our crude inventory volumes on hand as of December 31, 2013. We determine our inventory and our obligations under supply and exchange agreements based on physical inventory observations each reporting period. During May 2014, we determined that we did not appropriately consider an adjustment to the measurements taken during the physical inventory observation that occurred on December 31, 2013. Management’s discussion and analysis of financial condition and results of operations have been revised to reflect the effects of the restatement.

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Overview

We emerged from the bankruptcy of Delta Petroleum in August 2012. The reorganization converted approximately $265 million of unsecured debt to equity and allowed us to preserve significant tax attributes. As required by U.S. generally accepted accounting principles we adopted fresh-start reporting as of the Emergence Date, resulting in us becoming a new entity for financial reporting purposes. See “- Reorganization under Chapter 11” and “- Fresh-Start Reporting and the Effects of the Plan”.

We currently operate in three segments:

• refining, distribution and marketing;

• natural gas and oil operations; and

• commodity marketing and logistics

Our refining, distribution and marketing segment owns and operates a refinery rated at 94,000 barrels per day of throughput capacity in Kapolei, Hawaii, 2.4 million barrels of crude oil and feedstock storage and 2.5 million barrels of refined product storage. The refinery produces ultra-low sulfur diesel, gasoline, jet fuel, marine fuel and other associated refined products primarily for consumption in Hawaii. Our refinery logistics assets include five refined products terminals, 27 miles of pipelines, a single point mooring and other associated logistics assets. In addition, we distribute our products through 31 retail outlets located across the islands of Oahu, Maui and Hawaii. Results of operations in our refinery segment depend on favorable “crack spreads”, or the difference between the price we pay for crude oil, sourced internationally, and the prices we receive for our refined products, which are primarily determined by the local Hawaii market.

Our natural gas and oil assets are non-operated and are concentrated in our 33.34% ownership of Piceance Energy, a joint venture entity operated by Laramie and focused on producing natural gas in Garfield and Mesa Counties, Colorado. The estimated value of Piceance Energy’s estimated proved reserves was $89.3 million at December 31, 2013. In addition, we own non-operating interests in Colorado and offshore California, and an overriding royalty interest in New Mexico. We estimate the value of estimated proved reserves for these additional properties to be approximately $3.5 million at December 31, 2013. Our interests are heavily weighted towards natural gas and natural gas liquids.

Our commodity marketing and logistics segment focuses on sourcing, transporting, marketing and distributing crude oil from Canada and the Western U.S. to refining hubs in the Midwest, Gulf Coast and East Coast regions of the U.S. Our logistics capabilities consist of historical pipeline shipping status (giving us assured pipeline access) a leased rail car fleet and experience in contracted chartering of tugs and barges. We contract to provide logistics services for others and trade for our own account. Our success primarily depends on favorable spreads between the discounted crudes available from the Western U.S. and Canada and the prices we receive from our customers.

Due to significant acquisitions in December 2012 and September 2013 and our emergence from bankruptcy in August 2012, our consolidated results of operations for any period after December 31, 2013 will not be comparable to any prior period. We will continue to recognize our proportional share of the earnings or losses of Piceance Energy, which will be driven by drilling results and market prices. We will also continue to reflect results of operations of our commodity marketing and logistics segment, which will be dependent primarily on marketing and transportation revenues and will be driven by price differentials along the crude oil supply chain. However, we anticipate our future results of operations, capital and liquidity positions and the overall success of our business will depend, in large part, on the results of our refinery segment. Crack spreads will be the primary driver of the refinery’s results of operations and therefore, of our own profitability.

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2013 Results

Results of operations for the periods discussed in “- Results of Operations” are presented in the table below (in thousands):

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1, 2012 through August 31, 2012
Refining, distribution and marketing revenues	$	778,126		$	—		$	—
Commodity marketing and logistics		100,149			—			—
Oil and gas sales		7,739			2,144			23,079
Total revenues		886,014			2,144			23,079
Cost of revenues		857,476			—			—
Operating expense, excluding depreciation, depletion, and amortization expense shown separately below		27,251			—			—
Lease operating expense		5,627			1,684			9,038
Transportation expense		—			—			6,963
Production taxes		49			4			979
Exploration expense		—			—			2
Dry hole costs and impairments		—			—			151,347
Depreciation, depletion, amortization and accretion		5,982			401			16,041
Trust litigation and settlements		6,206			—			—
General and administrative expense		21,494			4,520			9,386
Acquisition and integration costs		9,794			556			—
Total operating expenses		933,879			7,165			193,756
Operating loss		(47,865	)		(5,021	)		(170,677	)
Loss from unconsolidated affiliates		(2,941	)		(1,325	)		(20	)
Interest expense and financing costs, net		(19,471	)		(1,056	)		(6,852	)
Other income		808			86			516
Change in value of common stock warrants		(10,114	)		(4,280	)		—
Gain on derivative instruments, net		410			—			—
Income tax benefit		—			2,757			—
Loss from continuing operations		(79,173	)		(8,839	)		(177,033	)
Reorganization items:
Professional fees and administrative costs		—			—			22,354
Changes in asset fair values due to fresh start accounting adjustments		—			—			14,765
Gain on settlement of senior debt		—			—			(166,144	)
Gain on settlement of liabilities		—			—			(2,571	)
Net loss	$	(79,173	)	$	(8,839	)	$	(45,437	)

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Contributors to 2013 Results

Results of operations for the quarter and year ended December 31, 2013 reflect the acquisition, integration and operation of HIE which we acquired on September 25, 2013. Our gross margin was impacted by our out of cycle feedstock purchases during the refinery start up, exacerbated by tensions in Libya and Syria. The majority of the feedstocks consumed during the fourth quarter were procured during the refinery start up in order to restock the supply chain before the closing of the acquisition. Market crack spreads (or the margin between the price paid for crude oil and the price received for refined products) declined in the fourth quarter of 2013 compared to the fourth quarter of 2012 and the third quarter of 2013. We believe our refinery’s economics reflect components of both Singapore and West Coast refineries. Average crack spreads for the Singapore and San Francisco markets declined $1.07 and $4.17 per barrel, respectively, for the fourth quarter of 2013 from the fourth quarter of 2012, in each case using a Brent 4:1:2:1 index (or one part gasoline, two parts distillate and one part fuel oil). In addition, since the acquisition, we have relied heavily on third party service providers as well as a transition services agreement with the former owner as we build internal infrastructure, contributing to elevated general and administrative expenses.

We believe that our efforts to rationalize the sourcing of our crude oil should improve our margins and that reducing our dependence on third party service providers as well as the transition services agreement should lower relative general and administrative expenses.

Reorganization under Chapter 11

In December 2011 and January 2012, Delta and its subsidiaries filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware. Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In March 2012, the Debtors obtained approval from the bankruptcy court to proceed with Laramie Energy II, LLC (“Laramie”) as the sponsor of a plan of reorganization (the “Plan”). In June 2012, Delta entered into a contribution agreement (the “Contribution Agreement”) with a new joint venture formed by Delta, Laramie and Piceance Energy LLC (“Piceance Energy”) to effect the transactions contemplated by Plan.

On August 31, 2012 (the “Emergence Date”), Delta consummated the transactions contemplated by the Contribution Agreement and each of Delta and Laramie contributed to Piceance Energy their respective natural gas and oil assets in the Piceance Basin. Piceance Energy is owned 66.66% by Laramie and 33.34% by Delta.

At the closing, Piceance Energy entered into a new credit agreement, borrowed $100 million under that agreement, and distributed approximately $72.6 million net of settlements to the company and approximately $24.9 million to Laramie. The company used its distribution to pay bankruptcy expenses and to repay secured debt. The company also entered into a new credit facility and borrowed $13 million under that facility at closing, and used those funds primarily to pay bankruptcy claims and expenses.

Following the reorganization, the company retained its interest in the Point Arguello Unit offshore California and other miscellaneous assets and certain tax attributes, including significant net operating loss carryforwards. Based upon the Plan as confirmed by the bankruptcy court, Delta’s creditors were issued approximately 14.8 million shares of common stock, and Delta’s former stockholders received no consideration under the Plan.

On the Emergence Date, Delta also amended and restated its certificate of incorporation and bylaws and changed its name to “Par Petroleum Corporation.” The amended and restated certificate of incorporation contains restrictions that render void certain transfers of our stock that involve a holder of five percent or more of our shares. The purpose of this provision is to preserve certain of our tax attributes that we believe may have value.

Fresh-Start Reporting and the Effects of the Plan

As required by U.S. GAAP, effective as of August 31, 2012, Par adopted fresh-start reporting because (i) holders of voting shares immediately before confirmation of the Plan received less than 50% of the emerging entity and (ii) the reorganization value of

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our assets immediately before confirmation of the Plan was less than our post-petition liabilities and allowed claims. Fresh-start reporting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities. Fresh-start reporting results in us becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to August 31, 2012 reflect the operations of Delta prior to reorganization (hereinafter also referred to as the “Predecessor”) and are not comparable to the consolidated financial statements presented on or after August 31, 2012. Accordingly, certain disclosures relating to the Predecessor’s financial statements for the eight months ended August 31, 2012 have been omitted.

Results of Operations

Successor year ended December 31, 2013 compared to Successor four months ended December 31, 2012 and Predecessor eight months ended August 31, 2012

The 2013 and 2012 periods lack comparability due to the application of fresh-start accounting effective August 31, 2012, the contribution of the majority of our natural gas and oil assets to Piceance Energy effective August 31, 2012, our acquisition of Texadian effective December 31, 2012 and our acquisition of HIE effective September 25, 2013.

Net Loss. Net loss was approximately $79.2 million, or a loss of $4.01 per basic and diluted common share, for the year ended December 31, 2013, compared to a net loss of approximately $8.8 million, or a loss of $0.56 per basic and diluted common share, for the four months ended December 31, 2012 and a net loss of approximately $45.4 million, or a loss of $1.57 per basic and diluted common share, for the eight months ended August 31, 2012.

Operating Revenues. For the year ended December 31, 2013, our operating revenues were approximately $878.3 million, consisting of refining and distribution and marketing revenues totaling approximately $778.1 million and commodity marketing and logistics revenues of approximately $100.1 million. There were no such revenues in the periods prior to December 31, 2012 due to HIE and Texadian being acquired effective September 25, 2013 and December 31, 2012, respectively.

Natural Gas and Oil Sales. For the year ended December 31, 2013, natural gas and oil sales was approximately $7.7 million. For the four months ended December 31, 2012 and eight months ended August 31, 2012, natural gas and oil sales were approximately $2.1 million and $23.1 million, respectively. The increase in natural gas and oil sales for the year ended December 31, 2013 compared to the four months ended December 31, 2012 is primarily due to the inclusion of 12 months activity in 2013 compared to four months of activity in 2012. The decrease in natural gas and oil sales for the year ended December 31, 2013 compared to the eight months ended August 31, 2012 is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy on August 31, 2012 in connection with our emergence from bankruptcy.

Cost of Revenues. For the year ended December 31, 2013, our cost of revenues was approximately $857.5 million consisting of refining distribution costs totaling approximately $773.6 million and commodity marketing and logistics costs of approximately $83.9 million. There were no such expenses in the periods prior to December 31, 2012 due to HIE and Texadian being acquired effective September 25, 2013 and December 31, 2012, respectively.

Lease Operating Expense. For the year ended December 31, 2013, lease operating expense was approximately $5.6 million. For the four months ended December 31, 2012 and eight months ended August 31, 2012, lease operating expense was approximately $1.7 million and $9.0 million, respectively. The increase in lease operating expense for the year ended December 31, 2013 compared to the four months ended December 31, 2012 is primarily due to the inclusion of 12 months activity in 2013 compared to four months of activity in 2012. The decrease in lease operating expense for the year ended December 31, 2013 compared to the eight months ended August 31, 2012 is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy on August 31, 2012 in connection with our emergence from bankruptcy.

Transportation Expense. For the year ended December 31, 2013 and the four months ended December 31, 2012, we incurred no transportation expense. For the eight months ended August 31, 2012, transportation expense was approximately $7.0 million. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy on August 31, 2012 in connection with our emergence from bankruptcy.

Production Taxes. For the year ended December 31, 2013, production taxes were approximately $49 thousand. For the four months ended December 31, 2012 and eight months ended August 31, 2012, production taxes were approximately $4 thousand and $979 thousand, respectively. The increase in production taxes for the year ended December 31, 2013 compared to the four months ended December 31, 2012 is primarily due to the inclusion of 12 months activity in 2013 compared to four months of activity in 2012. The decrease in production taxes for the year ended December 31, 2013 compared to the eight months ended August 31, 2012 is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy on August 31, 2012 in connection with our emergence from bankruptcy.

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Dry Hole Costs and Impairments. For the year ended December 31, 2013 and the four months ended December 31, 2012, we incurred no dry hole costs or impairment expense. Dry hole costs and impairments for the eight month period ended August 31, 2012 were approximately $151.3 million. On August 31, 2012, concurrent with the approval of the Plan, our natural gas and oil properties were reclassified to assets held for sale resulting in an impairment of approximately $151.3 million. Subsequent to the contribution of the majority of our natural gas and oil assets to Piceance Energy, we hold solely non-operated interests in natural gas and oil properties and have not participated in any exploratory drilling activities.

Depreciation, Depletion, Amortization and Accretion. For the year ended December 31, 2013, depreciation, depletion, amortization and accretion (“DD&A”) expense was approximately $6.0 million, which consisted primarily of $2.3 million for our refining, distribution and marketing business, $2.0 million for our commodity marketing and logistics business, approximately $1.7 million for our natural gas and oil operations and approximately $20 thousand relating to corporate. For the four months ended December 31, 2012 and eight months ended August 31, 2012, DD&A expense was approximately $401 thousand and $16 million, respectively and primarily related to our natural gas and oil activities. The increase in DD&A expense related to our refining and distribution business and our marketing and transportation business is due to the HIE acquisition and the Texadian acquisition on September 25, 2013 and December 31, 2012, respectively. The increase in DD&A expense for the year ended December 31, 2013 compared to the four months ended December 31, 2012 is primarily due to the inclusion of 12 months activity in 2013 compared to four months of activity in 2012. The decrease in DD&A expense for the year ended December 31, 2013 compared to the eight months ended August 31, 2012 is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy on August 31, 2012 in connection with our emergence from bankruptcy.

Trust Litigation and Settlements. For the year ended December 31, 2013, trust litigation and settlement expense was approximately $6.2 million and consisted of legal and other professional fees relating to the Recovery Trust of approximately $519 thousand and revisions to the settlement claim liability of approximately $5.7 million based on the claims settled during the period.

General and Administrative Expense. For the year ended December 31, 2013, general and administrative expense was approximately $21.5 million. For the four months ended December 31, 2012 and eight months ended August 31, 2012, general and administrative expense was approximately $4.5 million and $9.4 million, respectively. General and administrative costs were higher in 2013 due to the growth of the company, costs related to contractors, and costs related to the transition services agreement.

Acquisition and Integration Costs. For the year ended December 31, 2013 and 2012, were $9.8 million and $556 thousand. Of the $9.8 million recorded in 2013, $7.0 million is specific to acquisition costs and $2.8 million is related to integration costs.

Loss From Unconsolidated Affiliates. For the year ended December 31, 2013, our loss from Piceance Energy totaled approximately $2.9 million consisting of an allocated loss of $3.5 million partially offset by an accretion of the basis difference in the investment of approximately $575 thousand. The allocated loss includes an operating loss of approximately $2.3 million and financing and derivative costs of approximately $1.2 million. For the four months ended December 31, 2012, our allocated loss from our investment in Piceance Energy was approximately $1.3 million, which includes a loss of approximately $699 thousand from operating activities and financing and derivative loss of approximately $626 thousand. There was no significant loss from unconsolidated affiliates for the Predecessor as Piceance Energy was formed in connection with our emergence from bankruptcy on August 31, 2012.

Interest Expense and Financing Costs. For the year ended December 31, 2013, our interest expense and financing costs was approximately $19.5 million. For the four months ended December 31, 2012 and eight months ended August 31, 2012, interest expense and financing costs were approximately $1.1 million and $6.9 million, respectively. Our Predecessor and its subsidiaries filed bankruptcy petitions in December 2011 and January 2012. As a result, we ceased accruing interest on the Predecessor’s outstanding debt, except for the debtor-in-possession

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financing loan. The consummation of the Plan of Reorganization on August 31, 2012 resulted in a new capital structure. Furthermore, we have entered into various credit agreements related to the HIE acquisition and Texadian acquisition to support their related operations which have increased interest costs relative to prior periods.

Change in value of common stock warrants. For the year ended December 31, 2013, we recognized a loss related to the change in value of common stock warrants of approximately $10.1 million due to mark-to-market adjustments resulting from an increase in the price of our common stock. For the four months ended December 31, 2012, we recognized an unrealized loss of approximately $4.3 million due to mark-to-market adjustments resulting from an increase in the price of our common stock. These derivatives did not exist prior to our emergence from bankruptcy.

Gain on Derivative Instruments, net. For the year ended December 31, 2013, we recognized a gain primarily related to our derivative instruments of approximately $410 thousand due to mark-to-market adjustments. These derivatives did not exist prior to our emergence from bankruptcy.

Other Income. For the year ended December 31, 2013, other income totaled approximately $809 thousand. Other income for the four months ended December 31, 2012 was not significant. For the eight months ended August 31, 2012, other income was approximately $516 thousand.

Income Taxes. For the year ended December 31, 2013, we recorded no tax expense. For the four months ended December 31, 2012, we recorded a net income tax benefit of approximately $2.8 million, which represents the reduction in our valuation allowance as a result of deferred tax liabilities recorded in connection with the Texadian acquisition.

As of December 31, 2013, there was insufficient evidence for us to conclude that it was more likely than not that the deferred tax asset would be realized.

Reorganization Items. For the eight months ended August 31, 2012, we recognized approximately $22.4 million in professional fees and administrative expenses, a loss of approximately $14.8 million relating to a change in fair value of assets due to fresh-start reporting adjustments, and a gain on the extinguishment of debt of approximately $168.7 million related to the settlement of our senior debt and other liabilities. There are no reorganization items in periods subsequent to August 31, 2012.

Liquidity and Capital Resources

Our primary sources of liquidity are our cash flows from operations and borrowing availability under our credit facilities, as more fully described below. We believe that our cash flows from operations and available capital resources will be sufficient to meet our capital expenditure, working capital, and debt service requirements for the next twelve months. However, our ability to generate sufficient cash flow from operations depends, in part, on market prices for oil and refined products and general economic, political and other factors beyond our control. We believe we could, during periods of economic downturn, access the capital markets and/or other available financial resources or reduce our capital and discretionary expenditure plans to strengthen our financial position.

Current Liquidity. The following table summarizes our liquidity position as of March 25, 2014 and December 31, 2013 (in thousands):

	Refining Distribution and Marketing		Commodity Marketing and Logistics		Other		Total
March 25, 2014
Cash and cash equivalents (1)	$	9,680	$	10,773	$	2,216	$	22,669
Revolver availability		5,000		—		—		5,000
ABL Facility		33,134		18,491		—		51,625
Total available liquidity	$	47,814	$	29,264	$	2,216	$	79,294

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	Refining Distribution and Marketing		Commodity Marketing and Logistics		Other		Total
December 31, 2013
Cash and cash equivalents (1)	$	4,536	$	24,009	$	9,516	$	38,061
Revolver availability		5,000		—		—		5,000
ABL Facility		28,436		8,420		—		36,856
Total available liquidity	$	37,972	$	32,429	$	9,516	$	79,917

(1) The HIE, HIE Retail and Texadian credit agreements contain certain covenants that limit our ability to distribute cash to their parent or other subsidiaries.

In addition to the above, in conjunction with our acquisition of HIE, and to finance the acquisition and the operations of the business of HIE after the acquisition, we entered into the crude oil Supply and Exchange Agreements. Since the Emergence Date, the primary uses of our capital resources have been in the acquisition and operation of Texadian and HIE, payment of operating expenses related to our natural gas and oil assets, professional fees, and bankruptcy expenses.

We may be required to fund capital contributions of up to $20 million to Piceance Energy under the Piceance Energy LLC Agreement. We expect that our capital contributions will be funded from available cash on hand and possible equity contributions from certain existing stockholders. If our cash sources are not sufficient to fund our entire capital contribution, then our equity ownership interest in Piceance Energy may be reduced or diluted to the extent of our shortfall.

Private Placement Equity Transaction

On September 13, 2013, we entered into a Common Stock Purchase Agreement pursuant to which we agreed to sell shares of our common stock at a price of $13.90 per share, as adjusted to reflect the one for ten reverse stock split effective for trading purposes on January 29, 2014 (the “Reverse Stock Split”), in a private placement transaction (the “Private Placement”) in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933. Certain purchasers, namely, ZCOF Par Petroleum Holdings, L.L.C., an affiliate of Zell Credit Opportunities Master Fund, L.P. (“ZCOF”), and affiliates of Whitebox Advisors, LLC (“Whitebox”), each owned 10% or more of the our common stock directly or through affiliates prior to the execution of the Common Stock Purchase Agreement and are deemed to be our affiliates as a result of such ownership. ZCOF and Whitebox have representatives on our board of directors.

On September 25, 2013, we completed the Private Placement and issued approximately 14.4 million shares of common stock resulting in aggregate gross proceeds to us of approximately $200 million. We did not engage any investment advisors with respect to the Private Placement, and no finders’ fees or commissions were paid to any party in connection therewith. The proceeds from the Private Placement were used to fund a portion of the purchase price for the HIE acquisition.

Delayed Draw Term Loan Credit Agreement

Pursuant to the Plan, on the Emergence Date, we and certain of our subsidiaries (the “Guarantors” and, together with the company, the “Loan Parties”) entered into a Delayed Draw Term Loan Credit Agreement (the “Loan Agreement”) with Jefferies Finance LLC, as administrative agent (the “Agent”) for the lenders party thereto from time to time, including WB Delta, Ltd., Waterstone Offshore ER Fund, Ltd., Prime Capital Master SPC, GOT WAT MAC Segregated Portfolio, 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 (collectively, the “Lenders”), pursuant to which the Lenders agreed to extend credit to us in the form of term loans (each, a “Loan” and collectively, the “Loans”) of up to $30 million. We borrowed $13 million on the Emergence Date in order to, along with the proceeds from the Contribution Agreement: (i) repay the loans and obligations due under the Predecessor’s secured debtor-in-possession credit facility, and (ii) pay allowed but unpaid administrative expenses to the Debtors related to the Plan. During 2013, we borrowed an additional $17 million for general corporate use. In November 2013, we repaid in full and terminated all of our obligations under the Loan Agreement, other than the New Tranche B Loans described below.

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Amendment to the Loan Agreement

On December 28, 2012, in order to fund a portion of the purchase price for our acquisition of Texadian Energy, the Loan Parties entered into an amendment to the Loan Agreement with the Agent and the Lenders, pursuant to which certain lenders (the “Tranche B Lenders”) agreed to extend additional borrowings to us (the “Tranche B Loan”). The total commitment of the Tranche B Loan of $35 million was drawn at closing. In addition to funding a portion of the purchase price of the acquisition of Texadian, the Tranche B Loan provided cash collateral for our former cash collateralized letter of credit facility. Pursuant to the Eighth Amendment to the Loan Agreement entered into on July 24, 2013, the Lenders refinanced and replaced the Tranche B Loan with new Tranche B Loans in the aggregate principal amount of $65 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Tranche B Loan, to make payments due under the membership interests purchase agreement in connection with the acquisition of HIE (the “HIE Purchase Agreement”), and for working capital and general corporate purposes.

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to the Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the HIE Purchase Agreement and the use of a portion of the proceeds from the Private Placement to fund a portion of the consideration for the acquisition of HIE and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the HIE Purchase Agreement, (iii) increased the interest rate applicable to certain of the loans, and (iv) amended certain provisions of the Loan Agreement and the other loan documents in connection with the consummation of the transactions contemplated by the HIE Purchase Agreement and the Private Placement.

The consent provided by the Lenders was conditioned on, among other things, (i) the repayment in full of the New Tranche B Loans owing to all Lenders except for ZCOF Par Petroleum Holdings, L.L.C., and a partial repayment of the New Tranche B Loans owing to ZCOF Par Petroleum Holdings, L.L.C. from a portion of the proceeds from the Private Placement and (ii) a portion of the proceeds from the Private Placement being used to consummate the transactions contemplated by the HIE Purchase Agreement.

The term loans (other than the New Tranche B Loans that remain outstanding following the repayment described above) under the Loan Agreement bore interest (a) from September 25, 2013 through October 31, 2013, at a rate equal to 9.75% per annum payable, at the election of the company, either (i) in cash or (ii) in-kind, and (b) from and after November 1, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in-kind. These term loans were repaid in full in November 2013.

The New Tranche B Loans bear interest (a) from June 24, 2013 through October 31, 2013 at a rate equal to 9.75% per annum payable, at the election of the company, either (i) in cash or (ii) in kind, and (b) from and after November 1, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in kind. Additionally, we agreed to pay the New Tranche B Lenders a nonrefundable exit fee equal to 2.5% of the aggregate amount of the New Tranche B Loans. The exit fee is earned in full and payable on the maturity date of the Tranche B Loans or, if earlier, the date on which the New Tranche B Loans are paid in full.

The New Tranche B Loans mature and are payable in full on August 31, 2016. We may prepay the New Tranche B Loans at any time, provided that any prepayment is in an integral multiple of $100,000 and not less than $100,000 or, if less, the outstanding principal amount of the New Tranche B Loans. Amounts to be applied to prepayment of New Tranche B Loans shall be applied (i) first, towards payment of interest then outstanding and fees then due, and (ii) second, towards payment of principal then outstanding.

The New Tranche B Loans are secured by a lien on substantially all of our assets and our subsidiaries, excluding Texadian, Texadian Energy Canada Limited (“Texadian Canada”), certain of our immaterial subsidiaries, and Hawaii Pacific Energy and its subsidiaries. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

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ABL Facility

On September 25, 2013 and in connection with the with the acquisition of Tesoro Hawaii, HIE and certain subsidiaries of HIE (the “ABL Borrowers”) and Hawaii Pacific Energy entered into an asset-based revolving credit facility (the “ABL Facility”) to provide the ABL Borrowers with a senior secured revolving credit facility of up to $125 million under which the ABL Borrowers may borrow amounts from time to time based on the available borrowing base as determined in accordance with the ABL Facility. The ABL Facility also allows the ABL Borrowers to use up to $50 million of availability under the ABL Facility for the issuances of letters of credit. The amounts borrowed pursuant the ABL Facility and all obligations arising under the ABL Facility are secured by a lien on substantially all of HIE’s assets. The ABL Borrowers agreed to pay an up-front fee, an origination fee, and commitment fees for the ABL Facility. The ABL Borrowers borrowed $15 million on September 25, 2013 under the ABL Facility in order to, in part, (i) fund the purchase price under the HIE Purchase Agreement, and (ii) provide working capital to the ABL Borrowers. The proceeds from any future amounts borrowed pursuant to the ABL Facility will be used for general corporate purposes and to fund the working capital of the ABL Borrowers. All loans and other obligations outstanding under the ABL Facility are payable in full on September 25, 2017. The ABL Facility requires HIE and its subsidiaries and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting its business and operations, including compliance by HIE in certain circumstances with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”), as adjusted, to total fixed charges of 1.0 to 1.0.

HIE Retail Credit Agreement

On November 14, 2013, HIE Retail, LLC (“HIE Retail”), our subsidiary, entered into a Credit Agreement (the “Retail Credit Agreement”) in the form of a senior secured term loan of up to $30 million (the “Term Loan”) and a senior secured revolving line of credit of up to $5 million (the “Revolver”). The Lenders initially advanced $26 million of the Term Loan at the closing and will advance an additional $4 million of the Term Loan upon HIE Retail’s compliance with certain liquor licensing requirements, if such requirements are satisfied prior to December 31, 2014. The proceeds of the Term Loan are available for general corporate purposes. Loans made under the Retail Credit Agreement are secured by a first priority security interest in substantially all of the assets of HIE Retail consisting primarily of 31 retail outlets on the islands of Oahu, Maui and Hawaii. HIE Retail agreed to pay the lenders an upfront and an annual agent fee beginning on November 14, 2014. The Retail Credit Agreement requires HIE Retail to comply with various financial covenants that are measured on a quarterly basis commencing with the fiscal quarter ending March 31, 2014 and are calculated on a trailing four-quarter basis. The Term Loan matures and is fully payable on November 14, 2020. Principal on the Term Loan will be repaid in 28 equal quarterly principal payments over the term. The Revolver matures on November 14, 2016. Letters of credit issued under the Revolver are not to expire beyond the maturity date of the Revolver. A percentage of annual cash flow may be applied to the outstanding principal balance of the Term Loan begins with fiscal year 2014 if the leverage ratio exceeds 4.5:1.00.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly-owned subsidiary Texadian Canada entered into an uncommitted credit agreement (the “Uncommitted Credit Agreement”) that provides for loans and letters of credit, on an uncommitted and absolutely discretionary basis, in an aggregate amount at any one time outstanding not to exceed $50 million. Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian’s assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian. Texadian agreed to pay certain fees with respect to the loans and letters of credit made available to it under the Uncommitted Credit Agreement, including an up-front fee, an origination fee, a minimum compensation fee, a collateral audit fee, and fees with respect to letters of credit. The Uncommitted Credit Agreement requires Texadian to comply with various affirmative and negative covenants affecting its business, and Texadian must comply with certain financial maintenance covenants, including among other things, covenants regarding the minimum net working capital and minimum tangible net worth of Texadian. The Uncommitted Credit Facility does not permit, at any time, Texadian’s consolidated leverage ratio to be greater than 5.00 to 1.00 or its consolidated gross asset coverage to be equal to or less than zero. As of December 31, 2013, Texadian was in compliance with these covenants. There was $41.6 million outstanding in letters of credit as of December 31, 2013.

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Warrant Issuance Agreement

Pursuant to the Plan of Reorganization, on the Emergence Date, we issued to the lenders under the Loan Agreement warrants (the “Warrants”) to purchase up to an aggregate of 959,213 shares of our common stock (the “Warrant Shares”). In connection with the issuance of the Warrants, we also entered into a Warrant Issuance Agreement, dated as of the Emergence Date (the “Warrant Issuance Agreement”). Subject to the terms of the Warrant Issuance Agreement, the holders are entitled to purchase shares of common stock upon exercise of the Warrants at an exercise price of $0.10 per share of common stock (the “Exercise Price”), subject to certain adjustments from time to time as provided in the Warrant Issuance Agreement. The Warrants expire on the earlier of (i) August 31, 2022 or (ii) the occurrence of certain merger or consolidation transactions specified in the Warrant Issuance Agreement. A holder may exercise the Warrants by paying the applicable exercise price in cash or on a cashless basis.

The Warrant Issuance Agreement includes certain restrictions on the transfer by holders of their Warrants, including, among others, that (i) the Warrants and the notes under the Loan Agreement are not detachable for transfer purposes, and for as long as obligations under the Loan Agreement are outstanding, the notes and Warrants may not be transferred separately, and (ii) in the event that any holder desires to transfer any pro rata portion of the notes and Warrants, then such holder must provide the other Lenders and/or holders of the Warrants with a right of first offer to make an election to purchase such offered notes and Warrants.

The number of shares of our common stock issuable upon exercise of the Warrants and the exercise prices of the Warrants will be adjusted in connection with certain issuances or sales of shares of the company’s common stock and convertible securities, or any subdivision, reclassification or combinations of common stock. Additionally, in the case of any reclassification or capital reorganization of the capital stock of the company, the holder of each Warrant outstanding immediately prior to the occurrence of such reclassification or reorganization shall have the right to receive upon exercise of the applicable Warrant, the kind and amount of stock, other securities, cash or other property that such holder would have received if such Warrant had been exercised.

From the Emergence Date through December 31, 2013, we issued an additional 208,460 shares of our common stock to settle bankruptcy matters. This entitles the Lenders to receive an additional 14,859 Warrant Shares as of December 31, 2013. On December 12, 2013, Warrants to purchase 183,389 Warrant Shares were exercised. At December 31, 2013, Warrants to purchase an aggregate of 790,683 Warrant Shares were outstanding.

Cash Flows

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1 though August 31, 2012
				(In thousands)
Net cash provided by (used in) operating activities	$	(35,677	)	$	(4,636	)	$	(20,262	)
Net cash provided by (used in) investing activities	$	(564,500	)	$	(17,690	)	$	72,622
Net cash provided by financing activities	$	632,053		$	23,629		$	(60,340	)

Net cash used in operating activities was approximately $35.7 million for the year ended December 31, 2013 which resulted from a net loss of approximately $79.2 million offset by non-cash charges to operations of approximately $37.1 million and working capital changes of approximately $6.4 million. Net cash used in operating activities for the four months ended December 31, 2012 and eight months ended August 31, 2012 was approximately $4.6 million and $20.3 million, respectively. The operations of the 2012 and 2013 periods are not comparable due to the contribution of the majority of our natural gas and oil assets to Piceance Energy and the application of fresh - start accounting effective August 31, 2012, our acquisition of Texadian on December 31, 2012 and our acquisition of HIE on September 25, 2013.

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For the year ended December 31, 2013, net cash used in investing activities was primarily related to the acquisition of HIE for approximately $564.5 million, of which approximately $378.2 million was funded from the Supply and Exchange Agreements (see below), capitalized drilling costs and additions to property and equipment totaling approximately $8.1 million partially offset by proceeds of the sale of our assets held for sale of approximately $2.9 million. For the four months ended December 31, 2012, net cash used in investing activities was primarily related to our acquisition of Texadian and totaled approximately $17.4 million. Net cash provided by investing activities was approximately $72.6 million in the eight months ended August 31, 2012 and was generated from the proceeds of the sale of our oil and gas assets to Piceance Energy for approximately $74.2 million ($72.6 million net after working capital adjustments made in subsequent periods).

Net cash provided by financing activities for the year ended December 31, 2013 of approximately $632.1 million resulting from advances from our supply and exchange agreements totaling approximately $378.2 million, the sale of common stock totaling approximately $199.2 million, additional borrowings under our debt agreements of approximately $159.8 million and the release of approximately $19 million from restricted cash held to secure letters of credit partially offset by repayment of borrowings of approximately $121.9 million and payment of loan issue costs of approximately $2.3 million. For the four months ended December 31, 2012, net cash provided by financing activities totaled $23.6 million and was primarily related to borrowing of $35.0 million under our Tranche B Loan, the release of $5.2 million of restricted cash by the Recovery Trusts, as discussed under “ - Commitments and Contingencies” below, an additional $2.4 million generated by recoveries from the Wapiti Trust, offset by a required deposit of $19 million to support letters of credit. Net cash used in financing activities was approximately $60.3 million in the eight months ended August 31, 2012. During the eight months ended August 31, 2012, we borrowed (i) approximately $13 million under our Loan Agreement on the Emergence Date, and (ii) approximately $10 million, and then repaid approximately $59.5 million under the senior secured debt-in-possession credit facility entered into by the Predecessor and reserved an additional $21.8 million in order to extinguish liabilities relating to the bankruptcy and funded the Wapiti and General Recovery Trusts with $2.0 million.

Capital Expenditures

Our capital expenditures excluding acquisitions for the year ended December 31, 2013 totaled approximately $7.8 million and was primarily related to our refinery and information technology systems.

Additional capital may be required to maintain our interests at our Point Arguello Unit offshore California, but this is currently unestimatable. Furthermore, we may be required as part of our equity investment in Piceance Energy to contribute up to an aggregate of approximately $20.0 million if approved by the majority of its board of managers. 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 Exchange Agreements

HIE entered into several agreements with Barclays Bank PLC (“Barclays”), referred to collectively as the Supply and Exchange Agreements, on September 25, 2013 in connection with the acquisition of HIE. We entered into the Supply and Exchange Agreements for the purpose of managing our working capital and the crude oil and refined product inventory at the refinery.

Pursuant to the Supply and Exchange Agreements, Barclays holds title to all of the crude oil in the tanks at the Refinery. Additionally, Barclays holds title to a majority of our refined product inventory in our tanks at the Refinery. We hold title to the inventory during the refining process. Barclays sells the crude oil as it is discharged out of the Refinery’s tanks. We exchange refined product owned by Barclays stored in our tanks for equal volumes of refined product produced by our refinery when we execute third party sales of refined product. We currently market and sell the refined product independently to third parties. The Supply and Exchange Agreements have an initial term of three years with two one-year renewal options.

As described in Note 2 - Summary of Significant Accounting Policies, we record the inventory owned by Barclays on our behalf because we maintain the risk of loss until the refined products are sold to third parties.

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Because we do not hold legal title to the crude oil inventory until it enters the refinery, we record a liability in an amount equal to the carrying value of the crude oil inventory. In accordance with the terms of the Supply and Exchange Agreements, the volume of refined products purchased by Barclays in connection with the acquisition of HIE is known as the “Block Volume”. To the extent we have refined products inventory volumes at period-end in excess of the Block Volume, we record a liability for the Block Volume valued at the per barrel carrying value of the refined product inventory owned by Barclays. From time to time, we may sell refined product inventory that causes our refined product inventory to be less than the Block Volume. To the extent of this shortfall, we record a liability for the volumes that we would need to purchase at current market prices in order to meet the Block Volume requirement. The liability related to the Supply and Exchange Agreements is included in obligations under supply and exchange agreements on our consolidated balance sheets.

Environmental Matters

Like other petroleum refiners and oil and gas 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. Our policy is to accrue environmental and clean-up related costs of a non-capital nature when it is probable that a liability has been incurred and the amount can be reasonably estimated. Such estimates may be subject to revision in the future as regulations and other conditions change.

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. 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.

Regulation of Greenhouse Gases. The United States Environmental Protection Agency (“US EPA”) has begun regulating greenhouse gases under the Clean Air Act Amendments of 1990 (the “Clean Air Act”). New construction or material expansions that meet certain greenhouse gas emissions thresholds will likely require that, among other things, a greenhouse gas permit be issued in accordance with the Clean Air Act 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 greenhouse gas emissions.

Furthermore, the US EPA is currently developing refinery-specific greenhouse gas regulations and performance standards that are expected to impose, on new and modified operations, greenhouse gas 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 cost of the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity.

In 2007, the State of Hawaii passed Act 234, which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed, the Hawaii Department of Health (“DOH”) 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 greenhouse gas emissions were reported to the US EPA under 40 CFR Part 98). Those rules are pending final approval by the Government of Hawaii. The refinery’s capacity to reduce fuel use and greenhouse gas emissions is limited. However, the state’s pending regulation allows, and the refinery should be able to demonstrate, that additional reductions are not cost-effective or necessary in light of the state’s current greenhouse gas inventory and future year projection. The pending regulation allows for “partnering” with other facilities (principally power plants) which 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 (“EISA”) which, 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 United States by model year 2020, and contained a second Renewable Fuel Standard (the “RFS2”). In August 2012, the US EPA and National Highway Traffic Safety Administration jointly adopted

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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 36.0 billion gallons by 2022. In the near term, the RSF2 will be satisfied primarily with fuel ethanol blended into gasoline. The RSF2 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 US 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 US EPA issued a partial waiver decision under the Clean Air Act 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 US EPA issued a second waiver for the use of E15 in vehicles model year 2001-2006. There are numerous issues, including state and federal regulatory issues, which need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines. Since April 2006, the State of Hawaii has required that a minimum of 9.2% ethanol be blended into at least 85% of the gasoline pool, but the regulation also limited the amount of ethanol to no more than 10%. Consequently, unless either the state or federal regulations are revised, qualified Renewable Identification Numbers (“RINS”) will be required to fulfill the federal mandate for renewable fuels.

In March 2014, the US EPA published a final Tier 3 gasoline standard that lowers the allowable sulfur level in gasoline to 10 ppm and also lowers the allowable benzene, aromatics and olefins content of gasoline. The effective date for the new standard, January 1, 2017, gives refiners nation-wide little time to engineer, permit and implement substantial modifications. Along with credit and trading options, potential capital upgrades for the refinery are being evaluated. The American Petroleum Institute and American Fuel and Petrochemical Association may challenge the final regulation.

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. We may 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 (the “Closing Date”), Hawaii Pacific Energy (a wholly-owned subsidiary of Par created for purposes of the Tesoro Acquisition), Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities related to the acquisition of HIE, including the Consent Decree as described below.

Consent Decree. Tesoro is currently negotiating a Consent Decree with the US EPA and the United States Department of Justice concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates, including our refinery. It is anticipated that the Consent Decree will be finalized sometime during 2014 and will require certain capital improvements to our refinery to reduce emissions of air pollutants.

It is not possible at this time to estimate the cost of compliance with the final decree. However, Tesoro is responsible under the Environmental Agreement for reimbursing HIE for all reasonable third party capital expenditures incurred for the construction, installation and commissioning of such capital projects and for the payment of any fines or penalties imposed on HIE arising from the Consent Decree to the extent related to acts or omission of Tesoro or HIE prior to the Closing Date. Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, the obligation relating to fines and penalties terminates on the third anniversary of the Closing Date.

Tank Replacements. Tesoro has agreed, at its expense, to replace the existing underground storage tanks at certain retail locations.

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 breached of Tesoro’s

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representations, warranties and covenants in the Environment 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 Closing Date, any fine, penalty or other cost assessed by a governmental authority in connection with violations of environmental laws by HIE prior to the Closing Date, certain groundwater remediation work, the replacement of underground storage tanks located at certain retail assets, fines or penalties imposed on HIE by the Consent Decree related to acts or omissions of Tesoro prior to the Closing Date and to the Pearl City Superfund Site.

Tesoro’s indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement.

Bankruptcy Matters

On the date we emerged from bankruptcy, or the Emergence Date, two trusts were formed, the Wapiti Trust and the Delta Petroleum General Recovery Trust (the “General Trust,” and together with the Wapiti Trust, the “Recovery Trusts”). The Recovery Trusts were 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. The Recovery Trusts were funded with $1 million each pursuant to the Plan.

The General Trust is pursuing all bankruptcy causes of action not otherwise vested in the Wapiti Trust, claim objections and resolutions, and all other responsibilities for winding-up the bankruptcy. The General Trust is overseen by a three person General Trust Oversight Board and our Chief Legal Officer is currently the trustee (the “Recovery Trustee”). Costs, expenses and obligations incurred by the General Trust are charged against assets in the General Trust. To conduct its operations and fulfill its responsibilities under the Plan and the trust agreements, the Recovery Trustee may request additional funding from us. Any litigation pending at the time we emerged from Chapter 11 was transferred to the General Trust for resolution and settlement in accordance with the Plan and the order confirming the Plan. We are the beneficiary of the General Trust, subject to the terms of the trust agreement and the Plan. Since the Emergence Date, the General Trust has filed various claims and causes of action against third parties before the Bankruptcy Court, which actions are ongoing. Upon liquidation of the various claims and causes of action held by the General Trust, the proceeds, less certain administrative reserves and expenses, will be transferred to us. It is unknown at this time what proceeds, if any, we will realize from the General Trust’s litigation efforts.

From the Emergence Date through December 31, 2013, the Recovery Trusts have released approximately $5.2 million to us, which is available for our general use, due to a negotiated reduction in certain fees and claims associated with the bankruptcy, as well as a favorable variance in actual expenses versus budgeted expenses. The entire $5.2 million was released prior to December 31, 2012.

The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. On the Emergence Date, 112 claims totaling approximately $73.7 million had been filed in the bankruptcy. Pursuant to the Plan, between the Emergence Date and December 31, 2012, the Recovery Trustee settled 25 claims with an aggregate face amount of $6.6 million for $258,905 in cash and 20,275 shares of common stock. Pursuant to the Plan, during the year ended December 31, 2013, the Recovery Trustee settled an additional 59 claims with an aggregate face amount of $26.9 million for approximately $5.4 million in cash and 208,460 shares of common stock.

As of December 31, 2013, it is estimated that a total of 28 claims totaling approximately $40.2 million remain to be resolved by the Recovery Trustee. The largest remaining proof of claim 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. 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, owned a 2.41934% 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

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per $1,000 of claim. At December 31, 2013, we have reserved approximately $3.8 million representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end (see Note 13 - Commitments and Contingencies to our audited consolidated financial statements).

Operating Leases

Within our refining, distribution and marketing segment, we have various cancellable and noncancellable operating leases related to land, vehicles, office and retail facilities and other facilities used in the storage, transportation and sale of crude oil and refined products. The majority of the future lease payments relate to retail stations and facilities used in the storage, transportation and sale of crude oil and refined products. We have operating leases for most of our retail stations with primary terms of up to 32 years, and generally containing renewal options and escalation clauses. Leases for facilities used in the storage, transportation and sale of crude oil and refined products have various expiration dates extending to 2027.

In addition, with our commodity, marketing and logistics segment, we have various agreements to lease storage facilities, primarily along the Mississippi River, railcars, inland river tank barges and towboats and other equipment. These leasing agreements have been classified as operating leases for financial reporting purposes and the related rental fees are charged to expense over the lease term as they become payable. The leases generally range in duration of five years or less and contain lease renewal options at fair value. Our railcar leases contain an empty mileage indemnification provision whereby if the empty mileage exceeds the loaded mileage, we are charged for the empty mileage at the rate established by the tariff of the railroad on which the empty miles accrued.

Minimum annual lease payments extending to 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):

	Total
2013	$	22,725
2014		13,277
2015		12,362
2016		10,375
2017		9,244
Thereafter		25,614
Total minimum rental payments	$	93,597

Capital Leases

Within our refining, distribution and marketing segment, we have capital lease obligations related primarily to the leases of five retail stations with initial terms of 17 years, with four 5-year renewal options. Minimum annual lease payments including interest, for capital leases are as follows (in thousands):

2013	$	382
2014		382
2015		382
2016		382
2017		382
Thereafter		840
Total minimum lease payments		2,750
Less amount representing interest		829
Total minimum rental payments	$	1,921

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Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations were based on the consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. Our significant accounting policies are described in Note 2 - Summary of Significant Accounting Policies of our audited consolidated financial statements included herein. We have identified certain of these policies as being of particular importance to the portrayal of our financial position and results of operations and which require the application of significant judgment by management. We analyze our estimates, including those related to fresh start accounting adjustments, natural gas and oil reserves, bad debts, natural gas and oil properties, income taxes, derivatives, contingencies and litigation, and base our estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions. We believe the following critical accounting policies affect our more significant judgments and estimates used in the preparation of our consolidated financial statements.

Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. In estimating fair value, we use discounted cash-flow projections, recent comparable market transactions, if available, or quoted prices. We consider assumptions that third parties would make in estimating fair value, including the highest and best use of the asset. There is a significant amount of judgment involved in cash-flow estimates. The assumptions used by another party could differ significantly from our assumptions.

We classify fair value balances based on the classification of the inputs used to calculate the fair value of a transaction. The inputs used to measure fair value have been placed in a hierarchy based on priority. The hierarchy gives the highest priority to unadjusted, readily observable quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

We used a variety of methods to estimate fair value of our acquired assets and the value assigned to assets and liabilities in business combinations and in the application of fresh-start reporting, including the cost approach, the sales approach and the income approach. These methods require management to make judgments regarding characteristics of the acquired property, future revenues and expenses. Changes in these estimates would result in different amounts allocated to the related assets and liabilities.

Assets and Liabilities Recorded at Fair Value on a Recurring Basis

In the valuation of the liability for the contingent consideration to be paid for the acquisition of HIE and of our outstanding Warrants, we use a Monte Carlo Simulation model which requires management to make estimates of future gross margin, gross margin volatility and expected volatility of our stock price and a present value factor. Different estimates would result in a change in the fair value of the amounts presented in our consolidated financial statements.

Additionally, we have certain derivative instruments where we have elected the normal purchases and normal sales exception. Had we not made this election, these derivatives would be marked to market each period with the difference recorded in earnings.

Derivatives and Other Financial instruments

We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange traded futures contracts, collar agreements, swaps or options. The purpose of the transactions will be to provide a measure of stability to our cash flows in an environment of volatile commodity prices.

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Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle. Should we not designate a contract as a normal purchase or normal sale then the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. We elect to offset amounts recognized for derivative instruments executed with the same counterparty under a master netting arrangement. As a result, our consolidated balance sheets present derivative assets and liabilities on a net basis. As of December 31, 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.

In addition, from time to time we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.

As a part of the Plan of Reorganization, we issued warrants that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in earnings.

Asset Retirement Obligations

We record asset retirement obligations (“AROs”) at fair value in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the fair value of the liability. Our AROs arise from our refining, distribution and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and oil operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value and the related capitalized cost is depreciated over the asset’s useful life and both are recorded in depreciation, depletion and amortization in the statements of operations. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments in our statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives.

We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos), and removal or dismantlement requirements associated with the closure of our refining facility, terminal facilities or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines or other equipment.

Revenue Recognition

We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met.

Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the

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property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2013 and 2012, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements. Additionally, we provide an accrual for natural gas and oil sales using the sales method by estimating natural gas and oil volumes and prices for months in which revenues have not been received using production and pricing information provided by the operator.

Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of rail cars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the customer, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.

Refining, Distribution and Marketing. We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We record certain transactions in cost of sales in our statements of consolidated operations on a net basis. These transactions include nonmonetary crude oil and refined product exchange transactions used to optimize our refinery supply, and sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another. We include transportation fees charged to customers in revenues in our statements of consolidated operations, while the related transportation costs are included in cost of sales or operating expenses. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.

Inventory

Inventories are stated at the lower of cost or market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.

We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions, with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.

Income Taxes

We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard, and to the extent this threshold is not met, a valuation allowance is recorded.

We recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2010, 2011, and 2012. However, since

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we have net operating loss carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations under Section 6501 of the Internal Revenue Code of 1986, as amended (the “Code”), in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.

We expect to incur state income tax liabilities as a result of certain operations in states where we have no net operating loss carryovers available to offset taxable income generated within those states.

Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Financial statements begin on page F-1. There are no financial statement schedules since they are either not applicable or the information is included in the notes to the financial statements.

Item 9A. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

In connection with the filing of our Annual Report on Form 10-K (“Original Form 10-K”), as of December 31, 2013, an evaluation was performed under the supervision and with the participation of the Company’s 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 Rule 15d-15 (e) under the Exchange Act. In performing this evaluation, management reviewed the selection, application and monitoring of our historical accounting policies. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded, based on a material weakness in internal control over financial reporting, that these disclosure controls and procedures were not effective as of December 31, 2013. In designing and evaluating disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. Management is required to apply judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Subsequent to the filing of the Original Form 10-K and in connection with the restatement discussed elsewhere in this Amendment No. 2 on Form 10-K/A (“Amendment No. 2”), management identified an additional material weakness in the Company’s internal control over financial reporting, as described in Management’s Report on Internal Control Over Financial Reporting below. As a result of its identification of the material weaknesses, management, under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer, reevaluated the effectiveness of the Company’s disclosure controls and procedures as of December 31, 2013. Based on that reevaluation, our Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures were not effective. Notwithstanding the material weaknesses, each of the Company’s Chief Executive Officer and Chief Financial Officer has concluded, based on his knowledge, that the consolidated financial statements included in this Amendment No. 2 fairly present, in all material respects, the financial condition, results of operations and cash flows of the Company as of and for the periods presented in this report, in conformity with accounting principles generally accepted in the United States.

Management’s Report on Internal Control Over Financial Reporting (as revised)

Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Under the supervision and with the participation of our management, in connection with the Original Form 10-K, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992) (the “COSO Framework”). Based on our evaluation under this framework, our management concluded that our internal control over financial reporting was not effective as of December 31, 2013.

Prior to December 31, 2011, we filed for voluntary bankruptcy and during the duration of the proceedings, our ability to maintain effective internal control over financial reporting was weakened due to a high amount of turnover to our accounting staff. As of August 31, 2012, we emerged from bankruptcy and replaced the operations and financial reporting functions with a new accounting group. In December 2012 and September 2013, we completed acquisitions which significantly increased the size of the Company and its resource requirements. Due to our rapid growth there has been a heavy reliance on external service providers and contractors, particularly in the accounting department.

        During the fourth quarter of 2013, management performed a comprehensive assessment of the design and operating effectiveness of internal control over financial reporting. In performing its assessment, management considered the number of late

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adjustments and corrections to the consolidated financial statements. As a result of this assessment, management concluded that the Company had a material weakness because it did not have sufficient qualified accounting personnel to prevent our financial statements and related disclosures from being materially misstated. As a result of this assessment and based on the criteria in the COSO Framework, management concluded, based upon the material weakness described above, that the Company did not maintain effective internal control over financial reporting as of December 31, 2013.

In connection with the restatement discussed elsewhere in this Amendment No. 2, management reevaluated the effectiveness of its internal control over financial reporting. Based on this reevaluation, management concluded that the Company had an additional material weakness because it did not have appropriate controls in place to ensure inventory measurements were calculated correctly. Based upon this additional material weakness, management concluded that the Company did not maintain effective internal control over financial reporting as of December 31, 2013.

Changes in Internal Control over Financial Reporting

There have been no changes during the quarter ended December 31, 2013 in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financing reporting.

As a result of the initial material weakness described above, management determined that the Company needed to hire additional finance and accounting personnel to ensure it had adequate resources to perform the accounting functions and, to the extent external service providers and contractors continue to be used, adequately supervise those resources to prevent the financial statements and related disclosures from being materially misstated. We hired a new Chief Financial Officer in December 2013, and hired a Corporate Controller and additional accounting staff in early 2014 to enhance controls and procedures in the accounting function. Additionally, as a result of the additional material weakness described above and in connection with the restatement discussed elsewhere in this Amendment No. 2, management has established inventory reporting guidelines and policies to ensure inventory quantities will be reported on a consistent basis. The internal control gap remediation to be performed by management is ongoing and was not completed as of the filing of this Amendment No. 2.

No Attestation Report of the Registered Public Accounting Firm

This Amendment No. 2 does not include an attestation report of the Company’s independent registered public accounting firm regarding the Company’s internal control over financial reporting. Management’s report was not subject to attestation by the Company’s independent registered public accounting firm pursuant to an exemption for smaller reporting companies under Section 989G of the Dodd-Frank Act. We qualify for the Dodd-Frank Act exemption from the independent auditor attestation requirement under Section 404(b) of the Sarbanes-Oxley Act for small issuers that are neither a large accelerated filer nor an accelerated filer.

PART IV

Item 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES

(a)(1) Financial Statements.

	Page No.
Reports of Independent Registered Public Accounting Firms		F-1
Consolidated Balance Sheets		F-5
Consolidated Statements of Operations		F-6
Consolidated Statements of Changes in Stockholders’ Equity		F-7
Consolidated Statements of Cash Flows		F-8
Notes to Consolidated Financial Statements		F-9

(2) Financial Statement Schedules. None.

(3) Exhibits.

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INDEX TO EXHIBITS

2.1	Third Amended Joint Chapter 11 Plan of Reorganization of Delta Petroleum Corporation and Its Debtor Affiliates dated August 13, 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 2.2 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 at June 17, 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.***
3.1	Amended and Restated Certificate of Incorporation of the company. Incorporated by reference to Exhibit 3.1 to the company’s Current Report on Form 8-K filed on September 7, 2012.
3.2	Certificate of Amendment to the Certificate of Incorporation of the company dated effective September 25, 2013. Incorporated by reference to Exhibit 3.1 to the company’s Current Report on Form 8-K filed on September 27, 2013.
3.3	Certificate of Amendment to Amended and Restated Certificate of Incorporation of the company dated January 23, 2014. Incorporated by reference to Exhibit 3.1 to the company’s Current Report on Form 8-K filed on January 23, 2014.
3.4	Amended and Restated Bylaws of the company. Incorporated by reference to Exhibit 3.2 to the company’s Current Report on Form 8-K filed on September 7, 2012.
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 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 4.2 to the company’s Current Report on Form 8-K filed on September 7, 2012.
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	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, GOT WAT MAC Segregated Portfolio, 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.
4.5	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.
4.6	Par Petroleum Corporation 2012 Long Term Incentive Plan. Incorporated by reference to Exhibit 4.1 to the company’s Registration Statement on Form S-8 filed on December 21, 2012.*
10.1	Delayed Draw Term Loan Credit Agreement dated as of August 31, 2012, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jefferies Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.2	First Amendment to Delayed Draw Term Loan Credit Agreement, Joinder, Waiver, Consent and Omnibus Amendment Agreement dated as of September 28, 2012, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jefferies Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.2 to the Company’s Annual Report on Form 10-K filed on March 27, 2013.

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10.3	Waiver and Second Amendment to Delayed Draw Term Loan Credit Agreement, Joinder, Waiver, Consent and Omnibus Amendment Agreement dated as of November 29, 2012, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jefferies Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.3 to the Company’s Annual Report on Form 10-K filed on March 27, 2013.
10.4	Third Amendment to Delayed Draw Term Loan Credit Agreement, Joinder, Waiver, Consent and Omnibus Amendment Agreement dated as of December 28, 2012, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jefferies Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on January 3, 2013.
10.5	Fourth Amendment to Delayed Draw Term Loan Credit Agreement dated as of April 19, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jefferies Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on April 22, 2013.
10.6	Fifth Amendment to Delayed Draw Term Loan Credit Agreement dated as of June 4, 2013, by and among the company, the Guarantors party thereto, the lenders party thereto and Jeffries Finance LLC, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.2 to the company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013, filed on August 14, 2013.
10.7	Sixth Amendment to Delayed Draw Term Loan Agreement dated as of June 12, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.2 to the company’s Current Report on Form 8-K filed on June 17, 2013.
10.8	Seventh Amendment to Delayed Draw Term Loan Agreement dated as of June 17, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.3 to the company’s Current Report on Form 8-K filed on June 17, 2013.
10.9	Eighth Amendment to Delayed Draw Term Loan Agreement dated as of June 14, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.1 to the company’s Current Report on Form 8-K filed on June 24, 2013.
10.10	Ninth Amendment to Delayed Draw Term Loan Agreement dated as of August 1, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.10 to the company’s Registration Statement on Form S-1 filed on November 22, 2013.
10.11	Tenth Amendment to Delayed Draw Term Loan Agreement dated as of September 25, 2013, by and among the company, the Guarantors party thereto, the Lenders party thereto and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.8 to the company’s Current Report on Form 8-K filed on September 27, 2014.
10.12	Eleventh Amendment to Delayed Draw Term Loan Agreement dated as of January 23, 2014, by and among the company, the Guarantors party thereto, ZCOF Par Petroleum Holdings, L.L.C. and Jeffries Finance, LLC, as administrative agent for the Lenders, Incorporated by reference 10.1 to the company’s Current Report on Form 8-K filed on January 23, 2014.
10.13	Amended and Restated Limited Liability company Agreement for Piceance Energy, LLC. Incorporated by reference to Exhibit 10.2 to the company’s Current Report on Form 8-K filed on September 7, 2012.

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10.14	Credit Agreement dated as of June 4, 2012 among Piceance Energy, LLC, the financial institutions party thereto, JPMorgan Chase Bank, N.A., as administrative agent, and Wells Fargo Bank, National Association, as syndication agent. Incorporated by reference to Exhibit 10.3 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.15	First Amendment to Credit Agreement dated August 31, 2012, by and among Piceance Energy, LLC, the financial institutions party thereto, and JPMorgan Chase Bank, N.A. Incorporated by reference to Exhibit 10.4 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.16	Wapiti Recovery Trust Agreement dated August 27, 2012, by and among the company, DPCA LLC, Delta Exploration company, Inc., Delta Pipeline, LLC, DLC, Inc., CEC, Inc., Castle Texas Production Limited Partnership, Amber Resources company of Colorado, Castle Exploration company, Inc. and John T. Young. Incorporated by reference to Exhibit 10.5 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.17	Delta Petroleum General Recovery Trust Agreement dated August 27, 2012, by and among the company, DPCA LLC, Delta Exploration company, Inc., Delta Pipeline, LLC, DLC, Inc., CEC, Inc., Castle Texas Production Limited. Partnership, Amber Resources company of Colorado, Castle Exploration company, Inc. and John T. Young. Incorporated by reference to Exhibit 10.6 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.18	Pledge Agreement dated August 31, 2012, by Par Piceance Energy Equity LLC in favor of Jefferies Finance LLC. Incorporated by reference to Exhibit 10.7 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.19	Intercreditor Agreement dated August 31, 2012, by and among JP Morgan Chase Bank, N.A., as administrative agent for the First Priority Secured Parties (as defined therein), Jefferies Finance LLC, as administrative agent for the Second Priority Secured Parties (as defined therein), the company and Par Piceance Energy Equity LLC. Incorporated by reference to Exhibit 10.8 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.20	Pledge and Security Agreement, dated August 31, 2012, by the company and certain of its subsidiaries in favor of Jefferies Finance LLC. Incorporated by reference to Exhibit 10.9 to the company’s Current Report on Form 8-K filed on September 7, 2012.
10.21	Letter of Credit Facility Agreement dated as of December 27, 2012, by and between the company and Compass Bank. Incorporated by reference to Exhibit 10.2 to the company’s Current Report on Form 8-K filed on January 3, 2013.
10.22	Form of Indemnification Agreement between the company and its Directors and Executive Officers. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on October 19, 2012.*
10.23	Uncommitted Credit Agreement dated as of June 12, 2013, by and among Texadian Energy, Inc., Texadian Energy Canada Limited and BNP Paribas. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed in June 17, 2013.
10.24	Common Stock Purchase Agreement dated effective as of September 10, 2013, by and among the company and the Purchasers party thereto. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed in September 13, 2013.
10.25	Letter Agreement dated as of September 17, 2013 but effective as of January 1, 2013, by and between Whitebox Advisors, LLC and the company. Incorporated by reference to Exhibit 10.18 to the company’s Quarterly Report on Form 10-Q filed on November 14, 2013.

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10.26	Letter Agreement dated as of September 17, 2013 but effective as of January 1, 2013, by and between Equity Group Investments and the company. Incorporated by reference to Exhibit 10.17 to the company’s Quarterly Report on Form 10-Q filed on November 14, 2013.
10.27	Framework Agreement dated as of September 25, 2013, by and among Hawaii Pacific Energy, LLC, Tesoro Hawaii, LLC and Barclays Bank PLC. Incorporated by reference to Exhibit 10.1 to the company’s Quarterly Report on Form 80K filed on September 27, 2013.
10.28	Storage and Services Agreement dated as of September 25, 2013, by and among Tesoro Hawaii, LLC and Barclays Bank PLC. Incorporated by reference to Exhibit 10.2 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.29	Agency and Advisory Agreement dated as of September 25, 2013, by and among Tesoro Hawaii, LLC and Barclays Bank PLC. Incorporated by reference to Exhibit 10.3 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.30	Inventory First Lien Security Agreement dated as of September 25, 2013, by and among Tesoro Hawaii, LLC and Wells Fargo Bank, N.A, as inventory collateral agent. Incorporated by reference to Exhibit 10.4 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.31	First Lien Mortgage dated as of September 25, 2013, by and among Tesoro Hawaii, LLC and Wells Fargo Bank, N.A, as inventory collateral agent. Incorporated by reference to Exhibit 10.5 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.32	Intercreditor Agreement dated as of September 25, 2013, by and among Barclays Bank PLC, Wells Fargo Bank, N.A, as inventory collateral agent, Deutsche Bank AG New York Branch, as ABL loan collateral agent and as administrative agent pursuant to the ABL Credit Agreement, Hawaii Pacific Energy, LLC, and Tesoro Hawaii, LLC. Incorporated by reference to Exhibit 10.6 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.33	Membership Interests First Lien Pledge Agreement dated as of September 25, 2013, by and between Hawaii Pacific Energy, LLC and Wells Fargo Bank, N.A, as inventory collateral agent. Incorporated by reference to Exhibit 10.7 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.34	ABL Credit Agreement dated as of September 25, 2013, by and among Tesoro Hawaii, LLC and other borrowers party thereto, Hawaii Pacific Energy, LLC, the Lenders party thereto and Deutsche Bank AG New York Branch, as administrative agent and ABL loan collateral agent. Incorporated by reference to Exhibit 10.9 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.35	ABL Loan Second Lien Security Agreement dated as of September 25, 2013, by and between Tesoro Hawaii, LLC and Wells Fargo Bank, National Association, as inventory collateral agent. Incorporated by reference to Exhibit 10.10 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.36	ABL Loan First Lien Security Agreement dated as of September 25, 2013, by and between Tesoro Hawaii, LLC and Deutsche Bank AG New York Branch, as ABL loan collateral agent. Incorporated by reference to Exhibit 10.11 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.37	Second Lien Mortgage dated as of September 25, 2013, by and between Tesoro Hawaii, LLC and Deutsche Bank AG New York Branch, as collateral agent. Incorporated by reference to Exhibit 10.12 to the company’s Current Report on Form 8-K filed on September 27, 2013.

26

10.38	Membership Interests Second Lien Pledge Agreement dated as of September 25, 2013, by and between Hawaii Pacific Energy, LLC and Deutsche Bank AG New York Branch, as ABL loan collateral agent. Incorporated by reference to Exhibit 10.13 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.39	Inventory Second Lien Security Agreement dated as of September 25, 2013, by and between Tesoro Hawaii, LLC and Deutsche Bank AG New York Branch, as collateral agent. Incorporated by reference to Exhibit 10.14 to the company’s Current Report on Form 8-K filed on September 27, 2013.
10.40	Environmental Agreement dated as of September 25, 2013, by and among Tesoro Corporation, Tesoro Hawaii, LLC and Hawaii Pacific Energy, LLC. Incorporated by reference to Exhibit 10.16 to the company’s Quarterly Report on Form 10-Q filed on November 14, 2013.
10.41	Credit Agreement dated as of November 14, 2013, by and among the company, the Lenders party thereto and Bank of Hawaii, as administrative agent for the Lenders. Incorporated by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on November 19, 2013.
14.1	Par Petroleum Corporation Code of Business Conduct and Ethics for Employees, Executive Officers and Directors, effective October 15, 2012. Incorporated by reference to Exhibit 14.1 to the company’s Current Report on Form 8-K filed on October 19, 2012.
21.1	Subsidiaries of the Registrant. Incorporated by reference to Exhibit 21.1 to the company’s Annual Report on Form 10-K filed on March 31, 2014.
23.1	Consent of Deloitte & Touche LLP**
23.2	Consent of EKS&H LLLP**
23.3	Consent of KPMG LLP**
23.4	Consent of Netherland, Sewell & Associates, Inc.**
31.1	Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
31.2	Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
32.1	Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350.**
32.2	Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350.**
99.1	Report of Netherland, Sewell & Associates, Inc. regarding the registrants Proved Reserves as of December 31, 2013. Incorporated by reference to Exhibit 99.1 to the company’s Annual Report on Form 10-K filed on March 31, 2014.
99.2	Agreement of Settlement and Release dated September 19, 2012, by and between The Wapiti Recovery Trust and Wapiti Oil & Gas, L.L.C. Incorporated by reference to Exhibit 99.1 to the company’s Current Report on Form 8-K filed on September 25, 2013.
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.

27

* Management contracts and compensatory plans.

** Filed herewith.

*** Schedules and similar attachments to this agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The company will furnish supplementally a copy of any omitted schedule or similar attachment to the Securities and Exchange Commission upon request.

28

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

Par Petroleum Corporation

Houston, Texas

We have audited the accompanying consolidated balance sheet of Par Petroleum Corporation and subsidiaries (the “Company”) as of December 31, 2013, and the related consolidated statements of operations, changes in stockholders’ equity, and cash flows for the year then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements based on our audit. We did not audit the financial statements of Piceance Energy, LLC, an equity method investee of the Company. The Company’s investment in Piceance Energy, LLC constitutes 13% of consolidated total assets as of December 31, 2013, and the Company’s interest in the net loss of Piceance Energy, LLC constitutes 4% of consolidated net loss for the year ended December 31, 2013. The financial statements of Piceance Energy, LLC were audited by other auditors whose report has been furnished to us, and our opinion, insofar as it relates to the amounts included for Piceance Energy, LLC, is based solely on the report of the other auditors.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit and the report of the other auditors provide a reasonable basis for our opinion.

In our opinion, based on our audit and the report of the other auditors, such consolidated financial statements present fairly, in all material respects, the financial position of Par Petroleum Corporation and subsidiaries as of December 31, 2013, and the results of their operations and their cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.

As discussed in the Introductory Note to the consolidated financial statements, the accompanying 2013 consolidated financial statements have been restated to correct a misstatement.

/s/ DELOITTE & TOUCHE LLP

Houston, Texas

March 31, 2014 (May 30, 2014 as to the effects of the restatement discussed in the Introductory Note)

F-1

Report of Independent Registered Public Accounting Firm

To the Members of

Piceance Energy, LLC

Denver, Colorado

We have audited the balance sheet of Piceance Energy, LLC (the “company”) as of December 31, 2013, and the related statements of operations, members’ equity, and cash flows for the year then ended, and the related notes to the financial statements (not separately included herein). These financial statements are the responsibility of the company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audits in accordance with the standards of the Public company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. The company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Piceance Energy, LLC as of December 31, 2013 and the results of its operations and its cash flows for the year then ended December 31, 2013 in conformity with accounting principles generally accepted in the United States of America.

/s/ EKS&H LLLP

EKS&H LLLP

February 28, 2014

Denver, Colorado

F-2

Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders

Par Petroleum Corporation

We have audited the accompanying consolidated balance sheet of Par Petroleum Corporation and subsidiaries (the “company”) as of December 31, 2012 (Successor), and the related consolidated statements of operations, changes in stockholders’ equity, and cash flows for the period from September 1, 2012 through December 31, 2012 (Successor). These financial statements are the responsibility of the company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The company is not required to have, nor were engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Par Petroleum Corporation and subsidiaries as of December 31, 2012 (Successor), and the results of their operations and their cash flows for the period from September 1, 2012 through December 31, 2012 (Successor), in conformity with accounting principles generally accepted in the United States of America.

As discussed in Notes 1 and 2 to the financial statements, the company entered into a plan of reorganization and emerged from bankruptcy on August 31, 2012. As a result of the reorganization, the company applied fresh start accounting and the consolidated financial statements for the period after the reorganization date are presented on a different cost basis than that for the periods before the reorganization and, therefore, are not comparable.

/s/ EKS&H LLLP

EKS&H LLLP

Denver, Colorado

March 27, 2013, except for Note 14, as to which the date is March 31, 2014

F-3

Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders

Delta Petroleum Corporation

We have audited the accompanying consolidated statements of operations, changes in stockholders’ equity and cash flows of Par Petroleum Corporation (formerly Delta Petroleum Corporation) and subsidiaries (the Predecessor) for the period from January 1, 2012 through August 31, 2012. These consolidated financial statements are the responsibility of the company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audit in accordance with the standards of the Public company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the results of operations and cash flows of Par Petroleum Corporation (formerly Delta Petroleum Corporation) and subsidiaries (the Predecessor) for the period from January 1, 2012 through August 31, 2012, in conformity with U.S. generally accepted accounting principles.

As discussed in Note 1 to the consolidated financial statements, the Predecessor filed a petition for reorganization under Chapter 11 of the United States Bankruptcy Code on December 16, 2011. The Predecessor’s plan of reorganization became effective and the Predecessor emerged from bankruptcy protection on August 31, 2012. In connection with its emergence from bankruptcy, the company adopted the guidance for fresh start accounting in conformity with FASB ASC Topic 852, Reorganizations, effective as of August 31, 2012. Accordingly, the company’s consolidated financial statements prior to August 31, 2012 are not comparable to its consolidated financial statements for periods after August 31, 2012.

/s/ KPMG LLP

KPMG LLP

Denver, Colorado

March 27, 2013

F-4

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

	December 31, 2013			December 31, 2012
	(Restated - See Introductory Note)
ASSETS
Current assets
Cash and cash equivalents	$	38,061		$	6,185
Restricted cash		802			23,970
Trade accounts receivable		117,493			17,730
Inventories		380,623			10,466
Prepaid and other current assets		7,522			1,575
Total current assets		544,501			59,926
Property and equipment
Property, plant and equipment		107,623			1,415
Proved oil and gas properties, at cost, successful efforts method of accounting		4,949			4,804
Total property and equipment		112,572			6,219
Less accumulated depreciation, depletion and amortization		(3,968	)		(373	)
Property and equipment, net		108,604			5,846
Long-term assets
Investments in unconsolidated affiliate		101,796			104,434
Intangible assets, net		11,170			8,809
Goodwill		20,603			7,756
Assets held for sale		—			2,800
Other long-term assets		26,539			11
Total assets	$	813,213		$	189,582
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current maturities of long-term debt	$	3,250		$	35,000
Obligations under supply and exchange agreements		385,519			—
Accounts payable		28,870			25,329
Other accrued liabilities		31,956			981
Accrued settlement claims		3,793			8,667
Total current liabilities		453,388			69,977
Long-term liabilities
Long-term debt		94,030			7,391
Derivative liabilities		17,336			10,945
Long-term capital lease obligations		1,526			—
Deferred tax liability		216			—
Contingent consideration liability		11,980			—
Other liabilities		6,473			512
Total liabilities		584,949			88,825
Commitments and contingencies (Note 13)
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 and 300,000,000 shares authorized at December 31, 2013 and 2012, respectively, 30,151,000 shares and 15,008,092 shares issued at December 31, 2013 and 2012, respectively		301			150
Additional paid-in capital		315,975			109,446
Accumulated deficit		(88,012	)		(8,839	)
Total stockholders’ equity		228,264			100,757
Total liabilities and stockholders’ equity	$	813,213		$	189,582

See accompanying notes to consolidated financial statements.

F-5

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share amounts)

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1, 2012 through August 31, 2012
	(Restated - See Introductory Note)
Revenues
Refining, distribution and marketing revenues	$	778,126		$	—		$	—
Commodity marketing and logistics revenues		100,149			—			—
Oil and gas sales		7,739			2,144			23,079
Total operating revenues		886,014			2,144			23,079
Operating expenses
Cost of revenues		857,476			—			—
Operating expense, excluding depreciation, depletion and amortization expense shown separately below		27,251			—			—
Lease operating expense		5,627			1,684			9,038
Transportation expense		—			—			6,963
Production taxes		49			4			979
Exploration expense		—			—			2
Dry hole costs and impairments		—			—			151,347
Depreciation, depletion and amortization		5,982			401			16,041
Trust litigation and settlements		6,206			—			—
General and administrative expense		21,494			4,520			9,386
Acquisition and integration costs		9,794			556			—
Total operating expenses		933,879			7,165			193,756
Operating loss		(47,865	)		(5,021	)		(170,677	)
Other income and (expense):
Interest expense and financing costs, net		(19,471	)		(1,056	)		(6,852	)
Other income		808			86			516
Change in value of common stock warrants		(10,114	)		(4,280	)
Gain on derivative instruments, net		410			—			—
Loss from unconsolidated affiliates		(2,941	)		(1,325	)		(20	)
Total other expense		(31,308	)		(6,575	)		(6,356	)
Loss before income taxes and reorganization items		(79,173	)		(11,596	)		(177,033	)
Income tax benefit		—			(2,757	)		—
Loss before reorganization items		(79,173	)		(8,839	)		(177,033	)
Reorganization items
Professional fees and administrative costs		—			—			22,354
Changes in asset fair values due to fresh start accounting adjustments		—			—			14,765
Gain on settlement of senior debt		—			—			(166,144	)
Gain on settlement of liabilities		—			—			(2,571	)
Net loss	$	(79,173	)	$	(8,839	)	$	(45,437	)
Basic loss per common share	$	(4.01	)	$	(0.56	)	$	(1.57	)
Diluted loss per common share	$	(4.01	)	$	(0.56	)	$	(1.57	)
Weighted average number of shares outstanding:
Basic		19,740			15,734			28,841
Diluted		19,740			15,734			28,841

See accompanying notes to consolidated financial statements.

F-6

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(In thousands)

							Additional
	Common Stock						paid-in			Accumulated			Total
	Shares			Amount			capital			Deficit			Equity
Balance, January 1, 2012 (Predecessor)		28,841		$	288		$	1,641,390		$	(1,591,453	)	$	50,225
Net loss		—			—			—			(45,437	)		(45,437	)
Forfeitures		(58	)		—			—			—			—
Stock-based compensation		—			—			1,895			—			1,895
Balance, August 31, 2012 (Predecessor)		28,783			288			1,643,285			(1,636,890	)		6,683
Cancellation of predecessor common stock		(28,783	)		(288	)		288			—			—
Elimination of predecessor accumulated deficit		—			—			(1,636,890	)		1,636,890			—
Issuance of common stock and fresh start accounting upon emergence from Chapter 11		14,766			148			102,731			—			102,879
Balance, August 31, 2012 (Successor)		14,766			148			109,414			—			109,562
Stock issued to settle bankruptcy claims		20			—			—			—			—
Stock-based compensation		222			2			32			—			34
Net loss		—			—			—			(8,839	)		(8,839	)
Balance, December 31, 2012 (Successor)		15,008			150			109,446			(8,839	)		100,757
Stock issued in a private transaction, net of offering cost of $830		14,388			144			199,026			—			199,170
Stock issued to settle bankruptcy claims		209			2			2,603			—			2,605
Stock issued through exercise of warrants		184			2			3,739			—			3,741
Stock-based compensation		362			3			1,161			—			1,164
Net loss (Restated - See Introductory Note)		—			—			—			(79,173	)		(79,173	)
Balance, December 31, 2013 (Successor) (Restated - See Introductory Note)		30,151		$	301		$	315,975		$	(88,012	)	$	228,264

See accompanying notes to consolidated financial statements.

F-7

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1 through August 31, 2012
	(Restated - See Introductory Note)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(79,173	)	$	(8,839	)	$	(45,437	)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation, depletion, amortization and accretion		5,982			401			16,041
Non cash interest expense		16,742			1,056			2,989
Change in asset values due to fresh - start accounting adjustments		—			—			14,765
Gain on extinguishment of senior debt		—			—			(166,144	)
Gain on settlement of liabilities		—			—			(2,188	)
(Gain) loss on property sales		(50	)		(82	)		126
Dry hole costs and impairments		—			—			151,347
Stock-based compensation		1,161			34			1,895
Change in value of common stock warrants		10,114			4,280			—
Loss from unconsolidated affiliates		2,941			1,325			20
Deferred income tax expense (benefit)		179			(2,757	)		—
Other		—			—			(699	)
Net changes in operating assets and liabilities:
Trade accounts receivable		(40,278	)		(2,234	)		3,472
Prepaids and other current assets		(2,569	)		(538	)		(1,378	)
Inventories		48,593			—			—
Accounts payable		15,829			2,718			(4,187	)
Supply and exchange agreements		(18,381	)		—			—
Settlement liability		1,898			—			—
Accrued reorganization costs		—			—			9,116
Other accrued liabilities		1,335			—			—
Net cash used in operating activities		(35,677	)		(4,636	)		(20,262	)
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures		(7,768	)		—			(1,613	)
Acquisitions, net of cash acquired		(559,279	)		(17,439	)		—
Proceeds from asset sales		2,850			—			74,209
Proceeds from sale of other fixed assets		—			39			26
Capitalized drilling costs paid to operator		(303	)		(415	)		—
Proceeds from sale of unconsolidated affiliates		—			125			—
Net cash (used in) provided by investing activities		(564,500	)		(17,690	)		72,622
CASH FLOWS FROM FINANCING ACTIVITIES:
Funding of purchase of HIE from supply and exchange agreements		378,238			—			—
Proceeds from sale of common stock, net of offering costs		199,170			—			—
Proceeds from exercise of common stock warrants		18			—			—
Proceeds from borrowings		159,800			35,000			23,000
Repayments of borrowings		(121,909	)		—			(59,535	)
Payment of deferred loan costs		(2,264	)		—			—
Fund distribution agent account		—			—			(21,805	)
Proceeds from (funding of) Wapiti and General Recovery Trusts		—			2,446			(2,000	)
Recoveries from bankruptcy settlements		—			5,183			—
Restricted cash released from (held to) secure letter of credits		19,000			(19,000	)		—
Net cash provided by (used in) financing activities		632,053			23,629			(60,340	)
Net increase (decrease) in cash and cash equivalents		31,876			1,303			(7,980	)
Cash at beginning of period		6,185			4,882			12,862
Cash at end of period	$	38,061		$	6,185		$	4,882
SUPPLEMENTAL CASH FLOW INFORMATION
Cash paid for interest and financing costs	$	2,186		$	—		$	3,745
NON-CASH INVESTING AND FINANCING ACTIVITIES
Stock issued used to settle bankruptcy claims	$	2,605		$	—		$	—
Interest payable capitalized to principal balance	$	6,096		$	—		$	—
Non-cash additions to property, plant and equipment	$	—		$	209		$	—

See accompanying notes to consolidated financial statements.

F-8

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements

Introductory Note

These consolidated financial statements reflect the restatement of our previously issued financial statements included in our Annual Report on Form 10-K and Amendment No. 1 on Form 10-K/A for the period ended December 31, 2013. The restatement relates to an $8.6 million understatement of cost of revenues and net loss ($0.44 per common share). The restatement had no impact on net cash flow used in operations.

We determine our inventory balance and our obligations under supply and exchange agreements based on physical inventory observations each reporting period. During May 2014, we determined that we did not appropriately consider an adjustment to the measurements taken during the physical inventory observation that occurred on December 31, 2013. This overstatement of inventory volumes also impacted our monthly settlement under our supply and exchange agreements, resulting in a decrease to our trade receivables. The increase in net loss had no impact on income tax expense due to the valuation allowance on our deferred tax assets.

The table below summarizes the effects of the error on our consolidated financial statements (in thousands):

	As Previously Reported			Adjustment			As Restated
Consolidated Balance Sheet
Trade accounts receivable	$	122,913		$	(5,420	)	$	117,493
Inventories		389,075			(8,452	)		380,623
Total current assets		558,373			(13,872	)		544,501
Total assets		827,085			(13,872	)		813,213
Obligations under supply and exchange agreements		390,839			(5,320	)		385,519
Total current liabilities		458,708			(5,320	)		453,388
Total liabilities		590,269			(5,320	)		584,949
Accumulated deficit		(79,460	)		(8,552	)		(88,012	)
Total stockholders’ equity		236,816			(8,552	)		228,264
Total liabilities and stockholders’ equity	$	827,085		$	(13,872	)	$	813,213
Consolidated Statement of Operations
Cost of revenues	$	848,924		$	8,552		$	857,476
Total operating expenses		925,327			8,552			933,879
Operating loss		(39,313	)		(8,552	)		(47,865	)
Loss before income taxes and reorganization items		(70,621	)		(8,552	)		(79,173	)
Loss before reorganization items		(70,621	)		(8,552	)		(79,173	)
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Basic loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Diluted loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Consolidated Statement of Cash Flows
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Net changes in operating assets and liabilities:
Trade accounts receivable		(45,698	)		5,420			(40,278	)
Inventories		40,141			8,452			48,593
Supply and exchange agreements	$	(13,061	)	$	(5,320	)	$	(18,381	)

Please note that these financial statements and the notes thereto do not reflect events occurring after March 31, 2014 (the date of the original Form 10-K). For a description of these events, please read our Exchange Act reports filed since March 31, 2014, including our Current Reports on Form 8-K and any amendments thereto.

F-9

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 1 - Overview

We are a diversified energy holding company based in Houston, Texas (OTCQB:PARR). We were created through the successful reorganization of Delta Petroleum in August 2012. The reorganization converted approximately $265 million of unsecured debt to equity and allowed us to preserve significant tax attributes. Currently, we operate in three segments: (i) refining, distribution and marketing, (ii) natural gas and oil operations and (iii) commodity marketing and logistics operations.

Our refining, distribution and marketing segment consists of a refinery in Kapolei, Hawaii. The refinery produces ultra-low sulfur diesel, gasoline, jet fuel, marine fuel and other associated refined products primarily for consumption in Hawaii. Our refinery logistics assets include refined products terminals, pipelines, a single point mooring and other associated logistics assets. In addition, we distribute products though 31 branded retail outlets located across the islands of Oahu, Maui and Hawaii. The refining, distribution and marketing segment was established through the acquisition of Hawaii Independent Energy, LLC (“HIE”) (formerly known as Tesoro Hawaii, LLC (“Tesoro Hawaii”)) in September 2013 for approximately $75 million in cash, plus net working capital and inventories and certain contingent earn out payments of up to approximately $40 million (the “HIE Acquisition”). As part of the purchase price, we also funded $24.3 million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing.

Our natural gas and oil operations consist primarily of a 33.34% interest in Piceance Energy, LLC (“Piceance Energy”) (Note 3 - Investment in Piceance Energy). Piceance Energy is a joint venture with Laramie Energy II, LLC (“Laramie”), who owns the remaining interest and manages the day to day operations of the joint venture. Laramie is a Denver-based company primarily focused on finding and developing natural gas reserves from unconventional gas reservoirs within the Rocky Mountain region. Piceance Energy was formed and capitalized in August 2012 when we and Laramie Energy contributed oil and natural gas assets, surface real estate, and other related assets located in the Piceance Basin geological province of Colorado to the joint venture entity.

Our commodity marketing and logistics segment focuses on sourcing, marketing, transportation and distribution of crude oil and refined products. Our logistics capability consists of historical pipeline shipping status, a rail car fleet, and expertise in contracted chartering of tows and barges, with the capability of moving crude oil from land-locked locations in the Western U.S. and Canada to the refining hubs in the Midwest, the Gulf Coast, and the East Coast regions of the U.S. The commodity marketing and logistics operations segment was established through the acquisition of Texadian Energy, Inc. (“Texadian”) (formerly known as SEACOR Energy, Inc.) in December 2012 for approximately $14 million in cash, plus approximately $3 million in working capital.

As a result of these transactions, our results of operations for any period after December 31, 2013 will not be comparable to any prior period.

On January 23, 2014, we amended and restated our certificate of incorporation to implement a one-for-ten (1:10) reverse stock split of our issued and outstanding common stock, par value $0.01 per share. All references in the financial statements to the number of shares of common stock or warrants, price per share and weighted average number of common stock outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor (see Note 20 - Subsequent Events).

F-10

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

To generate earnings and cash flows from operations, the Company’s refining, distribution and marketing segment is primarily dependent upon processing crude oil and selling refined petroleum products at margins sufficient to cover fixed and variable costs and other expenses. Crude oil and refined petroleum products are commodities and factors largely out of the Company’s control can cause prices to vary over time.

Note 2 - Summary of Significant Accounting Policies

Principles of Consolidation and Basis of Presentation

The consolidated financial statements include the accounts of Par Petroleum Corporation and its consolidated subsidiaries. All inter-company balances and transactions have been eliminated in consolidation. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.

Our wholly-owned subsidiaries include Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”) which acquired all of the outstanding membership interests of HIE on September 25, 2013 (see Note 4 - Acquisitions and Dispositions), Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3 - Investment in Piceance Energy) and Texadian, which we acquired on December 31, 2012 (see Note 4 - Acquisitions and Dispositions). Certain amounts from prior periods have been reclassified to conform to the current presentation.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include fair value of assets and liabilities recorded in connection with the application of fresh-start reporting or acquisitions, natural gas and oil reserves, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, bad debts, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

Fresh-Start Reporting and the Effects of the Plan

Certain companies qualify for fresh-start reporting in connection with their emergence from bankruptcy. Fresh-start reporting is appropriate on the emergence from bankruptcy if the reorganization value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims, and if the holders of existing voting shares immediately before confirmation receive less than 50 percent of the voting shares of the emerging entity. We met these requirements on August 31, 2012 and adopted fresh-start reporting resulting in the creation of a new reporting entity.

The bankruptcy court issued a confirmation order approving our plan of reorganization (the “Plan”) on August 15, 2012 and we met the requirements of the Plan on August 31, 2012. Under the requirements of fresh-start reporting, we have adjusted our assets and liabilities to their estimated fair values as of August 31, 2012 in conformity with the guidance for the acquisition method of accounting for business combinations. The net effect of all fresh-start adjustments, including the effects of implementing the plan, resulted in a gain of approximately $154 million, which is reflected in the 2012 Predecessor Period. The application of the fresh-start reporting provisions created a new reporting entity having no retained earnings nor accumulated deficit.

Our fresh-start adjustments consisted primarily of (i) estimates of the fair value of our minority interest in Piceance Energy and (ii) of the fair value of our remaining existing fixed assets and liabilities. A description of the adjustments and amounts is provided in Note 19 - Reorganization under Chapter 11, Fresh-Start Reporting and the Effects of the Plan.

F-11

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Cash and Cash Equivalents

Cash and cash equivalents consist of demand deposits and funds invested in highly liquid short-term investments with original maturities of three months or less.

Restricted Cash

Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to bankruptcy matters and cash held at commercial banks to support letter of credit facilities.

Allowance for Doubtful Accounts

We establish provisions for losses on trade receivables if it becomes probable we will not collect all or part of the outstanding balances. We review collectability and establish or adjust our allowance as necessary using the specific identification method. As of December 31, 2013 and 2012, we had no significant allowance for doubtful accounts.

Refined Product Exchanges

We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.

Inventories

Commodity inventories are stated at the lower of cost or market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 9 - Supply and Exchange Agreements. The crude oil remains in the legal title of Barclays and is stored in HIE’s storage tanks governed by a storage agreement. Legal title to the crude oil passes to HIE at the tank outlet. After processing, Barclays takes title to the refined products when the refined products enter the tanks which are then stored in HIE’s storage tanks until sold to HIE’s retail locations or to third parties. We record the inventory owned by Barclays on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties.

Investment in Unconsolidated Affiliate

We account for our investment in unconsolidated affiliate using the equity method as we have the ability to exert significant influence, but do not control the operating and financial policies. Our proportionate share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations. Investment in unconsolidated affiliate is reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

At December 31, 2013 and 2012, our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3 - Investment in Piceance Energy.)

Property, Plant and Equipment (Other than Natural Gas and Oil Properties)

We capitalize the cost of additions, major improvements and modifications to property, plant and equipment. The cost of repairs and normal maintenance of property, plant and equipment is expensed as incurred. Major improvements and modifications of property, plant and equipment are those expenditures that either extend the useful life, increase the capacity or improve the operating efficiency of the asset, or improve the safety of our operations. We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of each asset as follows:

F-12

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Assets	Lives in Years
Refining	8 to 47
Logistic	3 to 30
Retail	14 to 18
Corporate	3 to 7
Software	3

We record property under capital leases at the lower of the present value of minimum lease payments using our incremental borrowing rate or the fair value of the leased property at the date of lease inception. We depreciate leasehold improvements and property acquired under capital leases over the shorter of the lease term or the economic life of the asset.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.

Natural Gas and Oil Properties

We account for our natural gas and oil exploration and development activities using the successful efforts method of accounting. Under such method, costs of productive exploratory wells, development dry holes and productive wells and undeveloped leases are capitalized. Natural gas and oil lease acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological or geophysical expenses and delay rentals for natural gas and oil leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, then evaluated quarterly and charged to expense if and when the well is determined not to have found reserves in commercial quantities. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of producing properties.

Unproved properties with significant acquisition costs are assessed quarterly on a property-by-property basis and any impairment in value is charged to expense. If the unproved properties are determined to be productive, the related costs are transferred to proved oil and natural gas properties and are depleted. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain or loss until all costs have been recovered.

Depreciation, depletion and amortization of capitalized acquisition, exploration and development costs is computed using the units-of-production method by individual fields (common reservoirs) using proved producing natural gas and oil reserves as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based on total proved natural gas and oil reserves as the related reserves are produced.

Our natural gas and oil assets are reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

Goodwill and Other Intangible Assets

Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that

F-13

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

the carrying value of a reporting unit exceeds its estimated fair value, a two-step quantitative test is required. If required, we will review the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment indicator exists and an estimate of the impairment loss is calculated.

Our intangible assets include relationships with suppliers and shippers, favorable railcar leases, trade names and trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist. When we believe impairment indicators may exist, projections of the undiscounted future cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values.

Asset Retirement Obligations

We record asset retirement obligations (“AROs”) in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the liability. Our AROs arise from our refining, distribution and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and oil operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in depreciation, depletion and amortization expense on our consolidated statement of operations and the related capitalized cost is depreciated over the asset’s useful life. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments in our statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives.

We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos), and removal or dismantlement requirements associated with the closure of our refining facility, terminal facilities or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines or other equipment.

Environmental Matters

We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and environmental expenses are recorded in operating expenses in our consolidated statements of operations.

Derivatives and Other Financial instruments

We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange traded futures contracts, collar agreements, swaps or options. The purpose of the transactions is to provide a measure of stability to our cash flows in an environment of volatile commodity prices.

F-14

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle. Should we not designate a contract as a normal purchase or normal sale then the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. As of December 31, 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.

In addition, from time to time we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.

As a part of the Plan of Reorganization, we issued warrants (see Note 10 - Debt) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in change in value of common stock warrants and loss on derivative instruments, net respectively, on our consolidated statement of operations.

Accrued Settlement Claims

We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy (See Note 13 - Commitments and Contingencies). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.

Income Taxes

We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard, and to the extent this threshold is not met, a valuation allowance is recorded.

We recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2010, 2011, and 2012. However, since we have net operating loss carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.

Stock Based Compensation

We recognize the cost of share-based payments over the period the employee provides service, generally the vesting period, and include such costs in general and administrative expense in the consolidated statements of operations. The fair value of equity instruments issued to employees is measured on the grant date and recognized over the service period on a straight-line basis.

F-15

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Revenue Recognition

We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met. These transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.

Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2013 and 2012, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of rail cars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the purchaser, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.

Refining, Distribution and Marketing. We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title and risk of loss is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We include transportation fees charged to customers in revenues in our statements of consolidated operations, while the related transportation costs are included in cost of sales. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.

Loss Per Share

Basic loss per share (“EPS”) is computed by dividing net loss by the sum of the weighted average number of common shares outstanding, and the weighted average number of shares issuable under the Warrants (see Note 16 - Loss Per Share). The Warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation of basic EPS as these shares are not considered earned until vesting occurs.

Foreign Currency Transactions

We may, on occasion, enter into transactions denominated in currencies other than our functional currency (“U.S. $”). Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in other income (expense) in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.

Note 3 - Investment in Piceance Energy

We account for our 33.34% ownership interest in Piceance Energy using the equity method of accounting because we are able to exert significant influence but do not control the operating and financial policies. The Piceance Energy LLC Agreement provides that its sole manager may make a written capital call such that each member shall make additional capital contributions up to an aggregate combined total capital contribution of $60 million ($20 million to our interest), if approved by a majority of its board. If any member does not fund its share of the capital call, its interest may be reduced or diluted by the amount of the shortfall. In

F-16

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

addition, Piceance Energy has a $400 million secured revolving credit facility secured by a lien on its natural gas and oil properties and related assets with a borrowing base currently set at $120 million. As of December 31, 2013, the balance outstanding on the revolving credit facility was approximately $90.2 million. We are guarantors of Piceance Energy’s credit facility, with recourse limited to the pledge of our equity interests of Par Piceance Energy. Under the terms of its credit facility, Piceance Energy is generally prohibited from making future cash distributions to its owners, including us.

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

				September 1
	Year Ended			through
	December 31, 2013			December 31, 2012
Beginning balance	$	104,434		$	105,344
Loss from unconsolidated affiliates		(3,516	)		(1,325	)
Accretion of basis difference		575			—
Capitalized drilling costs obligation paid		303			415
Ending balance	$	101,796		$	104,434

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

	December 31, 2013			December 31, 2012
Assets
Current assets	$	5,901		$	6,275
Non-current assets		454,402			460,991
Current liabilities		(13,040	)		(11,826	)
Non-current liabilities		(96,738	)		(94,369	)

	Year Ended			September 1 through
	December 31, 2013			December 31, 2012
	100%			100%
Oil, natural gas and natural gas liquids revenues	$	61,091		$	19,391
Loss from operations		(6,765	)		(2,095	)
Net loss		(10,546	)		(3,975	)

The net loss for the year ended December 31, 2013 includes $26.6 million and $770 thousand in DD&A expense and losses on derivative instruments, respectively. The net loss for the period from September 1 through December 31, 2012 include $8.5 million and $917 thousand of DD&A expense and losses on derivative instruments, respectively.

At December 31, 2013 and 2012, our equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment by approximately $15.1 million and $15.9 million, respectively. This difference arose due to lack of control and marketability discounts and we attributed it to natural gas and oil properties and will amortize the difference over 15 years based on the estimate of proved reserves at the date Piceance Energy was formed.

Note 4 - Acquisitions and Dispositions

We made our acquisitions in furtherance of our growth strategy that focuses on the acquisition of income producing businesses in order to monetize our net operating loss carryforwards.

Texadian Energy, Inc.

On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for $14 million plus estimated net working capital of approximately $3 million at closing resulting in approximately $17 million of cash paid at closing. Texadian operates an oil transportation, distribution and marketing business with significant logistics capabilities. The

F-17

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

purchase price for the acquisition was funded with a combination of cash and additional borrowings under the Tranche B Loan (see Note 10 - Debt). During 2013, the purchase price was reduced by $1.3 million due to funds received from SEACOR Holdings, Inc. for certain employee-related benefits.

The purchase was accounted for as a business combination whereby the purchase price is allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Texadian’s, and specifically utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. In addition, we recorded certain other identifiable intangible assets. These include relationships with suppliers and shippers and favorable railcar leases. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.

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

Intangible assets	$	8,809
Goodwill		6,990
Net non cash-working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	16,139

None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs of approximately $556 thousand are included in our consolidated statements of operations for the period ended December 31, 2012.

Hawaii Independent Energy, LLC

On June 17, 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, entered into a membership interest purchase agreement (the “HIE Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the HIE Purchase Agreement, Tesoro Hawaii. Pursuant to the HIE Purchase Agreement, on September 25, 2013 (the “Effective Date”), Hawaii Pacific Energy purchased from the Seller all of the issued and outstanding units representing the membership interests in Tesoro Hawaii (the “Purchased Units”), and indirectly thereby also acquired Tesoro Hawaii’s wholly-owned subsidiary, Smiley’s Super Service, Inc. Tesoro Hawaii owns and operates (i) a petroleum refinery located at the Campbell Industrial Park in Kapolei, Hawaii (the “Refinery”), (ii) certain pipeline assets, floating pipeline mooring equipment, and refined products terminals, and (iii) retail assets selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii. Following the acquisition, Tesoro Hawaii was renamed Hawaii Independent Energy, LLC (“HIE”).

Hawaii Pacific Energy acquired the Purchased Units for $75 million, paid in cash at the closing of the HIE Purchase Agreement, plus net working capital and inventories at closing and plus certain contingent earnout payments of up to $40 million. As a part of the purchase price, we also funded approximately $24.3 million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing. The earnout payments, if any, are to be paid annually following each of the three calendar years beginning January 1, 2014 through the year ending December 31, 2016, in an amount equal to 20% of the consolidated annual gross margin of HIE in excess of $165 million during such calendar years, with an annual cap of $20 million. In the event that the Refinery ceases operations or in the event Hawaii Pacific Energy disposes of any facility used in the acquired business, Hawaii Pacific Energy’s obligation to make earnout payments could be modified and/or accelerated as provided in the HIE Purchase Agreement. The purchase price was paid with a portion of the net proceeds from the sale of the shares of our common stock in a private transaction (see Note 14 - Stockholders’ Equity), amounts received pursuant to the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements) and the ABL Facility (see Note 10 - Debt).

We accounted for the acquisition of HIE as a business combination whereby the purchase price has been preliminary allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with HIE’s, and utilization of our net

F-18

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. In addition, we recorded certain other identifiable intangible assets. These include trade names and trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.

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

Inventory	$	418,750
Trade accounts receivable		59,485
Prepaids and other current assets		1,978
Property, plant and equipment		58,782
Land		39,800
Goodwill		13,613
Intangible assets		4,689
Accounts payable and other current liabilities		(18,154	)
Contingent consideration liability		(11,980	)
Other noncurrent liabilities		(6,384	)
Total	$	560,579

We are continuing to evaluate certain liabilities assumed in the acquisition, including those related to employee benefits. We have recorded a preliminary estimate of the liability and expect to finalize the purchase price allocation during 2014.

The acquisition was partially funded from proceeds totaling approximately $378.2 million from the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements). None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs totaled approximately $7 million are included in acquisition and integration costs our consolidated statement of operations for the year ended December 31, 2013.

Pro Forma Effects of the Acquisitions

The unaudited pro forma financial information presented below assumes that the Texadian and HIE acquisitions occurred as of January 1, 2012 and combines the Predecessor and Successor periods to include a full year of results for the year ended December 31, 2012. We did not include any adjustments related to the application of fresh-start reporting for the year ended December 31, 2012.

	2013			2012
(in millions)
Revenues	$	2,986.8		$	3,811.1
Net loss	$	(122.0	)	$	(12.0	)

Revenue and earnings for HIE subsequent to the acquisition are included in Note 17 - Segment Information.

Assets Contributed to Piceance Energy

At December 31, 2011, Delta’s oil and gas assets were classified as held for use and no impairment charges resulted from the analysis performed at December 31, 2011 as the estimated undiscounted net cash flows exceeded carrying amounts for all properties. In August 2012, the Bankruptcy Court approved a plan of sale of substantially all of the Predecessor’s assets and accordingly these assets were classified as held for sale and an impairment of approximately $151.3 million was recognized for the period from January 1, 2012 through August 31, 2012 to write-down these assets to fair value due to the application of fresh-start reporting. The assets were then contributed to Piceance Energy in accordance with our Plan of Reorganization.

F-19

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Assets Held for Sale

As of December 31, 2012, we classified certain compressors as held for sale, which were recorded at the lower of cost or estimated net realizable value. On February 20, 2013, these compressors were sold for approximately $2.9 million resulting in a gain of $50 thousand.

Note 5 - Property, Plant and Equipment

Major classes of property, plant and equipment consist of the following (in thousands):

	December 31,
	2013			2012
Land	$	39,800		$	—
Buildings and equipment		65,878			—
Other		1,945			1,415
Property, plant and equipment		107,623			1,415
Proved oil and gas properties		4,949			4,804
Less: accumulated depreciation, depletion and amortization		(3,968	)		(373	)
	$	108,604		$	5,846

Note 6 - Asset Retirement Obligations

The following is a reconciliation of our AROs (in thousands):

	Successor				Predecessor
			September 1		January 1
	Year Ended		through		through
	December 31, 2013		December 31, 2012		August 31, 2012
Asset retirement obligation - beginning of period	$	512	$	476	$	3,799
Obligation acquired		2,601		—		—
Accretion expense		59		36		178
Change in estimate		—		—		437
Settlement upon transfer to Piceance Energy		—		—		(3,938	)
Asset retirement obligation - end of period	$	3,172	$	512	$	476

As the result of the contribution of assets to Piceance Energy during the reorganization, approximately $3.9 million of our AROs was deemed settled as of the Emergence Date.

F-20

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 7 - Inventories

The following is a summary of our inventory (in thousands):

	December 31, 2013						December 31, 2012
	Titled Inventory		Supply and Exchange Agreements		Total		Titled Inventory
Crude oil and feedstocks	$	—	$	137,706	$	137,706	$	10,466
Refined products and blend stock		67,532		161,554		229,086		—
Spare parts, materials and supplies, and merchandise		13,831		—		13,831		—
	$	81,363	$	299,260	$	380,623	$	10,466

Note 8 - Intangible assets

Our intangible assets consist of the following (in thousands):

	December 31,
	2013			2012
Amortized intangible assets:
Gross carrying amount:
Supplier relationships	$	3,360		$	3,360
Rail car leases		3,249			3,249
Historical shipper status		2,200			2,200
Trade names and trademarks		4,689			—
Subtotal		13,498			8,809
Accumulated amortization
Supplier relationships		(258	)		—
Rail car leases		(650	)		—
Historical shipper status		(1,100	)		—
Trade name and trademarks		(320	)		—
Subtotal		(2,328	)		—
Net:
Supplier relationships		3,102			3,360
Rail car leases		2,599			3,249
Historical shipper status		1,100			2,200
Trade name and trademarks		4,369			—
Total amortized intangible assets, net	$	11,170		$	8,809

Amortization expense was approximately $2.3 million for the year ended December 31, 2013. There was no amortization expense during 2012. Expected future amortization expense for each of the next five years and thereafter is as follows (in thousands):

Year Ended	Amount
2014	$	3,571
2015		2,471
2016		2,151
2017		908
2018		258
Thereafter		1,811
	$	11,170

F-21

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

During the year ended December 31, 2013 the changes in the carrying amount of goodwill for the year ended December 31, 2013 were as follows (in thousands):

Balance at beginning of period	$	7,756
Additions		13,613
Texadian purchase price adjustments		(766	)
Balance at end of period	$	20,603

Note 9 - Supply and Exchange Agreements

HIE entered into several agreements with Barclays Bank PLC (“Barclays”), referred to collectively as the Supply and Exchange Agreements, on September 25, 2013 in connection with the acquisition of HIE. We entered into the Supply and Exchange Agreements for the purpose of managing our working capital and the crude oil and refined product inventory at the refinery.

Pursuant to the Supply and Exchange Agreements, Barclays holds title to all of the crude oil in the tanks at the refinery. Additionally, Barclays holds title to a majority of our refined product inventory in our tanks at the refinery. Barclays also prepaid us for certain inventory held at locations outside of our refinery. We hold title to the inventory during the refining process. Barclays sells the crude oil as it is discharged out of the refinery’s tanks. We exchange refined product owned by Barclays stored in our tanks for equal volumes of refined product produced by our refinery when we execute third party sales of refined product. We currently market and sell the refined product independently to third parties. The Supply and Exchange Agreements have an initial term of three years with two one-year renewal options.

As described in Note 2 - Summary of Significant Accounting Policies, we record the inventory owned by Barclays on our behalf because we maintain the risk of loss until the refined products are sold to third parties. Because we do not hold legal title to the crude oil inventory until it enters the refinery, we record a liability in an amount equal to the carrying value of the crude oil inventory. In accordance with the terms of the Supply and Exchange Agreements, the volume of refined products purchased by Barclays in connection with the acquisition of HIE is known as the “Block Volume”. To the extent we have refined products inventory volumes at period-end in excess of the Block Volume, we record a liability for the Block Volume valued at the per barrel carrying value of the refined product inventory owned by Barclays. From time to time, we may sell refined product inventory that causes our refined product inventory to be less than the Block Volume. To the extent of this shortfall, we record a liability for the volumes that we would need to purchase at current market prices in order to meet the Block Volume requirement. The liability related to the Supply and Exchange Agreements is included in obligations under supply and exchange agreements on our consolidated balance sheet.

For the year ended December 31, 2013, we incurred approximately $3.7 million in handling fees related to the Supply and Exchange Agreements, which is included in cost of revenues on our consolidated statement of operations. For the year ended December 31, 2013, interest expense and financing costs, net includes $1.4 million of expense related to the Supply and Exchange Agreements.

F-22

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 10 - Debt

Our debt is as follows (in thousands):

	December 31,
	2013			2012
Tranche B Loan	$	19,480		$	35,000
Delayed Draw Term Loan Agreement		—			13,465
ABL Facility		51,800			—
Retail Credit Agreement		26,000			—
Less: unamortized debt discount - warrants		—			(6,014	)
Less: unamortized debt discount - embedded derivative		—			(60	)
Total debt, net of unamortized debt discount		97,280			42,391
Less: current maturities		(3,250	)		(35,000	)
Long-term debt, net of current maturities and unamortized discount	$	94,030		$	7,391

Annual maturities of our long-term debt are due during the following years (in thousands):

Year	Amount Due
2014	$	3,250
2015		2,600
2016		22,080
2017		54,400
2018		2,600
Thereafter		12,350
	$	97,280

Delayed Draw Term Loan Credit Agreement

Pursuant to the Plan, on the Emergence Date, we and certain of our subsidiaries (the “Guarantors” and, together with the company, the “Loan Parties”) entered into a Delayed Draw Term Loan Credit Agreement (the “Loan Agreement”) with Jefferies Finance LLC, as administrative agent (the “Agent”) for the lenders party thereto from time to time, including WB Delta, Ltd., Waterstone Offshore ER Fund, Ltd., Prime Capital Master SPC, GOT WAT MAC Segregated Portfolio, 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 (collectively, the “Lenders”), pursuant to which the Lenders agreed to extend credit to us in the form of term loans (each, a “Loan” and collectively, the “Loans”) of up to $30 million. We borrowed $13 million on the Emergence Date in order to, along with the proceeds from the Contribution Agreement: (i) repay the loans and obligations due under the Predecessor’s secured debtor-in-possession credit facility, and (ii) pay allowed but unpaid administrative expenses to the Debtors related to the Plan. During 2013, we borrowed an additional $17 million for general corporate use. In November 2013, we repaid in full and terminated all of our obligations under the Loan Agreement, other than the New Tranche B Loans described below. Included in interest expense and financing cost, net on the consolidated statements of operations is $6.1 million recorded as loss on extinguishment of debt related to the November 2013 repayment.

Amendment to the Loan Agreement

On December 28, 2012, in order to fund a portion of the purchase price for our acquisition of Texadian Energy, the Loan Parties entered into an amendment to the Loan Agreement with the Agent and the Lenders, pursuant to which certain lenders (the “Tranche B Lenders”) agreed to extend additional borrowings to us (the “Tranche B Loan”). The total commitment of the Tranche B Loan of $35 million was drawn at closing. In addition to funding a portion of the purchase price of the acquisition of Texadian, the Tranche B Loan provided cash collateral for our former cash collateralized letter of credit facility. Pursuant to the Eighth Amendment to the Loan Agreement entered into on June 24, 2013, the Lenders refinanced and replaced the Tranche B Loan with new Tranche B Loans in the aggregate principal amount of $65 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Tranche B Loan, to make payments due under the membership interests purchase agreement in connection with the acquisition of HIE (the “HIE Purchase Agreement”), and for working capital and general corporate purposes.

F-23

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to the Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the HIE Purchase Agreement and the use of a portion of the proceeds from the Private Placement to fund a portion of the consideration for the acquisition of HIE and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the HIE Purchase Agreement, (iii) increased the interest rate applicable to certain of the loans, and (iv) amended certain provisions of the Loan Agreement and the other loan documents in connection with the consummation of the transactions contemplated by the HIE Purchase Agreement and the Private Placement (see Note 14 - Stockholder’s Equity).

The consent provided by the Lenders was conditioned on, among other things, (i) the repayment in full of the New Tranche B Loans owing to all Lenders except for ZCOF Par Petroleum Holdings, L.L.C., and a partial repayment of the New Tranche B Loans owing to ZCOF Par Petroleum Holdings, L.L.C. from a portion of the proceeds from the Private Placement and (ii) a portion of the proceeds from the Private Placement being used to consummate the transactions contemplated by the HIE Purchase Agreement.

The New Tranche B Loans bear interest (a) from June 24, 2013 through October 31, 2013 at a rate equal to 9.75% per annum payable, at the election of the company, either (i) in cash or (ii) in kind, and (b) from and after November 1, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in kind. Additionally, we agreed to pay the New Tranche B Lenders a nonrefundable exit fee equal to 2.5% of the aggregate amount of the New Tranche B Loans. The exit fee is earned in full and payable on the maturity date of the Tranche B Loans or, if earlier, the date on which the New Tranche B Loans are paid in full.

The New Tranche B Loans mature and are payable in full on August 31, 2016. We may prepay the New Tranche B Loans at any time, provided that any prepayment is in an integral multiple of $100,000 and not less than $100,000 or, if less, the outstanding principal amount of the New Tranche B Loans. Amounts to be applied to prepayment of New Tranche B Loans shall be applied (i) first, towards payment of interest then outstanding and fees then due, and (ii) second, towards payment of principal then outstanding.

The New Tranche B Loans are secured by a lien on substantially all of our assets and our subsidiaries, excluding Texadian, Texadian Energy Canada Limited (“Texadian Canada”), certain of our immaterial subsidiaries, and Hawaii Pacific Energy and its subsidiaries. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

ABL Facility

On September 25, 2013 and in connection with the with the acquisition of HIE, HIE and its subsidiary (the “ABL Borrowers”) and Hawaii Pacific Energy entered into an asset-based revolving credit facility (the “ABL Facility”) to provide the ABL Borrowers with a senior secured revolving credit facility of up to $125.0 million under which the ABL Borrowers may borrow amounts from time to time based on the available borrowing base as determined in accordance with the ABL Facility. The ABL Facility also allows the ABL Borrowers to use up to $50 million of availability under the ABL Facility for the issuances of letters of credit. The ABL Borrowers borrowed $15 million on September 25, 2013 under the ABL Facility in order to, in part, (i) fund the purchase price under the Purchase Agreement, and (ii) provide working capital to the ABL Borrowers. The proceeds from any future amounts borrowed pursuant to the ABL Facility will be used for general corporate purposes and to fund the working capital of the ABL Borrowers. As of December 31, 2013, the total capacity of the ABL Facility was $83.3 million.

Outstanding balances on the ABL Facility bear interest at the base rate specified below (“Base Rate”) plus a margin (based on a sliding scale of 1.00% to 1.50% depending on the borrowing base usage) or the adjusted LIBO rate specified below (“LIBO Rate”) plus a margin (based on a sliding scale of 2.00% to 2.50% depending on the borrowing base usage). The margin was 1.25% for Base Rate loans and 2.25% for LIBO Rate loans during 2013. The Base Rate is equal to the highest of (i) the prime lending rate of the ABL Agent, (ii) the Federal Funds Rate plus 0.5% per annum, and (iii) the LIBO Rate for a LIBO Rate loan denominated in dollars with a one-month interest period commencing on such day plus 1.00%. The effective weighted-average interest rate for 2013 was 3.13%.

The amounts borrowed pursuant the ABL Facility and all obligations arising under the ABL Facility are secured by a lien in favor of the ABL Agent on substantially all of HIE’s assets.

F-24

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

The ABL Borrowers agreed to pay commitment fees for the ABL Facility equal to 0.375% if the borrowing base usage is greater than 50% and 0.500% if the borrowing base usage is less than or equal to 50%. Outstanding letters of credit will be charged a participation fee at a per annum rate equal to the margin applicable to LIBO Rate loans, a facing fee and customary administrative fees.

All loans and other obligations outstanding under the ABL Facility are payable in full on September 25, 2017.

The ABL Facility requires HIE and its subsidiaries and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting its business and operations, including compliance by HIE in certain circumstances with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”), as adjusted, to total fixed charges of 1.0 to 1.0.

HIE Retail Credit Agreement

On November 14, 2013 , HIE Retail, LLC (“HIE Retail”), our subsidiary, entered into a Credit Agreement (the “Retail Credit Agreement”) in the form of a senior secured term loan of up to $30 million the (“Term Loan”) and a senior secured revolving line of credit of up to $5 million (the “Revolver”). HIE Retail initially borrowed $26 million of the Term Loan at the closing and an additional $4 million of the Term Loan upon HIE Retail’s compliance with certain liquor licensing requirements, if such requirements are satisfied prior to December 31, 2014, will be available. The proceeds of the Term Loan are available for general corporate purposes.

Loans made under the Retail Credit Agreement are secured by a first priority security interest in substantially all of the assets of HIE Retail consisting primarily of 31 distribution outlets, selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii.

The Retail Credit Agreement requires HIE Retail to comply with various financial covenants that are measured on a quarterly basis commencing with the fiscal quarter ending March 31, 2014 and are calculated on a trailing four-quarter basis. Such covenants require HIE Retail to maintain a maximum Leverage Ratio (as defined in the Retail Credit Agreement) as follows:

Period (during and as of the last day of)	Maximum Leverage Ratio
2013 Fiscal Year	5.75 to 1.00
2014 Fiscal Year	5.50 to 1.00
2015 Fiscal Year	5.25 to 1.00
2016 Fiscal Year	5.00 to 1.00
2017 Fiscal Year, and at all times thereafter	4.75 to 1.00

HIE Retail is also required to maintain a Fixed Charge Coverage Ratio of 1.15:1.00.

Term Loan

Principal on the Term Loan will be repaid in 28 quarterly principal payments over the term through November 14, 2020.

The Term Loan will bear interest, at HIE Retail’s election, at a rate equal to (i) 30, 90 and 180 day LIBOR plus the Applicable Margin (as specified below) for LIBOR Loans (as defined in the Retail Credit Agreement), or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Applicable Margin. The effective interest rate for 2013 on the outstanding loan was 2.5%.

Interest is payable at the end of the selected interest period, but no less frequently than quarterly. The Applicable Margin for each fiscal quarter is the applicable rate per annum set forth below, such amount to be determined as of the last day of the immediately preceding fiscal quarter.

F-25

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Level	Leverage Ratio	Applicable Margin for LIBOR Loans			Applicable Margin for Base Rate Loans
1	<4.00x		2	%		0	%
2	4.00x-5.00x		2.25	%		.25	%
3	>5.00x		2.5	%		.50	%

Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.

Fifty percent of annual Excess Cash Flow (as defined in the Retail Credit Agreement) will be applied to the outstanding principal balance of the Term Loan beginning with Excess Cash Flow for fiscal year 2014 to the extent the leverage ratio is equal to or greater than 4.50:1.00.

Revolver

The Revolver matures on November 14, 2016. Letters of credit issued under the Revolver are not to expire beyond the maturity date of the Revolver.

Advances under the Revolver will bear interest, at HIE Retail’s election, at a rate equal to (a) 30, 90 and 180 day LIBOR plus the Revolver Applicable Margin (as defined below) for LIBOR Loans, or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Revolver Applicable Margin.

HIE Retail agreed to pay a fee (the “Unused Fee”), based on the leverage ratio on the last date of the immediately preceding quarter as set forth below, based on the unused portion of the Revolver and calculated on the average of the unused amount for the quarter. The Unused Fee is payable quarterly in arrears commencing on the November 14, 2013.

The Revolver Applicable Margin and the Unused Fee, for each quarter is determined, on the last date of the immediately preceding fiscal quarter:

Level	Leverage Ratio	Unused Fee			Revolver Applicable Margin for LIBOR Loans			Revolver Applicable Margin for Base Rate Loans
1	<4.00x		.25	%		1.75	%		-.25	%
2	4.00x-5.00x		.375	%		2.00	%		0	%
3	>5.00x		.50	%		2.25	%		.25	%

Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.

Commitment fees for Standby Letters of Credit issued under the Revolver are due quarterly in arrears and will be equal to 2.00% per annum on the letter of credit amount payable. Fees for the issuance and negotiation of Commercial Letters of Credit will be based on the Agent’s standard fee schedule then in effect.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly-owned subsidiary Texadian Canada entered into an uncommitted credit agreement to provide for loans and letters of credit, on an uncommitted and absolutely discretionary basis, in an aggregate amount at any one time outstanding not to exceed $50 million. Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian’s assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian. Texadian agreed to pay certain fees with respect to the loans and letters of credit made available to it under the Uncommitted Credit Agreement, including an up-front fee, an origination fee, a minimum compensation fee, a collateral audit fee, and fees with respect to letters of credit. The Uncommitted Credit Agreement requires Texadian to comply with various affirmative

F-26

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

and negative covenants affecting its business, and Texadian must comply with certain financial maintenance covenants, including among other things, covenants regarding the minimum net working capital and minimum tangible net worth of Texadian. The Uncommitted Credit Facility does not permit, at any time, Texadian’s consolidated leverage ratio to be greater than 5.00 to 1.00 or its consolidated gross asset coverage to be equal to or less than zero. As of December 31, 2013, we had $41.6 million of letters of credit outstanding related to this agreement.

Letter of Credit Facility

On December 27, 2012, we entered into a letter of credit facility agreement (the “Letter of Credit Facility”). The Letter of Credit Facility provided for a letter of credit facility in an aggregate principal amount of $30 million that was available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries.

In connection with the acquisition of Texadian, we issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.7 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that certain letters of credit were drawn. Those letters of credit have been terminated and released. The Letter of Credit Facility was terminated on June 17, 2013.

Cross Default Provisions

Included within each of the 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 December 31, 2013, we are in compliance with all of our credit agreements.

Warrant Issuance Agreement

Pursuant to the Plan of Reorganization, on the Emergence Date, we issued to the Lenders warrants (the “Warrants”) to purchase up to an aggregate of 959,213 shares of our common stock (the “Warrant Shares”). In connection with the issuance of the Warrants, we also entered into a Warrant Issuance Agreement, dated as of the Emergence Date (the “Warrant Issuance Agreement”). Subject to the terms of the Warrant Issuance Agreement, the holders are entitled to purchase shares of common stock upon exercise of the Warrants at an exercise price of $0.10 per share of common stock (the “Exercise Price”), subject to certain adjustments from time to time as provided in the Warrant Issuance Agreement. The Warrants expire on the earlier of (i) August 31, 2022 or (ii) the occurrence of certain merger or consolidation transactions specified in the Warrant Issuance Agreement. A holder may exercise the Warrants by paying the applicable exercise price in cash or on a cashless basis.

The number of shares of our common stock issuable upon exercise of the Warrants and the exercise prices of the Warrants will be adjusted in connection with certain issuances or sales of shares of the company’s common stock and convertible securities, or any subdivision, reclassification or combinations of common stock. Additionally, in the case of any reclassification or capital reorganization of the capital stock of the company, the holder of each Warrant outstanding immediately prior to the occurrence of such reclassification or reorganization shall have the right to receive upon exercise of the applicable Warrant, the kind and amount of stock, other securities, cash or other property that such holder would have received if such Warrant had been exercised.

From the Emergence Date through December 31, 2013, we issued an additional 228,735 shares of our common stock to settle bankruptcy matters. This entitled the Lenders to receive an additional 14,859 Warrant Shares through December 31, 2013. On December 12, 2013, Warrants to purchase 183,389 Warrant Shares were exercised. At December 31, 2013, Warrants to purchase an aggregate of 790,683 Warrant Shares were outstanding.

Based on certain anti-dilution provisions in the Warrant Issuance Agreement, we have concluded that the Warrants are not indexed to our equity. Accordingly, on the Emergence Date we estimated the fair value of the Warrants on the date of grant to be approximately $6.6 million and recorded the estimated fair value of the Warrants as a derivative liability with the offset to debt discount. The debt discount was being amortized over the life of the Loan Agreement, using the effective interest method until repayment of the delayed draw term loan in November 2013. Subsequent changes in the fair value of the Warrants are reflected in earnings (see Note 11 - Fair Value Measurements).

F-27

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 11 - Fair Value Measurements

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are categorized with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority given to unobservable inputs. The three levels of the fair value hierarchy are as follows:

Level 1 -	Assets or liabilities for which the item is valued based on quoted prices (unadjusted) for identical assets or liabilities in active markets.
Level 2 -	Assets or liabilities valued based on observable market data for similar instruments.
Level 3 -	Assets or liabilities for which significant valuation assumptions are not readily observable in the market; instruments valued based on the best available data, some of which is internally-developed, and considers risk premiums that a market participant would require.

The level in the fair value hierarchy within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. Our policy is to recognize transfers in and/or out of fair value hierarchy as of the end of the reporting period for which the event or change in circumstances caused the transfer. We have consistently applied the valuation techniques discussed below for the periods presented. We use data from peers as well as external sources in the determination of the volatility and risk free rates used in our fair value calculations. A sensitivity analysis is performed as well to determine the impact of inputs on the ending fair value estimate.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Fresh-Start Reporting - The fair value of the Successor was based on its estimated enterprise value post-bankruptcy using valuation techniques described in notes (a) through (e) below. The individual components consist of the estimated enterprise value of Piceance Energy and the sum of the estimated fair value of the assets we retained. The estimates of fair value of the net assets were reflected in the Successor’s consolidated balance sheet as of August 31, 2012.

	Fair Value at August 31, 2012		Fair Value Technique
	(in thousands)
Oil and gas properties
Proved	$	4,587		(a)(b)
Other assets
Frac tanks		1,400		(c)
Compressors		2,800		(c)
Miscellaneous		39		(d)
Investment in Piceance Energy		105,344		(e)

(a) Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.

F-28

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

(b) The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.

(c) The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.

(d) Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.

(e) The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves’ future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

Purchase Price Allocation of Texadian - The fair values of the assets acquired and liabilities assumed as a result of the Texadian acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (f) described below.

	Fair Value at December 31, 2012			Fair Value Technique
	(in thousands)
Net non-cash working capital	$	3,631			(a)
Supplier relationship		3,360			(b)
Historical shipper status		2,200			(c)
Railcar leases		3,249			(d)
Goodwill		7,756			(e)
Deferred tax liabilities		(2,757	)		(f)
	$	17,439

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

F-29

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Purchase Price Allocation of HIE - The preliminary fair values of the assets acquired and liabilities assumed as a result of the HIE acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (g) described below.

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,059			(a)
Property, plant and equipment		58,782			(b)
Land		39,800			(c)
Trade names and trade marks		4,689			(d)
Goodwill		13,613			(e)
Contingent consideration liability		(11,980	)		(f)
Other noncurrent liabilities		(6,384	)		(g)
	$	560,579

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the property, plant and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and external obsolescence. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the trade names and trademarks was estimated using a form of the income approach, the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) The estimated fair value of the liability for contingent consideration was estimated using Monte Carlo Simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.

(g) Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.

Assets and Liabilities Measure at Fair Value on a Recurring Basis

Common stock warrants - We estimate the fair value of our outstanding Warrants using a Monte Carlo Simulation analysis, which is considered to be Level 3 fair value measurement. Significant inputs used in the Monte Carlo Simulation Analysis include:

	December 31,
	2013			2012
Stock price	$	22.30		$	12.00
Initial exercise price	$	0.1		$	0.1
Term (years)		8.67			9.67
Risk-free rate		2.78	%		1.68	%
Expected volatility		52.9	%		75.0	%

F-30

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

The expected volatility is based on the 10-year historical volatilities of comparable public companies. Based on the Monte Carlo Simulation Analysis, the estimated fair value of the Warrants was $21.64 and $11.30 per share, or approximately $17.3 million and $10.9 million, as of December 31, 2013 and 2012, respectively. Since the Warrants were in the money upon issuance, we do not believe that changes in the inputs to the Monte Carlo Simulation Analysis will have a significant impact to the value of the Warrants other than changes in the value of our common stock. Increases in the value of our common stock will directly be correlated to increases in the value of the Warrants. Likewise, a decrease in the value of our common stock will result in a decrease in the value of the Warrants.

Debt Prepayment Derivative - Our Loan Agreement contained mandatory repayments subject to premiums as set forth in the agreement. Factors such as the sale of assets, distributions from our investment in Piceance Energy, issuance of additional debt or issuance of additional equity may result in a mandatory prepayment. We considered the contingent prepayment feature to be an embedded derivative which was bifurcated from the loan and accounted for as a derivative. The fair value of the embedded derivative was estimated using an income valuation technique and a Crystal Ball forecast. The fair value measurement is considered to be a Level 3 fair value measurement. We do not believe that changes to the inputs in the model would have a significant impact on the valuation of the embedded derivative, other than a change to the estimate of the probability that a triggering event would occur. An increase in the probability of a triggering event occurring would cause an increase in the fair value of the embedded derivative. Likewise, a decrease in the probability of a triggering event occurring would cause a decrease in the value of the embedded derivative. At December 31, 2012, we estimated the fair value of the embedded derivative to be $145 thousand based on the probability of us repaying the loan prior to maturity. In November 2013, we repaid in full and terminated all of our obligations, including any repayment premiums, under this Loan Agreement (other than the new Tranche B loans described above) extinguishing the liability (see Note 10 - Debt).

Derivative instruments - With the acquisition of Texadian, we assumed certain open positions consisting of non-exchange traded fixed price physical contracts. These contracts were not treated as normal purchase or normal sales contracts and changes in fair value were recorded in earnings. In addition, we had certain exchange traded oil contracts that settled during the period and had no open positions as of December 31, 2013. The fair value of our commodity derivatives is measured using the closing market price at the end of the reporting period obtained from the New York Mercantile Exchange and from third party broker quotes and pricing providers. As of December 31, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts for which we have not elected the normal purchase or normal sale exception.

Contingent consideration liability - As described in Note 4, the purchase price for our acquisition of HIE may be increased pursuant to an earn out provision. The initial value of the contingent consideration was estimated to be approximately $12.0 million. The liability is re-measured at the end of each reporting period using the valuation technique as described above. We do not believe that there has been a material change in the liability from September 25, 2013 through December 31, 2013.

Financial Statement Impact

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their placement with our consolidated balance sheet consist of the following (in thousands):

	Location on Consolidated Balance Sheet	Fair Value at December 31, 2013			Fair Value at December 31, 2012
Commodities - physical forward contracts	Prepaid and other current assets	$	—		$	(307	)
Commodities - exchange traded futures	Prepaid and other current assets		—			542
Warrant derivatives	Derivative liabilities		(17,336	)		(10,900	)
Contingent consideration liability	Contingent consideration liability		(11,980	)		—
Debt repayment derivative	Derivative liabilities		—			(45	)

F-31

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

The following table summarizes the pre-tax effect resulting from changes in fair value of derivative instruments charged directly to earnings (in thousands):

		December 31, 2013			September 1 through December 31, 2012
	Income Statement Classification	Gain (loss) recognized in income			Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Change in value of warrants	$	(10,114	)	$	(4,280	)
Debt repayment derivative	Interest expense and financing costs, net		45			—
Commodities - exchange traded futures	Gain on derivative instruments, net		104			—
Commodities - physical forward contracts	Gain on derivative instruments, net		306			—

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their level within the fair value hierarchy is as follows (in thousands):

	December 31, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Warrants derivative	$	(17,336	)	$	—	$	—	$	(17,336	)
Contingent consideration liability		(11,980	)		—		—		(11,980	)
	$	(29,316	)	$	—	$	—	$	(29,316	)

	December 31, 2012
	Fair Value			Level 1		Level 2			Level 3
Assets
Commodities - exchange traded futures	$	542		$	542	$	—		$	—
Liabilities
Warrants derivative	$	(10,900	)	$	—	$	—		$	(10,900	)
Debt prepayment derivative		(45	)		—		—			(45	)
Commodities - physical forward contracts		(307	)		—		(307	)		—
	$	(11,252	)	$	—	$	(307	)	$	(10,945	)

F-32

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

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

Description	2013			2012
Balance, at beginning of period	$	(10,945	)	$	(6,665	)
Settlements		3,723			—
Acquired		(11,980	)		—
Total unrealized losses included in earnings		(10,114	)		(4,280	)
Transfers		—			—
Balance, at end of period	$	(29,316	)	$	(10,945	)

The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2013 and 2012 is as follows (in thousands):

	December 31, 2013
	Carrying Value		Fair Value(1)
Tranche B	$	19,480	$	18,800
ABL Facility		51,800		51,800
HIE Retail Credit Agreement		26,000		26,000
Warrants		17,336		17,336
Contingent consideration liability		11,980		11,980

	December 31, 2012
	Carrying Value		Fair Value(1)
Long-term debt	$	7,391	$	10,900
Warrants		10,900		10,900
Debt repayment derivative		45		45

⁽¹⁾ The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.

The fair value of all non-derivative financial instruments included in current assets, including cash and cash equivalents, restricted cash and trade accounts receivable, current liabilities and accounts payable approximate their carrying value due to their short term nature.

We estimate our long term debt’s fair value using a discounted cash flow analysis and an estimate of the current yield of 5.72% and 5.72% as of December 31, 2013 and 2012, respectively, by reference to market interest rates for term debt of comparable companies.

Note 12 - Defined Contribution Plans

We maintain several defined contribution plans for our employees. Eligible employees can enter the plans either immediately or after one year of service, depending on the plan. The plans permit employee contributions up to the IRS limits per year. For some plans, we contribute 3% of the employee’s eligible compensation to the plan regardless of the employee’s contribution. On all plans, we match a portion of all the employee’s contributions up to 6% depending on the plan. In addition, we have a money purchase pension plan for certain eligible employees. Under this plan, we make contributions to employee directed investment accounts ranging from 5.5% to 8.5% of eligible compensation depending on the employee’s age. For the year ended December 31, 2013, we made contributions to the plans totaling approximately $502 thousand. There were no such plans in place for the period from September 1, 2012 through December 31, 2012.

Note 13 - Commitments and Contingencies

Environmental Matters

Like other petroleum refiners and oil and gas 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.

F-33

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

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. 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.

Regulation of Greenhouse Gases. The United States Environmental Protection Agency (“US EPA”) has begun regulating greenhouse gases under the Clean Air Act Amendments of 1990 (the “Clean Air Act”). New construction or material expansions that meet certain greenhouse gas emissions thresholds will likely require that, among other things, a greenhouse gas permit be issued in accordance with the Clean Air Act 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 greenhouse gas emissions.

Furthermore, the US EPA is currently developing refinery-specific greenhouse gas regulations and performance standards that are expected to impose, on new and modified operations, greenhouse gas 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 cost of the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity.

In 2007, the State of Hawaii passed Act 234, which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed, the Hawaii Department of Health (“DOH”) 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 greenhouse gas emissions were reported to the US EPA under 40 CFR Part 98). Those rules are pending final approval by the Government of Hawaii. The refinery’s capacity to reduce fuel use and greenhouse gas emissions is limited. However, the state’s pending regulation allows, and the refinery should be able to demonstrate, that additional reductions are not cost-effective or necessary in light of the state’s current greenhouse gas inventory and future year projection. The pending regulation allows for “partnering” with other facilities (principally power plants) which 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 (“EISA”) which, 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 United States by model year 2020, and contained a second Renewable Fuel Standard (the “RFS2”). In August 2012, the US 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 36.0 billion gallons by 2022. In the near term, the RSF2 will be satisfied primarily with fuel ethanol blended into gasoline. The RSF2 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 US 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 Clean Air Act 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 US EPA issued a second waiver for the use of E15 in vehicles model year 2001-2006. There are numerous issues, including state and federal regulatory issues, which need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines. Since April 2006, the State of Hawaii has required that a minimum of 9.2% ethanol be blended into at least 85% of the gasoline pool, but the regulation also limited the amount of ethanol to no more than 10%. Consequently, unless either the state or federal regulations are revised, qualified Renewable Identification Numbers (“RINS”) will be required to fulfill the federal mandate for renewable fuels.

F-34

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

In March 2014, the US EPA published a final Tier 3 gasoline standard that lowers the allowable sulfur level in gasoline to 10 ppm and also lowers the allowable benzene, aromatics and olefins content of gasoline. The effective date for the new standard, January 1, 2017, gives refiners nation-wide little time to engineer, permit and implement substantial modifications. Along with credit and trading options, potential capital upgrades for the refinery are being evaluated. The American Petroleum Institute and American Fuel and Petrochemical Association may challenge the final regulation.

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. We may 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 (the “Closing Date”), Hawaii Pacific Energy (a wholly-owned subsidiary of Par created for purposes of the Tesoro Acquisition), Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities related to the acquisition of HIE, including the Consent Decree as described below.

Consent Decree. Tesoro is currently negotiating a consent decree with the US EPA and the United States Department of Justice concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (the “Consent Decree”), including the Hawaii refinery. It is anticipated that the Consent Decree will be finalized sometime during 2014 and will require certain capital improvements to our refinery to reduce emissions of air pollutants.

It is not possible at this time to estimate the cost of compliance with the ultimate decree. However, Tesoro is responsible under the Environmental Agreement for reimbursing HIE for all reasonable third party capital expenditures incurred for the construction, installation and commissioning of such capital projects and for the payment of any fines or penalties imposed on HIE arising from the Consent Decree to the extent related to acts or omission of Tesoro or HIE prior to the Closing Date. Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, the obligation relating to fines and penalties terminates on the third anniversary of the Closing Date.

Tank Replacements. Tesoro has agreed, at its expense, to replace the existing underground storage tanks at certain retail assets.

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 Environment 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 Closing Date, any fine, penalty or other cost assessed by a governmental authority in connection with violations of environmental laws by HIE prior to the Closing Date, certain groundwater remediation work, the replacement of underground storage tanks located at certain retail assets, fines or penalties imposed on HIE by the Consent Decree related to acts or omissions of Tesoro prior to the Closing Date and 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 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.

Helicopter Litigation.

HIE is the defendant in a lawsuit styled State of Hawaii Department of Transportation Airports Division et al. v. Tesoro Hawaii, Civil No. 09-2253-09 JHC. In this matter, the insurance company for the State of Hawaii is seeking reimbursement of the attorney’s

F-35

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

fees and costs incurred by outside council to defend against Tesoro Hawaii’s third-party complaints for contribution in three previously-settled underlying litigation matters. The underlying litigation was filed by three helicopter tour operators flying on the Island of Kauau. The helicopter tour operators allege bad jet fuel caused the formation of coking deposits in their engines which resulted in millions of dollars of repair costs and lost income. There were no in-flight issues.

Tesoro Hawaii filed third-party complaints against the State of Hawaii in each of the three underlying lawsuits alleging that any fuel issues arose from improper design and maintenance of the underground pipeline and dispensers owned and maintained by the State of Hawaii. The helicopter operators settled with the State of Hawaii, and Tesoro Hawaii and its aviation liability insurers subsequently settled with the helicopter operators.

The lawsuit alleges that the State of Hawaii was entitled to a defense and indemnity under the terms of its lease for the Tesoro Hawaii facility at the Lihue airport. The suit alleges defense costs of approximately $2 million in the underlying lawsuits. The State of Hawaii and its insurance company have since demanded $3.25 million. The issue at trial is ultimately whether Tesoro Hawaii owed a contractual duty to pay for the State of Hawaii’s defense against Tesoro Hawaii’s third-party complaints against the State of Hawaii for the State’s own negligence. The case is set for a bench trial in September 2014.

There is a companion lawsuit by the State of Hawaii and its insurance company against Tesoro Hawaii’s former liability insurer on the same issues. The Court previously held by way of a Motion for Summary Judgment that Tesoro Hawaii’s insurer had a duty to defend the State of Hawaii against Tesoro Hawaii’s third-party complaints. That matter is going to trial in July 2014 on the issue of damages only (e.g. the reasonable amount of attorney’s fees and costs the State of Hawaii is entitled to for the defense of the third-Party Complaints in the underlying lawsuits).

We do not believe that any loss relating to this litigation is probable. However, should any loss become probable before the end of the measurement period, such loss would be reflected as a purchase price adjustment relating to the HIE Acquisition.

Recovery Trusts

On the date we emerged from bankruptcy, or the Emergence Date, two trusts were formed; the Wapiti Recovery Trust (the “Wapiti Trust”) and the Delta Petroleum General Recovery Trust (the “General Trust,” and together with the Wapiti Trust, the “Recovery Trusts”). The Recovery Trusts were formed to pursue certain litigation against third-parties or causes of action under the U.S. Bankruptcy Code, and other claims and potential claims that the Debtors hold against third parties. The Recovery Trusts were funded with $1.0 million each pursuant to the Plan.

In September 2012, the Wapiti Trust settled all causes of action against Wapiti Oil & Gas, LLC (“Wapiti Oil & Gas”). Wapiti Oil & Gas made a one-time cash payment in the amount of $1.5 million to the Wapiti Trust, as consideration for the release of claims against it. These proceeds were then distributed to us, along with funds remaining from the initial funding of the Wapiti Trust of approximately $1.0 million. The Wapiti Trust was liquidated during 2013.

The General Trust is pursuing all bankruptcy causes of action not otherwise vested in the Wapiti Trust, claim objections and resolutions, and all other responsibilities for winding-up the bankruptcy. The General Trust is overseen by a three person General Trust Oversight Board and our Chief Legal Officer is currently the trustee (the “Recovery Trustee”). Costs, expenses and obligations incurred by the General Trust are charged against assets in the General Trust. To conduct its operations and fulfill its responsibilities under the Plan and the trust agreements, the Recovery Trustee may request additional funding from us. Any litigation pending at the time we emerged from Chapter 11 was transferred to the General Trust for resolution and settlement in accordance with the Plan and the order confirming the Plan. We are the beneficiary of the General Trust, subject to the terms of the trust agreement and the Plan. Since the Emergence Date, the General Trust has filed various claims and causes of action against third parties before the Bankruptcy Court, which actions are ongoing. Upon liquidation of the various claims and causes of action held by the General Trust, the proceeds, less certain administrative reserves and expenses, will be transferred to us. It is unknown at this time what proceeds, if any, we will realize from the General Trust’s litigation efforts.

F-36

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

From the Emergence Date through December 31, 2013, the Recovery Trusts have released approximately $5.2 million to us, which is available for our general use, due to a negotiated reduction in certain fees and claims associated with the bankruptcy, as well as a favorable variance in actual expenses versus budgeted expenses. The entire $5.2 million was released prior to December 31, 2012.

Shares Reserved for Unsecured Claims

The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. On the Emergence Date, 112 claims totaling approximately $73.7 million had been filed in the bankruptcy. Pursuant to the Plan, between the Emergence Date and December 31, 2012, the Recovery Trustee settled 25 claims with an aggregate face amount of $6.6 million for approximately $259 thousand in cash and 20,275 shares of common stock. Pursuant to the Plan, during the year ended December 31, 2013, the Recovery Trustee settled an additional 59 claims with an aggregate face amount of $26.9 million for approximately $5.4 million in cash and 208,460 shares of common stock.

As of December 31, 2013, it is estimated that a total of 28 claims totaling approximately $40.2 million remain to be resolved by the Recovery Trustee. The largest remaining proof of claim was filed by the US 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. 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 the Predecessor company owned a 2.41934% 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. At December 31, 2013 and 2012, we have reserved approximately $3.8 million and $8.7 million, respectively, representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end. A summary of claims is as follows (in thousands, except number of filed claims):

	Emergence-Date August 31, 2012				From Emergence-Date through December 31, 2012
	Filed Claims				Settled Claims								Remaining Filed Claims
									Consideration
	Count		Amount		Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		3	$	22,364		—	$	—	$	—		—		3	$	22,364
Former Employee Claims		32		16,380		13		3,685		230		20		19		12,695
Macquarie Capital (USA) Inc.		1		8,672		—		—		—		—		1		8,672
Swann and BuzzardCreek RoyaltyTrust		1		3,200		—		—		—		—		1		3,200
Other Various Claims*		75		23,114		12		2,915		29		—		63		20,199
Total		112	$	73,730		25	$	6,600	$	259		20		87	$	67,130

	For the Year Ended December 31, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364
Former Employee Claims		19		12,695		340		162		—		—
Macquarie Capital (USA) Inc.		1		8,672		2,500		—		—		—
Swann and Buzzard Creek Royalty Trust		1		3,200		2,000		—		—		—
Other Various Claims(1)		37		2,339		543		47		26		17,860
Total		59	$	26,906	$	5,383		209		28	$	40,224

(1) Includes reserve for contingent/unliquidated claims in the amount of $10 million.

F-37

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Capital Leases

Within our refining, distribution and marketing segment, we have capital lease obligations related primarily to the leases of five retail stations with initial terms of 17 years, with four 5-year renewal options. Minimum annual lease payments including interest, for capital leases are as follows (in thousands):

2014	$	382
2015		382
2016		382
2017		382
2018		420
Thereafter		420
Total minimum lease payments		2,368
Less amount representing interest		634
Total minimum rental payments	$	1,734

Operating Leases

Within our refining, distribution and marketing segment, we have various cancellable and noncancellable operating leases related to land, vehicles, office and retail facilities and other facilities used in the storage, transportation and sale of crude oil and refined products. The majority of the future lease payments relate to retail stations and facilities used in the storage, transportation and sale of crude oil and refined products. We have operating leases for most of our retail stations with primary terms of up to 32 years, and generally containing renewal options and escalation clauses. Leases for facilities used in the storage, transportation and sale of crude oil and refined products have various expiration dates extending to 2027.

In addition, with our commodity marketing and logistics segment, we have various agreements to lease storage facilities, primarily along the Mississippi River, railcars, inland river tank barges and towboats and other equipment. These leasing agreements have been classified as operating leases for financial reporting purposes and the related rental fees are charged to expense over the lease term as they become payable. The leases generally range in duration of five years or less and contain lease renewal options at fair value. Our railcar leases contain an empty mileage indemnification provision whereby if the empty mileage exceeds the loaded mileage, we are charged for the empty mileage at the rate established by the tariff of the railroad on which the empty miles accrued.

F-38

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Minimum annual lease payments extending to 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):

2014	$	22,724
2015		13,277
2016		12,362
2017		10,375
2018		9,244
Thereafter		25,614
Total minimum rental payments	$	93,596

Rent expense for the year ended December 31, 2013 and for the period from September 1, 2012 through December 31, 2012 was approximately $6.2 million and $61 thousand, respectively.

Major Customers

For the year ended December 31, 2013, no individual customer accounted for more than 10% of our consolidated revenue. For the period September 1, 2012 to December 31, 2012, we had one customer that accounted for 96% of our total oil and natural gas sales. During the period from January 1, 2012 to August 31, 2012, our Predecessor had two customers that accounted individually for 59% and 24%, respectively, of its total oil and natural gas sales.

Other

On April 22, 2013, Texadian entered into a terminaling and storage agreement whereby the operator will provide Texadian with storage facilities, access to a marine terminal and pipelines, and railcar offloading services. The initial term of the agreement is for a period of four years and Texadian’s minimum commitment during the initial term is approximately $28 million.

Note 14 - Stockholders’ Equity

Pursuant to the Plan, on the Emergence Date, (i) all shares of our common stock outstanding prior to the Effective Date were cancelled, (ii) each holder of our 7% senior unsecured notes due 2015 and our 3 ³⁄₄% senior convertible notes due 2037 received, in exchange for its total claim (including principal and interest), its pro rata portion of 14,573,608 shares of our common stock, (iii) each holder of an allowed general unsecured claim received, in exchange for its total claim, its pro rata portion of 191,973 shares of our common stock, and (iii) the Lenders under the Loan Agreement received warrants to purchase up to an aggregate of 959,213 shares of our common stock (which number of shares may be increased to an aggregate of 1,220,000 shares of our common stock pursuant to the terms of the Warrant Issuance Agreement).

Amendments to the Certificate of Incorporation and Bylaws

Pursuant to the Plan, on the Emergence Date, our certificate of incorporation and bylaws were amended and restated in their entirety.

Under the restated certificate of incorporation, the total number of all shares of capital stock that we are authorized to issue is 303 million shares, consisting of 300 million shares of common stock and 3 million shares of preferred stock, par value $0.01 per share. The restated certificate of incorporation contains restrictions on the transfer of certain of our securities in order to preserve the net operating loss carryovers, capital loss carryovers, general business credit carryovers, alternative minimum tax credit carryovers and foreign tax credit carryovers, as well as any “net unrealized built-in loss” within the meaning of Section 382 of the Code, of us or any direct or indirect subsidiary thereof.

On November 25, 2013, our amended and restated certificate of incorporation was further amended to (i) increase the authorized shares of Common Stock from 300,000,000 to 500,000,000 and (ii) revise certain provisions regarding approval by the company’s Board of Directors of transfers of Common Stock by holders of five percent or more of the outstanding Common Stock.

F-39

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Preferred Stock

As of December 31, 2013 and 2012, no shares of preferred stock were outstanding.

Common Stock

On December 31, 2012, a total of 3,052 shares of our common stock were issued to members of our Board of Directors in lieu of a cash fee for their service on the Board. We recognized compensation costs of approximately $33 thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $10.00 to $12.00 per share of common stock. Due to our limited daily trading activity, we believe that this represents a more accurate reflection of the fair value of our common stock.

On September 13, 2013, we entered into a Common Stock Purchase Agreement pursuant to which we agreed to sell shares of our common stock at a price of $13.90 per share, as adjusted to reflect the one for ten reverse stock split effective for trading purposes on January 29, 2014 (the “Reverse Stock Split”), in a private placement transaction (the “Private Placement”) in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933. Certain purchasers, namely, ZCOF Par Petroleum Holdings, L.L.C., an affiliate of Zell Credit Opportunities Master Fund, L.P. (“ZCOF”), and affiliates of Whitebox Advisors, LLC (“Whitebox”), each owned 10% or more of the our common stock directly or through affiliates prior to the execution of the Common Stock Purchase Agreement and are deemed to be our affiliates as a result of such ownership. ZCOF and Whitebox have representatives on our board of directors.

On September 25, 2013, we completed the Private Placement and issued approximately 14.4 million shares of common stock resulting in aggregate gross proceeds to us of approximately $200 million. We did not engage any investment advisors with respect to the Private Placement, and no finders’ fees or commissions were paid to any party in connection therewith. The proceeds from the Private Placement were used to fund a portion of the purchase price of the HIE acquisition.

During the year ended December 31, 2013, we issued approximately 208,512 shares of our common stock for settlement of bankruptcy claims, approximately 183,390 shares due to the exercise of Warrants and approximately 5,585 shares of unrestricted common stock to certain key employees and directors. We recognized compensation costs of approximately $90 thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $12.22 to $19.87 per share of common stock.

Registration Rights Agreements

Pursuant to the Plan, on the Effective Date, we entered into a registration rights agreement (the “Registration Rights Agreement”) providing the stockholders party thereto (the “Stockholders”) with certain registration rights.

The Registration Rights Agreement states that, among other things, at any time after the earlier of the consummation of a qualified public offering or 60 days after the Effective Date, any Stockholder or group of Stockholders that, together with its or their affiliates, holds more than fifteen percent of the Registrable Shares (as defined in the Registration Rights Agreement), will have the right to require us to file with the SEC a registration statement on Form S-1 or S-3, or any other appropriate form under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, for a public offering of all or part of its Registrable Shares (each a “Demand Registration”), by delivery of written notice to the company (each, a “Demand Request”).

Within 90 days after receiving the Demand Request, we must file with the SEC the registration statement, on any form for which we then qualify and which is available for the sale of the Registrable Shares in accordance with the intended methods of distribution thereof, with respect to the Demand Registration. We are required to use commercially reasonable efforts to cause the registration statement to be declared effective as soon as practicable after such filing. We will not be obligated (i) to effect a Demand Registration within 90 days after the effective date of a previous Demand Registration, other than for a shelf registration, or (ii) to effect a Demand Registration unless the Demand Request is for a number of Registrable Shares with an expected market value that is equal to at least

F-40

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

(x) $15 million as of the date of such Demand Request or is for one hundred percent of the demanding Stockholder’s Registrable Shares with respect to any Demand Registration made on Form S-1 or (y) $5 million as of the date of such Demand Request with respect to any Demand Registration made on Form S-3.

Upon receipt of any Demand Request, we are required to give written notice, within ten (10) days of such Demand Registration, to all other holders of Registrable Shares, who will have the right to elect to include in such Demand Registration such portion of their Registrable Shares as they may request, subject to certain exceptions.

In addition, subject to certain exceptions, if we propose to register any class of common stock for sale to the public, we are required, subject to certain conditions, to include all Registrable Shares with respect to which we have received written requests for inclusion.

The rights of a holder of Registrable Shares may be transferred, assigned or otherwise conveyed on to any transferee or assignee of such Registrable Shares, subject to applicable state and federal securities laws and regulations, our Certificate of Incorporation and the Stockholders Agreement. We will be responsible for expenses relating to the registrations contemplated by the Registration Rights Agreement.

The registration rights granted in the Registration Rights Agreement are subject to customary indemnification and contribution provisions, as well as customary restrictions such as suspension periods and, if a registration is for an underwritten offering, limitations on the number of shares to be included in the underwritten offering imposed by the managing underwriter.

In connection with the closing of the sale of the Private Placement, we entered into an additional registration rights agreement with the purchasers of the shares. Under this registration rights agreement, we agreed to file a registration statement relating to the shares of common stock with the U.S. Securities and Exchange Commission within 60 days after the closing date of the sale which would be declared effective within 180 days of the closing date of the sale. We also agreed to use commercially reasonable efforts to keep the registration statement effective until the earliest to occur of (i) the disposition of all registrable securities, (ii) the availability under Rule 144 of the Securities Act of 1933, as amended, for each holder of registrable securities to immediately freely resell such registrable securities without volume restrictions or (iii) the third anniversary of the effective date of the registration statement.

This registration rights agreement also provides the right for a holder or group of holders of more than $50 million of registrable securities to demand that we conduct an underwritten public offering of the registrable securities. However, the demanding holders are limited to a total of three such underwritten offerings, with no more than one demand request for an underwritten offering made in any 365 day period. Additionally, this registration rights agreement contains customary indemnification rights and obligations for both us and the holders of registrable securities.

If this registration statement (i) is not filed with the SEC on or prior to the applicable deadline (ii) is not declared effective by the SEC prior to the applicable deadline, or (iii) does not remain effective for the applicable effectiveness period described above then from the that date until cured, we must pay, as liquidated damages and not as a penalty, an amount in cash equal to 0.25% of the purchaser’s allocated purchase price per calendar month, not to exceed 0.75% of the allocated purchase price. We will accrue an obligation for this registration rights agreement when it is probable that an obligation has been incurred and the amount can be reasonably determined.

Incentive Plan

On December 20, 2012, our Board of Directors (the “Board”) approved the Par Petroleum Corporation 2012 Long Term Incentive Plan (the “Incentive Plan”). Under the Incentive Plan, the Board, or a committee of the Board, may issue up to 1.6 million shares of our common stock, or incentive stock options, nonstatutory stock options or restricted stock to our employee or directors, or other individuals providing services to us. In general, the terms of any award issue will be determined by the committee upon grant. In addition, in December 2012, we approved a new compensation plan for our directors. Our directors receive an annual retainer of $50 thousand, paid quarterly in cash or shares of our common stock at the election of the director. In addition, the Chairman of the Audit Committee receives an additional annual retainer of $15 thousand and the members of the Audit Committee (other than the

F-41

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Chairman) receive an annual retainer of $5 thousand, such retainers paid quarterly in cash or shares of our common stock at the election of the director. There are no fees for the members of any other committee or for attendance at meetings. Our directors are also entitled to receive an annual grant of restricted stock on the last day of each calendar year with a target value of $75 thousand, with the number of shares determined by the 60-day volume weighted average share price as of the day prior to the grant date.

On December 31, 2012, a total of 219,183 shares of restricted common stock were granted to members of the Board of Directors and certain employees. During the year ended December 31, 2013, an additional 355,481 shares of restricted stock were granted to certain employees. Restricted stock granted to members of the Board vests in full after one year from the date of grant, while most restricted stock granted to employees vests on a pro-rata basis over five years. For the year ended December 31, 2013, the following activity occurred under our Incentive Plan (in thousands, except per share amounts):

	Shares			Weighted- Average Grant Date Fair Value
Non vested balance, beginning of period		219		$	12.00
Granted		356			18.32
Vested		(51	)		12.00
Forfeited		—			—
Non vested balance, end of period		524		$	16.29
Available for grant		1,025

F-42

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

For the year ended December 31, 2013, we recognized compensation costs of approximately $1.2 million related to restricted stock awards. As of December 31, 2013, there is approximately $8.1 million of total unrecognized compensation costs related to restricted stock awards, which are expected to be recognized on a straight-line basis over a weighted average period of 4.37 years. The grant date fair value was estimated using the previous 20 days average trading price of our common stock.

Predecessor Stock Compensation Plans

On December 22, 2009, the Predecessor’s stockholders approved its 2009 Performance and Equity Plan (the “2009 Plan”). On June 21, 2011, the Predecessor granted 489,227 shares of non-vested common stock to certain employees. The shares vested in full on the earlier of a change in control or July 1, 2012. In conjunction with this grant, the Predecessor agreed to establish a “floor” price for the value of the shares on the date of vesting equal to the value of the shares on the grant date ($5.50 per share). In the event that the market price of the shares on the date of vesting was lower than the floor price on the date of vesting, the difference would be paid to the employees in cash. The compensation expense for the shares consists of a fixed equity component ($5.50 per share) and a variable liability component (based on the difference between the market price of the shares, if lower, and the floor price of the shares), both of which are included as a component of general and administrative expense in the accompanying Predecessor consolidated statement of operations. The Predecessor recognized stock compensation expense of approximately $1.9 million for the period from January 1, 2012 through August 31, 2012, which is included in general and administrative expenses. Under the terms of the Plan, the Predecessor’s stock compensation plans, and all awards issued under such plans, were canceled.

A summary of the stock option activity under the Predecessor’s various plans and related information for the period from January 1 through August 31, 2012 follows:

	Period from January 1 through August 31, 2012
	Options			Weighted-Average Exercise Price			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic Value
Outstanding-beginning of year		150,300		$	75.00
Granted		—			—
Exercised		—			—
Expired / canceled		(150,300	)		(75.00	)
Outstanding-end of year		—		$	—			—	$	—
Exercisable-end of year		—		$	—			—	$	—

A summary of the restricted stock (nonvested stock) activity under the Predecessor’s plan and related information for the period from January 1 through August 31, 2012 follows (in thousands, except share and per share amounts):

	Period from January 1 through August 31, 2012
	Nonvested Stock			Weighted-Average Grant-Date Fair Value			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic Value
Nonvested-beginning of year		558,301		$	7.45
Granted		—			—
Vested		—			—
Expired / canceled		(558,301	)		(7.45	)
Nonvested-end of year		—		$	—			—	$	—

F-43

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 15 - Income Taxes

Under the Plan of Reorganization, our prepetition debt securities, primarily prepetition notes, were extinguished. Absent an exception, a debtor recognizes cancellation of debt income (“CODI”) upon discharge of its outstanding indebtedness for an amount of consideration that is less than its adjusted issue price. Tax regulations provide that a debtor in a bankruptcy case may exclude CODI from income but must reduce certain of its tax attributes by the amount of any CODI realized as a result of the consummation of a plan of reorganization. The amount of CODI realized by a taxpayer is the adjusted issue price of any indebtedness discharged less the sum of (i) the amount of cash paid, (ii) the issue price of any new indebtedness issued and (iii) the fair market value of any other consideration, including equity, issued. As a result of the market value of our equity upon emergence from Chapter 11 bankruptcy proceedings, we were able to retain a significant portion of our NOLs and other “Tax Attributes” after reduction of the Tax Attributes for CODI realized on emergence from Chapter 11 and certain prior interest payments on debt converted to equity. Our NOLs have been reduced by approximately $225 million of CODI as a result of emergence from Chapter 11.

Pursuant to the Plan, on the Emergence Date, the existing equity interests of the Predecessor were extinguished. New equity interests were issued to creditors in connection with the terms of the Plan, resulting in an ownership change as defined under Section 382 of the Code. Section 382 generally places a limit on the amount of net operating losses and other tax attributes arising before the change that may be used to offset taxable income after the ownership change. We believe, however, that we will qualify for an exception to the general limitation rules. This exception under Code Section 382(l)(5) provides for substantially less restrictive limitations on our net operating losses; however the net operating losses are eliminated should another ownership change occur within two years. Our amended and restated certificate of incorporation places restrictions upon the ability of the equity interest holders to transfer their ownership in us. These restrictions are designed to provide us with the maximum assurance that another ownership change does not occur that could adversely impact our net operating loss carry forwards.

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 the current and prior periods, and projections for future results of operations over the periods in which the deferred tax assets are deductible, among other factors, management concluded that we did not meet the “more likely than not” requirement of ASC 740 in order to recognize deferred tax assets and a valuation allowance has been recorded for the full amount of our net deferred tax assets at December 31, 2013 and 2012.

During the years ended December 31, 2013 and 2012, no adjustments were recognized for uncertain tax benefits.

Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our NOL carry forwards will not always be available to offset taxable income apportioned to the various states. The states from which Texadian’s revenues and HIE’s 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 Texadian’s and HIE’s operations.

F-44

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

During 2014 and thereafter, 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 improve, the amount of the deferred tax asset considered more likely than not to be realizable could be increased.

Income tax expense (benefit) consisted of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Current:
U.S. - Federal	$	—		$	—		$	—
U.S. - State		(179	)		—			—
Deferred:
U.S. - Federal		(14	)		(2,757	)		—
U.S. - State		193			—			—
Total	$	—		$	(2,757	)	$	—

Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate of 35% to pretax income as a result of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Federal statutory rate		(35.0	)%		(35.0	)%		(35.0	)%
State income taxes, net of federal benefit		0.1	%		—			—
Change in valuation allowance		23.1	%		(2.0	)%		(33.0	)
Professional fees related to bankruptcy reorganization		—			8.0	%		17.0	%
Revenue from Wapiti Trust settlement		—			5.0	%		—
Cancellation of debt tax attribute reduction		—			—			51.0	%
Permanent Items		3.7	%
Provision to return adjustments		8.1	%		—			—
Actual income tax rate		—	%		(24.0	)%		—	%

Deferred tax assets (liabilities) are comprised of the following at December 31, 2013 and 2012 (in thousands):

	2013			2012
Deferred tax assets:
Net operating loss	$	544,377		$	450,195
Capital loss carry forwards		26,141			26,141
Property and equipment		34,683			23,045
Investment in Piceance Energy		32,138			45,172
Derivative instruments		—			1,498
Accrued bonuses		—			—
Trust liability		1,327			—
Other		1,183			1,506
Total deferred tax assets		639,849			547,557
Valuation allowance		(637,464	)		(544,442	)
Net deferred tax assets	$	2,385		$	3,115
Deferred tax liabilities:
Property and equipment	$	5		$	—
Texadian Energy intangibles		2,380			3,083
Prepaid insurance, marketable securities and other		—			32
State liabilities		216			—
Total deferred tax liabilities	$	2,601		$	3,115
Total deferred tax liability, net	$	(216	)	$	—

F-45

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

We have net operating loss carryovers as of December 31, 2013 of $1.3 billion for federal income tax purposes. If not utilized, the tax net operating loss carryforwards will expire during 2027 through 2032. Our capital loss carryovers as of December 31, 2013 are $74.7 million. If not utilized, these carryovers will expire during 2015 and 2016. We also have Alternative Minimum Tax Credit Carryovers of $0.8 million. These credits do not expire; however, we must first generate regular taxable income before they can be used. We will not likely generate regular taxable income utilized our net operating loss carry over.

Note 16 - Loss Per Share

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

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1 through August 31, 2012
Net loss attributable to common stockholders	$	(79,173	)	$	(8,839	)	$	(45,437	)
Basic weighted-average common shares outstanding		19,740			15,734			28,841
Add: dilutive effects of stock options and unvested stock grants(1)		—			—			—
Diluted weighted-average common stock outstanding		19,740			15,734			28,841
Basic loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)
Diluted loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)

(1) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

F-46

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding include the following (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		523		—		558
Total potentially dilutive securities		523		—		1,087

Note 17 - Segment Information

Following our acquisitions of HIE and Texadian, we have three business segments: (i) Refining, Distribution and Marketing, (ii) Natural Gas and Oil Operations and (iii) Commodity Marketing and Logistics. Corporate and Other includes trust litigation and settlements and other administrative costs. Summarized financial information concerning reportable segments consists of the following (in thousands):

For the year ended December 31, 2013	Refining, Distribution and Marketing			Natural Gas and Oil Operations		Commodity Marketing and Logistics			Corporate and Other			Total
Sales and operating revenues	$	778,126		$	7,739	$	100,149		$	—		$	886,014
Depreciation, depletion, amortization and accretion		2,267			1,686		2,009			20			5,982
Operating income (loss)		(27,870	)		246		9,126			(29,367	)		(47,865	)
Loss from unconsolidated affiliate													(2,941	)
Interest expense and financing costs, net													(19,471	)
Other income (expense)													808
Change in value of common stock warrants													(10,114	)
Gain on derivative instruments													410
Loss before income taxes													(79,173	)
Income tax benefit													—
Net loss												$	(79,173	)
Capital expenditures, including acquisitions	$	567,332		$	471	$	(1,300	)	$	544		$	567,047

Following our acquisition of Texadian, at December 31, 2012, we had two business segments: (i) Natural Gas and Oil Operations and (ii) Commodity Marketing and Logistics. For the period from September 1 through December 31, 2012, all of the operations as reported on our consolidated statement of operations related to Natural Gas and Oil Operations. For the period from September 1 through December 31, 2012, expenditures for long term assets, including goodwill and other intangible assets by segment were as follows (in thousands):

	Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
Capital expenditures, including acquisitions	$	415	$	17,439	$	—	$	17,854

Total assets by segment were as follows (in thousands):

	Refining, Distribution and Marketing		Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
At December 31, 2013	$	641,840	$	109,316	$	52,048	$	10,009	$	813,213
At December 31, 2012	$	—	$	116,034	$	62,754	$	10,794	$	189,582

F-47

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 18 - Related Party Transactions

Certain of our stockholders who are lenders under the Loan Agreement received Warrants exercisable for shares of common stock in connection with such loan (see Note 10 - Debt).

Certain of our stockholders and their affiliates who are owners of 10% or more of our common shares participated in the Stock Sale (see Note 14 - Stockholders’ Equity).

On September 17, 2013, we entered into letter agreements (the “Services Agreements”) with Equity Group Investments, an affiliate of ZCOF (“EGI”), and Whitebox. Pursuant to the Services Agreements, EGI and Whitebox 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 and Whitebox will not receive a fee for the provision of the strategic, advisory or consulting services set forth in the Services Agreements, 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 or Whitebox, as applicable, 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 or Whitebox’s, as applicable, services under the Services Agreements. In consideration of the services provided by EGI and Whitebox under the Services Agreements, we agreed to indemnity each of them for certain losses incurred by them relating to or arising out of the Services Agreements or the services provided thereunder.

The Services Agreements have 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 2013.

Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan

In December 2011 and January 2012, Delta and its subsidiaries filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”). Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In March 2012, the Bankruptcy Court approved the procedures relating to plans of reorganization as well as asset sales. Following completion of the asset sales, the Debtors obtained approval from the Bankruptcy Court to proceed with Laramie Energy II, LLC (“Laramie”) as the sponsor of a plan of reorganization (the “Plan”). In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with a new joint venture formed by Delta and Laramie, Piceance Energy LLC (“Piceance Energy”), and Laramie to effect the transactions contemplated by Plan.

The Plan was declared effective on August 31, 2012 (the “Emergence Date”). On the Emergence Date, Delta consummated the transaction contemplated by the Contribution Agreement and each of Delta and Laramie contributed to Piceance Energy their respective assets in the Piceance Basin. Piceance Energy is owned 66.66% by Laramie and 33.34% by Delta. At the closing, Piceance Energy entered into a new credit agreement, borrowed $100 million under that agreement, and distributed approximately $72.6 million net of settlements to the company and

F-48

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

approximately $24.9 million to Laramie. The company used its distribution to pay bankruptcy expenses and to repay its secured debt. The company also entered into a new credit facility and borrowed $13 million under that facility at closing, and used those funds primarily to pay bankruptcy claims and expenses.

Following the reorganization, Par retained its interest in the Point Arguello Unit offshore California and other miscellaneous assets and certain tax attributes, including significant net operating loss carryforwards. Based upon the Plan as confirmed by the Bankruptcy Court, Delta’s creditors were issued approximately 14.8 million shares of common stock, and Delta’s former stockholders received no consideration under the Plan.

Contemporaneously with the consummation of the Contribution Agreement, the company, through a wholly-owned subsidiary, entered into a Limited Liability company Agreement with Laramie that will govern the operations of Piceance Energy.

On the Emergence Date, Par adopted fresh-start reporting resulting in us becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to August 31, 2012 reflect the operations of Delta prior to reorganization (hereinafter also referred to as the “Predecessor”) and are not comparable to the consolidated financial statements presented on or after August 31, 2012. Fresh-start reporting was required upon emergence from Chapter 11 because (i) holders of voting shares immediately before confirmation of the Plan received less than 50% of the emerging entity and (ii) the reorganization value of our assets immediately before confirmation of the Plan was less than our post-petition liabilities and allowed claims. Fresh-start reporting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities. The effects of the implementation of the Plan and fresh-start adjustments are reflected in the results of operations of the Predecessor in the eight month period ended August 31, 2012. Our estimates of fair value are inherently subject to significant uncertainties and contingencies beyond our reasonable control. Accordingly, there can be no assurance that the estimates, assumptions, valuations, appraisals and financial projections will be realized, and actual results could vary materially. Moreover, the market value of our common stock may differ materially from the equity valuation for accounting purposes.

In the application of fresh-start reporting, a successor entity must determine a value to be assigned to the equity of the emerging company as of the date of adoption of fresh-start reporting, which for us is August 31, 2012, the date the Debtors emerged from Chapter 11. To facilitate this calculation, we first determined the enterprise value of the Successor and the individual components of the opening balance sheet. The most significant item is our 33.34% interest in Piceance Energy, the value of which was estimated to be approximately $105.3 million as of the Emergence Date. We also considered the fair value of the other remaining assets. See Note 11 - Fair Value Measurements for a detailed discussion of fair value and the valuation techniques.

The estimated enterprise value and the equity value are highly dependent on the achievement of the future financial results contemplated in the projections that were set forth in the Plan. The estimates and assumptions made in the valuation are inherently subject to significant uncertainties. The primary assumptions for which there is a reasonable possibility of the occurrence of a variation that would have significantly affected the reorganization value include the assumptions regarding our direct ownership of estimated proved reserves, our indirect ownership of estimated proved reserves through our equity ownership in Piceance Energy, operating expenses, the amount and timing of capital expenditures and the discount rate utilized.

Fresh-start reporting reflects the value of the Successor as determined in the confirmed Plan. Under fresh-start reporting, our asset values are remeasured and allocated based on their respective fair values in conformity with the acquisition method of accounting for business combinations. The reorganization values approximated the fair values of the identifiable net assets. Liabilities existing as of the Effective Date, other than deferred taxes and derivatives, were recorded at the present value of amounts expected to be paid using appropriate risk adjusted interest rates. Deferred taxes and derivatives were determined in conformity with applicable accounting standards. Predecessor accumulated depreciation, accumulated amortization and retained deficit were eliminated. Under the Plan, our priority non-tax claims and secured claims are unimpaired in accordance with the Bankruptcy Code. Each general unsecured claim and noteholder claims received its pro rata share of new common stock of Par in full satisfaction of its claims.

F-49

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

The following condensed consolidated balance sheet presents the implementation of the Plan and the adoption of fresh-start reporting as of the Effective Date. Reorganization adjustments have been recorded within the condensed consolidated balance sheet to reflect the effects of the Plan, including discharge of liabilities subject to compromise and the adoption of fresh-start reporting.

	August 31, 2012
	Predecessor			Plan of Reorganization Adjustments			Fresh Start Reporting Adjustments			Successor
	(in thousands)
ASSETS
Current assets
Cash and cash equivalents	$	1,954		$	74,167	(a)	$			$	4,882
					(45,035	)(c)
					(24,204	)(d)
					(2,000	)(e)
Trust assets		—			3,446	(e)					3,446
Restricted cash		—			20,359	(d)					20,359
Trade accounts receivable, net		3,708			(1,727	)(a)		(1,981	)(g)		—
Prepaid assets		4,777						(4,777	)(g)		—
Prepaid reorganization costs		1,326						(1,326	)(g)		—
Total current assets		11,765									28,687
Property and equipment
Oil and gas properties
Unproved		84						(84	)(g)		—
Proved		759,755			(740,392	)(a)		(14,776	)(g)		4,587
Land		4,000			(4,000	)(a)					—
Other		73,021			(47,493	)(a)		(21,289	)(g)		4,239
Total property and equipment		836,860									8,826
Less accumulated depreciation and depletion		(642,172	)		607,603	(a)		34,569	(g)		—
Property and equipment, net		194,688									8,826
Long-term assets:
Investments in unconsolidated affiliates		3,629			105,344	(a)		(3,629	)(g)		105,344
Other long-term assets		307						(253	)(g)		54
Total long-term assets		3,936									105,398
Total assets	$	210,389								$	142,911
LIABILITIES AND EQUITY
Current liabilities
Liabilities not subject to compromise
Debtor in possession financing	$	56,535			(56,535	)(c)				$	—
Accounts payable and other accrued liabilities		4,897									4,897
Other accrued liabilities		9,224			(2,685	)(b)					2,640
					(1,500	)(c)
					(3,845	)(d)
					1,446	(e)
Accrued reorganization and trustee expense		70,656									7,537
Liabilities subject to compromise
3 3⁄4% Senior notes		115,000			(115,000	)(b)					—
7% Senior convertible notes		150,000			(150,000	)(b)					—
Accounts payable and other accrued liabilities		17,203			(2,560	)(a)		(1,981	)(g)		12,336
					(3,526	)(d)		3,200	(g)
Total current liabilities		352,859									19,873
Long-term liabilities
Liabilities not subject to compromise
Long - term debt		—			6,335	(c)					6,335
Derivative liabilities		—			6,665	(c)					6,665
Asset retirement obligations		4,414			(3,938	)(a)					476
Total liabilities		357,273									33,349
Stockholders’ equity
Common stock		288			1,457	(b)		(288	)(f)		1,477
					20	(d)
Additional paid-in capital		1,643,285			100,084	(b)		288	(f)		108,085
					1,318	(d)		(1,636,890	)(h)
Retained earnings (accumulated deficit)		(1,790,457	)		166,144	(b)		(14,765	)(g)		—
					2,188	(d)		1,636,890	(h)
Total stockholders’ equity (deficit)		(146,884	)								109,562
Total liabilities and equity (deficit)	$	210,389								$	142,911

F-50

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Notes to Plan of Reorganization and Fresh Start Accounting Adjustments

(a) Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.

(b) Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(c) Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.

(d) Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(e) Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).

(f) Reflects the cancellation of Predecessor common stock.

(g) Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(h) Reflects the elimination of Predecessor’s accumulated deficit.

F-51

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 20 - Subsequent Events

On the January 23, 2014 and in connection with the consummation of the Reverse Stock Split as described in Note 1-Overview, we and certain of our subsidiaries entered into an Eleventh Amendment to our Loan Agreement pursuant to which the Lender consented to Fractional Share Cash Payments.

As a result of the Reverse Stock Split, every ten pre-split shares of Common Stock issued prior to January 29, 2014, the effective date of the reverse stock split for trading purposes, were exchanged for one post-split share of Common Stock, with fractional shares paid in cash at an amount equal to the product obtained by multiplying (a) the closing price of the Common Stock as reported on the OTCQB Marketplace on January 23, 2014, by (b) the fraction of one share owned by the stockholder. Further, the number of shares of Common Stock issued and outstanding was reduced from approximately 301,141,520 on January 23, 2014 to approximately 30,114,352. The number of authorized shares of Common Stock will remain at 500,000,000 and the par value of the Common Stock will remain at $0.01 per share. All references in the financial statements to the number of shares of common stock or warrants, price per share and weighted average number of common stock outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor.

Note 21 - Disclosures About Capitalized Costs, Costs Incurred (Unaudited)

Capitalized costs related to oil and gas activities are as follows (in thousands):

	Successor						Predecessor
	December 31, 2013			December 31, 2012			August 31, 2012
Company:
Unproved properties	$	—		$	—		$	84
Proved properties		4,949			4,804			759,755
		4,949			4,804			759,839
Accumulated depreciation and depletion		(1,868	)		(337	)		(642,172	)
	$	3,081		$	4,467		$	117,667
Company’s Share of Piceance Energy:
Unproved properties	$	15,763		$	16,180
Proved properties		168,378			134,638
		184,141			150,818
Accumulated depreciation and depletion		(38,452	)		(2,808	)
	$	145,689		$	148,010

(1) The capitalized cost amounts presented are as of August 31, 2012 for the Predecessor and exclude adjustments resulting from the plan or reorganization and fresh-start reporting (see Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan).

Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Company:
Development costs incurred on proved undeveloped reserves	$	—	$	—	$	1,613
Development costs - other		142		—		—
Total	$	142	$	—	$	1,613
Company’s Share of Piceance Energy:
Unproved properties acquisition costs	$	—	$	206
Proved properties acquisition costs(1)		—		32,519
Development costs - other		6,380		291
Total	$	6,380	$	33,016

(1) Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.

F-52

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

At December 31, 2011, the company had $8,770 of suspended exploratory well cost subject to evaluation. Upon the emergency from Bankruptcy on August 31, 2012 all capitalized oil and natural gas property costs, including suspended exploratory well cost, were transferred to Piceance in exchange for cash and a 33.34% equity interest in Piceance. For the period from September 1, 2012 through December 31, 2012 and for the year ended December 31, 2013 neither the company or Piceance incurred exploratory well costs so no amounts were capitalized or expensed during these respective periods. Accordingly, there were no suspended exploratory well costs at December 31, 2012 and 2013 that were being evaluated.

A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows:

	Successor				Predecessor
	Year Ended December 31, 2013		September 1 through December 31, 2012		January 1 through August 31, 2012
Company:
Revenue:
Oil and gas revenues	$	7,739	$	2,144	$	23,079
Expenses:
Production costs		5,696		1,688		16,980
Depletion and amortization		1,593		370		16,041
Exploration		—		—		2
Abandoned and impaired properties		—		—		151,347
Results of operations of oil and gas producing activities	$	450	$	86	$	(161,291	)
Company’s share of Piceance Energy:
Revenue:
Oil and gas revenues	$	20,364	$	6,464
Expenses:
Production costs		9,885		3,033
Depletion and amortization		8,855		2,808
Results of operations of oil and gas producing activities	$	1,624	$	623
Total Company and Piceance Energy income from operations of oil and gas producing activities	$	2,074	$	709

F-53

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

Note 22 - Information Regarding Proved Oil and Gas Reserves (Unaudited)

There are numerous uncertainties inherent in estimating quantities of proved crude oil and natural gas reserves. Crude oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be precisely measured. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of crude oil and natural gas that are ultimately recovered.

Estimates of the company’s oil and natural gas reserves and present values as of December 31, 2013 and 2012, and August 31, 2012 were prepared by Netherland, Sewell & Associates, Inc., independent reserve engineers.

A summary of changes in estimated quantities of proved reserves for the year ended December 31, 2013 and for respective periods in 2012 is as follows:

	Gas (MMcf)			Oil (MBbl)			NGLS (MBb1)			Total (MMcfe)(5)
Company:
Estimated Proved Reserves: Balance at January 1, 2012 (Predecessor)(1)		87,209			494			—			90,173
Revisions of quantity estimate		—			85			—			512
Sale/disposition of properties(2)		(82,357	)		(235	)		—			(83,770	)
Production		(4,852	)		(67	)		—			(5,256	)
Estimated Proved Reserves: Balance at August 31, 2012 (Successor)		—			277			—			1,659
Revisions of quantity estimate		456			31			—			643
Production		(10	)		(22	)		—			(139	)
Estimated Proved Reserves: Balance at December 31, 2012 (Successor)		446			286			—			2,163
Revisions of quantity estimate		460			16			—			557
Extensions and discoveries		9			3			—			25
Production		(253	)		(69	)		—			(667	)
Estimated Proved Reserves: Balance at December 31, 2013 (Successor)		662			236			—			2,078
Company’s Share of Piceance Energy:
Estimated Proved Reserves: Balance at September 1, 2012		—			—			—			—
Transfer from investees(3)		83,915			560			4,228			112,639
Revisions of quantity estimate		8,053			41			387			10,621
Extensions and discoveries		32,073			236			1,778			44,151
Production		(1,391	)		(6	)		(48	)		(1,711	)
Estimated Proved Reserves: Balance at December 31, 2012		122,650			831			6,345			165,700
Revisions of quantity estimate		72,436			174			2,818			90,387
Extensions and discoveries		3,599			(374	)		(1,334	)		(6,643	)
Production		(12,088	)		(47	)		(428	)		(14,935	)
Estimated Proved Reserves: Balance at December 31, 2013		186,597			584			7,401			234,509
Total Estimated Proved Reserves: Balance at December 31, 2013		187,259			820			7,401			236,587
Proved developed reserves
December 31, 2012		158			286			—			1,875
December 31, 2012 - Company Share of Piceance Energy		48,680			237			2,253			63,617
Total December 31, 2012		48,838			523			2,253			65,492
Proved undeveloped reserves
December 31, 2012		288			—			—			288
December 31, 2012 - Company Share of Piceance Energy		73,970			594			4,092			102,083
Total December 31, 2012		74,258			594			4,092			102,371
Proved developed reserves
December 31, 2013		662			236			—			2,078
December 31, 2013 - Company Share of Piceance Energy		45,072			165			1,627			55,829
Total December 31, 2013		45,734			401			1,627			57,907
Proved undeveloped reserves
December 31, 2013		—			—			—			—
December 31, 2013 - Company Share of Piceance Energy		141,525			419			5,774			178,680
Total December 31, 2013		141,525			419			5,774			178,680

F-54

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

	CIG per Mbtu		WTI per Bbl
Base pricing, before adjustments for contractual differentials:(4)
August 31, 2012	$	2.75	$	90.85
December 31, 2012	$	2.56	$	91.21
December 31, 2012 - Piceance	$	2.56	$	91.21
December 31, 2013	$	3.53	$	96.91
December 31, 2013 - Piceance	$	3.53	$	96.91

⁽¹⁾  At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.

⁽²⁾  On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).

⁽³⁾  On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).

⁽⁴⁾  Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.

⁽⁵⁾  MMcfe is based on a ratio of 6 Mcf to 1 barrel.

Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests.

	Successor						Predecessor
	December 31,						August 31,
	2013			2012			2012
	(in thousands)						(in thousands)
Company:
Future net cash flows	$	26,861		$	30,444		$	28,691
Future costs:
Production		21,999			20,596			19,973
Development and abandonment		319			319			319
Income taxes1		—			—			—
Future net cash flows		4,543			9,529			8,399
10% discount factor		(1,006	)		(1,519	)		(1,176	)
Standardized measure of discounted future net cash flows	$	3,537		$	8,010		$	7,223
Company’s Share of Piceance Energy:
Future net cash flows	$	984,205		$	568,706
Future costs:
Production		430,506			199,277
Development and abandonment		234,905			154,054
Income taxes1		—			—
Future net cash flows		318,794			215,375
10% discount factor		(229,469	)		(143,416	)
Standardized measure of discounted future net cash flows	$	89,325		$	71,959
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues	$	92,862		$	79,969

¹  No income tax provision is included in the standardized measure calculation shown above as the company does not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.

F-55

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements - (Continued)

The principal sources of changes in the standardized measure of discounted net cash flows for the year ended December 31, 2013 and for the respective periods during 2012 are as follows (in thousands):

	Successor
	December 31,			Company Share of Piceance Energy December 31,			Total
	2013			2013			2013
Beginning of the year
Beginning of the period	$	8,010		$	71,959		$	79,969
Sales of oil and gas production during the period, net of production costs		(2,044	)		(10,478	)		(12,522	)
Net change in prices and production costs		(3,833	)		(2,588	)		(6,421	)
Changes in estimated future development costs		—			8,831			8,831
Extensions, discoveries and improved recovery		147			15,471			15,618
Revisions of previous quantity estimates, estimated timing of development and other		395			(4,948	)		(4,553	)
Previously estimated development and abandonment costs incurred during the period		—			3,142			3,142
Other		61			740			801
Accretion of discount		801			7,196			7,997
End of period	$	3,537		$	89,325		$	92,862

	Successor									Predecessor
	Period from September 1, through December 31,			Company Share of Piceance Energy September 1, through December 31,			Total			January 1, through August 31,
	2012			2012			2012			2012
Beginning of the year										$	129,695
Beginning of the period	$	7,223		$	—		$	7,223			—
Transfer from investees		—			55,253			55,253			—
Sales of oil and gas production during the period, net of production costs		(456	)		(3,639	)		(4,095	)		(5,954	)
Net change in prices and production costs		(667	)		(139	)		(806	)		378
Changes in estimated future development costs		—			5			5			—
Extensions, discoveries and improved recovery		763			569			1,332			—
Revisions of previous quantity estimates, estimated timing of development and other		648			13,708			14,356			(7,439	)
Sales/disposition of reserves in place		—			—			—			(118,104	)
Other		258			4,360			4,618			—
Accretion of discount		241			1,842			2,083			8,647
End of period	$	8,010		$	71,959		$	79,969		$	7,223

F-56

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange of Act of 1934, the registrant has caused this Form 10-K/A to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Houston and State of Texas on the 30^th day of May, 2014.

PAR PETROLEUM CORPORATION
By:	/s/ William Monteleone.
	William Monteleone, Chief Executive Officer
By:	/s/ Christopher Micklas
	Christopher Micklas, Chief Financial Officer

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement Nos. 333-192519 and 333-195662 on Form S-3 and Registration Statement No. 333-185612 on Form S-8 of our report dated March 31, 2014 (May 30, 2014, as to the effects of the restatement discussed in the Introductory Note), relating to the consolidated financial statements of Par Petroleum Corporation as of and for the year ended December 31, 2013 (which report expresses an unqualified opinion and includes an explanatory paragraph relating to the restatement discussed in the Introductory Note) appearing in this Annual Report on Form 10-K/A of Par Petroleum Corporation for the year ended December 31, 2013.

/s/ DELOITTE & TOUCHE LLP

Houston, Texas

May 30, 2014

EX-23.2

Exhibit 23.2

We hereby consent to the incorporation by reference in the Registration Statement Nos. 333-192519 and 333-195662 on Form S-3 and Registration Statement No. 333-185612 on Form S-8 of Par Petroleum Corporation of our report dated March 27, 2013 and updated for Note 14 on March 31, 2014, with respect to the consolidated balance sheet of Par Petroleum Corporation and subsidiaries as of December 31, 2012, and the related consolidated statements of operations and comprehensive loss, changes in equity, and cash flows for the period from September 1, 2012 through December 31, 2012 and of our report dated February 28, 2014, with respect to the balance sheet of Piceance Energy, LLC as of December 31, 2013, and the related statements of operations, members’ equity, and cash flows for the year then ended, appearing in the Annual Report on Form 10-K/A of Par Petroleum Corporation for the fiscal year ended December 31, 2013.

/s/ EKS&H LLLP

Denver, Colorado

April 29, 2014

EX-23.3

Exhibit 23.3

Consent of Independent Registered Public Accounting Firm

The Board of Directors

Par Petroleum Corporation, Successor to Delta Petroleum Corporation:

We consent to the incorporation by reference in the registration statement on Form S-8 (No. 333-185612) and on Form S-3 (File No. 333-192519, No. 333-195662) of Par Petroleum Corporation (formerly Delta Petroleum Corporation) and subsidiaries (the Predecessor) of our report dated March 27, 2013, with respect to the consolidated statements of operations (Predecessor), changes in equity (Predecessor), and cash flows (Predecessor) for the period January 1, 2012 through August 31, 2012, which report appears in the December 31, 2013 annual report on Form 10-K/A of Par Petroleum Corporation.

Our report over the consolidated financial statements contains an explanatory paragraph that states that the Predecessor filed a petition for reorganization under Chapter 11 of the United States Bankruptcy Code on December 16, 2011. The Predecessor’s plan of reorganization became effective and the Company emerged from bankruptcy protection on August 31, 2012. In connection with its emergence from bankruptcy, the Company adopted the guidance for fresh start accounting in conformity with FASB ASC Topic 852, Reorganizations, effective as of August 31, 2012. Accordingly, the Predecessor’s consolidated financial statements prior to August 31, 2012 are not comparable to its consolidated financial statements for periods after August 31, 2012.

KPMG LLP

Denver, Colorado

May 30, 2014

EX-23.4

Exhibit 23.4

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS

We hereby consent to the inclusion in the Annual Report on Form 10-K, as amended by Amendments No. 1 and 2 on Form 10-K/A, of Par Petroleum Corporation for the year ended December 31, 2013 (collectively, the “Annual Report”), of our report dated March 17, 2014, with respect to estimates of reserves and future net revenue of Par Petroleum Corporation, as of December 31, 2013, and to all references to our firm included in the Annual Report.

We also consent to the incorporation by reference in Registration Statement Nos. 333-192519 and 333-195662 on Form S-3 and Registration Statement No. 333-185612 on Form S-8 of our report dated March 17, 2014, with respect to estimates of reserves and future net revenue of Par Petroleum Corporation, as of December 31, 2013, included in the Annual Report, and to the reference to us under the heading “Experts” in such Registration Statements.

NETHERLAND, SEWELL & ASSOCIATES, INC.
By:	/s/ C.H. (Scott) Rees III
	C.H. (Scott) Rees III, P.E. Chairman and Chief Executive Officer

Dallas, Texas

May 30, 2014

Please be advised that the digital document you are viewing is provided by Netherland, Sewell & Associates, Inc. (NSAI) as a convenience to our clients. The digital document is intended to be substantively the same as the original signed document maintained by NSAI. The digital document is subject to the parameters, limitations, and conditions stated in the original document. In the event of any differences between the digital document and the original document, the original document shall control and supersede the digital document.

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 Monteleone, certify that:

1. I have reviewed this annual report on Form 10-K/A (Amendment No. 2) of Par Petroleum Corporation;

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: May 30, 2014

/s/ William Monteleone

William Monteleone

Chief Executive Officer

EX-31.2

Exhibit 31.2

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

I, Christopher Micklas, certify that:

1. I have reviewed this annual report on Form 10-K/A (Amendment No. 2) of Par Petroleum Corporation;

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: May 30, 2014

/s/ Christopher Micklas

Christopher Micklas

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 Annual Report of Par Petroleum Corporation (the “Company”) on Form 10-K/A (Amendment No. 2) for the year ended December 31, 2013 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William Monteleone, 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 Monteleone

William Monteleone

Chief Executive Officer

May 30, 2014

EX-32.2

Exhibit 32.2

CERTIFICATION OF PRINCIPAL FINANCIAL 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 Annual Report of Par Petroleum Corporation (the “Company”) on Form 10-K/A (Amendment No. 2) for the year ended December 31, 2013 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Christopher Micklas, 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/ Christopher Micklas

Christopher Micklas

Chief Financial Officer

May 30, 2014

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Intangible assets (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Finite-Lived Intangible Assets

Our intangible assets consist of the following (in thousands):

	December 31,
	2013			2012
Amortized intangible assets:
Gross carrying amount:
Supplier relationships	$	3,360		$	3,360
Rail car leases		3,249			3,249
Historical shipper status		2,200			2,200
Trade names and trademarks		4,689			—
Subtotal		13,498			8,809
Accumulated amortization
Supplier relationships		(258	)		—
Rail car leases		(650	)		—
Historical shipper status		(1,100	)		—
Trade name and trademarks		(320	)		—
Subtotal		(2,328	)		—
Net:
Supplier relationships		3,102			3,360
Rail car leases		2,599			3,249
Historical shipper status		1,100			2,200
Trade name and trademarks		4,369			—
Total amortized intangible assets, net	$	11,170		$	8,809

Finite-lived Intangible Assets Amortization Expense

Expected future amortization expense for each of the next five years and thereafter is as follows (in thousands):

Year Ended	Amount
2014	$	3,571
2015		2,471
2016		2,151
2017		908
2018		258
Thereafter		1,811
	$	11,170

Schedule of Goodwill

During the year ended December 31, 2013 the changes in the carrying amount of goodwill for the year ended December 31, 2013 were as follows (in thousands):

Balance at beginning of period	$	7,756
Additions		13,613
Texadian purchase price adjustments		(766	)
Balance at end of period	$	20,603

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Information Regarding Proved Oil and Gas Reserves (Details) (Detail)	4 Months Ended		8 Months Ended		12 Months Ended
	Dec. 31, 2012 MMcf		Aug. 31, 2012 MMcf		Dec. 31, 2013 MMcf
Reserve Quantities [Line Items]
Ending Balance					236,587	[1]
Proved developed reserve	65,492	[1]			57,907	[1]
Proved undeveloped reserve	102,371	[1]			178,680	[1]
Company [Member]
Reserve Quantities [Line Items]
Beginning Balance	1,659	[1]			2,163	[1]
Revisions of quantity estimate	643	[1]			557	[1]
Extensions and discoveries					25	[1]
Production	(139)	[1]			(667)	[1]
Ending Balance	2,163	[1]			2,078	[1]
Proved developed reserve	1,875	[1]			2,078	[1]
Proved undeveloped reserve	288	[1]			0	[1]
Company's Share of Piceance Energy [Member]
Reserve Quantities [Line Items]
Beginning Balance	0	[1]			165,700	[1]
Transfer from investees	112,639	[1],[2]
Revisions of quantity estimate	10,621	[1]			90,387	[1]
Extensions and discoveries	44,151	[1]			(6,643)	[1]
Production	(1,711)	[1]			(14,935)	[1]
Ending Balance	165,700	[1]			234,509	[1]
Proved developed reserve	63,617	[1]			55,829	[1]
Proved undeveloped reserve	102,083	[1]			178,680	[1]
Natural Gas [Member]
Reserve Quantities [Line Items]
Ending Balance					187,259
Proved developed reserve	48,838				45,734
Proved undeveloped reserve	74,258				141,525
Natural Gas [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance	0				446
Revisions of quantity estimate	456				460
Extensions and discoveries					9
Production	(10)				(253)
Ending Balance	446		0		662
Proved developed reserve	158				662
Proved undeveloped reserve	288				0
Base Pricing, before adjustments for contractual differentials	2.56		2.75		3.53
Natural Gas [Member] | Company's Share of Piceance Energy [Member]
Reserve Quantities [Line Items]
Beginning Balance	0				122,650
Transfer from investees	83,915	[2]
Revisions of quantity estimate	8,053				72,436
Extensions and discoveries	32,073				3,599
Production	(1,391)				(12,088)
Ending Balance	122,650				186,597
Proved developed reserve	48,680				45,072
Proved undeveloped reserve	73,970				141,525
Base Pricing, before adjustments for contractual differentials	2.56				3.53
Natural Gas Liquids [Member]
Reserve Quantities [Line Items]
Ending Balance					7,401
Proved developed reserve	2,253				1,627
Proved undeveloped reserve	4,092				5,774
Natural Gas Liquids [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance	0				0
Revisions of quantity estimate	0				0
Extensions and discoveries					0
Production	0				0
Ending Balance	0				0
Proved developed reserve	0				0
Proved undeveloped reserve	0				0
Natural Gas Liquids [Member] | Company's Share of Piceance Energy [Member]
Reserve Quantities [Line Items]
Beginning Balance	0				6,345
Transfer from investees	4,228	[2]
Revisions of quantity estimate	387				2,818
Extensions and discoveries	1,778				(1,334)
Production	(48)				(428)
Ending Balance	6,345				7,401
Proved developed reserve	2,253				1,627
Proved undeveloped reserve	4,092				5,774
Oil [Member]
Reserve Quantities [Line Items]
Ending Balance					820
Proved developed reserve	523				401
Proved undeveloped reserve	594				419
Oil [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance	277				286
Revisions of quantity estimate	31				16
Extensions and discoveries					3
Production	(22)				(69)
Ending Balance	286		277		236
Proved developed reserve	286				236
Proved undeveloped reserve	0				0
Base Pricing, before adjustments for contractual differentials	91.21		90.85		96.91
Oil [Member] | Company's Share of Piceance Energy [Member]
Reserve Quantities [Line Items]
Beginning Balance	0				831
Transfer from investees	560	[2]
Revisions of quantity estimate	41				174
Extensions and discoveries	236				(374)
Production	(6)				(47)
Ending Balance	831				584
Proved developed reserve	237				165
Proved undeveloped reserve	594				419
Base Pricing, before adjustments for contractual differentials	91.21				96.91
Predecessor [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance			90,173	[1],[3]
Revisions of quantity estimate			512	[1]
Sale/disposition of properties			(83,770)	[1],[4]
Production			(5,256)	[1]
Predecessor [Member] | Natural Gas [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance			87,209	[3]
Revisions of quantity estimate			0
Sale/disposition of properties			(82,357)	[4]
Production			(4,852)
Predecessor [Member] | Natural Gas Liquids [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance			0	[3]
Revisions of quantity estimate			0
Sale/disposition of properties			0	[4]
Production			0
Predecessor [Member] | Oil [Member] | Company [Member]
Reserve Quantities [Line Items]
Beginning Balance			494	[3]
Revisions of quantity estimate			85
Sale/disposition of properties			(235)	[4]
Production			(67)

[1] MMcfe is based on a ratio of 6 Mcf to 1 barrel.

[2] On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).

[3] At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.

[4] On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).

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Summary of Significant Accounting Policies (Details) (Detail)	12 Months Ended
	Dec. 31, 2013
Refining [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	8 years
Refining [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	47 years
Logistic [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Logistic [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Retail [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	14 years
Retail [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	18 years
Corporate [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Corporate [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	7 years
Software [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years

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Disclosures About Capitalized Costs, Costs Incurred (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

Oil And Gas Property Successful Effort Method

Capitalized costs related to oil and gas activities are as follows (in thousands):

	Successor						Predecessor
	December 31, 2013			December 31, 2012			August 31, 2012
Company:
Unproved properties	$	—		$	—		$	84
Proved properties		4,949			4,804			759,755
		4,949			4,804			759,839
Accumulated depreciation and depletion		(1,868	)		(337	)		(642,172	)
	$	3,081		$	4,467		$	117,667
Company’s Share of Piceance Energy:
Unproved properties	$	15,763		$	16,180
Proved properties		168,378			134,638
		184,141			150,818
Accumulated depreciation and depletion		(38,452	)		(2,808	)
	$	145,689		$	148,010

(1) The capitalized cost amounts presented are as of August 31, 2012 for the Predecessor and exclude adjustments resulting from the plan or reorganization and fresh-start reporting (see Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan).

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure

Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Company:
Development costs incurred on proved undeveloped reserves	$	—	$	—	$	1,613
Development costs - other		142		—		—
Total	$	142	$	—	$	1,613
Company’s Share of Piceance Energy:
Unproved properties acquisition costs	$	—	$	206
Proved properties acquisition costs(1)		—		32,519
Development costs - other		6,380		291
Total	$	6,380	$	33,016

(1) Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.

Capitalized Exploratory Well Costs, Roll Forward

A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows:

	Successor				Predecessor
	Year Ended December 31, 2013		September 1 through December 31, 2012		January 1 through August 31, 2012
Company:
Revenue:
Oil and gas revenues	$	7,739	$	2,144	$	23,079
Expenses:
Production costs		5,696		1,688		16,980
Depletion and amortization		1,593		370		16,041
Exploration		—		—		2
Abandoned and impaired properties		—		—		151,347
Results of operations of oil and gas producing activities	$	450	$	86	$	(161,291	)
Company’s share of Piceance Energy:
Revenue:
Oil and gas revenues	$	20,364	$	6,464
Expenses:
Production costs		9,885		3,033
Depletion and amortization		8,855		2,808
Results of operations of oil and gas producing activities	$	1,624	$	623
Total Company and Piceance Energy income from operations of oil and gas producing activities	$	2,074	$	709

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Debt (Details) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Total debt, net of unamortized debt discount	$ 97,280	$ 42,391
Less: current maturities	(3,250)	(35,000)
Long-term debt, net of current maturities and unamortized discount	94,030	7,391
Delayed Draw Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	0	13,465
Warrant [Member]
Debt Instrument [Line Items]
Unamortized Debt Discount	0	(6,014)
Embedded Derivative [Member]
Debt Instrument [Line Items]
Unamortized Debt Discount	0	(60)
ABL Facility [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	51,800	0
Retail Credit Agreement [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	26,000	0
Tranche B Loan [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	$ 19,480	$ 35,000

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Investment in Piceance Energy (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013 Piceance Energy [Member]	Dec. 31, 2012 Piceance Energy [Member]	Aug. 31, 2012 Piceance Energy [Member]	Dec. 31, 2013 Parent Company [Member] Piceance Energy [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method investment ownership percentage			33.34%		33.34%
Equity Method Investments, Additional Capital Contribution			$ 60,000,000			$ 20,000,000
Line Of Credit Facility Maximum Borrowing Capacity			400,000,000
Line Of Credit Facility Current Borrowing Capacity			120,000,000
Line Of Credit Facility Amount Outstanding			90,200,000		100,000,000
Depreciation, Depletion, Amortization and Accretion Expense	401,000	5,982,000	26,600,000	8,500,000
Losses on derivative instruments			770,000	917,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity			$ 15,100,000	$ 15,900,000
Lack Of Control And Marketability Discounts Amortization Term		15 years

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Fair Value Measurements (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net, Total	$ 17,439
Net non-cash working capital [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,631	[1]
Supplier relationships [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,360	[2]
Historical Shipper Status [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	2,200	[3]
Rail car leases [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,249	[4]
Goodwill [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	7,756	[5]
Deferred tax liability [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities, Total	$ (2,757)	[6]

[1] Current assets acquired and liabilities assumed were recorded at their net realizable value.

[2] The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

[3] The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

[4] The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.

[5] The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

[6] A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

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Related Party Transaction (Details Textual) (Detail)	12 Months Ended
	Dec. 31, 2013
Travel And Out Of Pocket Expense Description	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 or Whitebox, as applicable, will obtain our consent prior to incurring additional costs

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Segment Information (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Segment Reporting Information, by Segment

Following our acquisitions of HIE and Texadian, we have three business segments: (i) Refining, Distribution and Marketing, (ii) Natural Gas and Oil Operations and (iii) Commodity Marketing and Logistics. Corporate and Other includes trust litigation and settlements and other administrative costs. Summarized financial information concerning reportable segments consists of the following (in thousands):

For the year ended December 31, 2013	Refining, Distribution and Marketing			Natural Gas and Oil Operations		Commodity Marketing and Logistics			Corporate and Other			Total
Sales and operating revenues	$	778,126		$	7,739	$	100,149		$	—		$	886,014
Depreciation, depletion, amortization and accretion		2,267			1,686		2,009			20			5,982
Operating income (loss)		(27,870	)		246		9,126			(29,367	)		(47,865	)
Loss from unconsolidated affiliate													(2,941	)
Interest expense and financing costs, net													(19,471	)
Other income (expense)													808
Change in value of common stock warrants													(10,114	)
Gain on derivative instruments													410
Loss before income taxes													(79,173	)
Income tax benefit													—
Net loss												$	(79,173	)
Capital expenditures, including acquisitions	$	567,332		$	471	$	(1,300	)	$	544		$	567,047

Following our acquisition of Texadian, at December 31, 2012, we had two business segments: (i) Natural Gas and Oil Operations and (ii) Commodity Marketing and Logistics. For the period from September 1 through December 31, 2012, all of the operations as reported on our consolidated statement of operations related to Natural Gas and Oil Operations. For the period from September 1 through December 31, 2012, expenditures for long term assets, including goodwill and other intangible assets by segment were as follows (in thousands):

	Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
Capital expenditures, including acquisitions	$	415	$	17,439	$	—	$	17,854

Schedule of Segment Reporting Information, by Segment, Financial Position

Total assets by segment were as follows (in thousands):

	Refining, Distribution and Marketing		Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
At December 31, 2013	$	641,840	$	109,316	$	52,048	$	10,009	$	813,213
At December 31, 2012	$	—	$	116,034	$	62,754	$	10,794	$	189,582

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2013

Property Plant And Equipment Estimated Useful Life

We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of each asset as follows:

Assets	Lives in Years
Refining	8 to 47
Logistic	3 to 30
Retail	14 to 18
Corporate	3 to 7
Software	3

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Fair Value Measurements (Details 2) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Sep. 25, 2013 Purchase Price Allocation Of Hie [Member]		Sep. 25, 2013 Purchase Price Allocation Of Hie [Member] Property, Plant and Equipment, Other Types [Member]		Sep. 25, 2013 Purchase Price Allocation Of Hie [Member] Land [Member]
Net working capital			$ 462,059	[1]
Property, Plant, and Equipment, Fair Value Disclosure					58,782	[2]	39,800	[3]
Trade names and trade marks			4,689	[4]
Goodwill			13,613	[5]
Contingent consideration liability	11,980	0	(11,980)	[6]
Other noncurrent liabilities			(6,384)	[7]
Fair Value, Net Asset (Liability), Total			$ 560,579

[1] Current assets acquired and liabilities assumed were recorded at their net realizable value.

[2] The estimated fair value of the property, plant and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and external obsolescence. We consider this to be a Level 3 fair value measurement.

[3] The estimated fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement.

[4] The estimated fair value of the trade names and trademarks was estimated using a form of the income approach, the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.

[5] The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

[6] The estimated fair value of the liability for contingent consideration was estimated using Monte Carlo Simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.

[7] Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.

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Debt (Details 2) (Detail)	12 Months Ended
	Dec. 31, 2013
2013 Fiscal Year [Member]
Debt Instrument [Line Items]
Debt Instrument, Maximum Leverage Ratio	5.75
2014 Fiscal Year [Member]
Debt Instrument [Line Items]
Debt Instrument, Maximum Leverage Ratio	5.50
2015 Fiscal Year [Member]
Debt Instrument [Line Items]
Debt Instrument, Maximum Leverage Ratio	5.25
2016 Fiscal Year [Member]
Debt Instrument [Line Items]
Debt Instrument, Maximum Leverage Ratio	5.00
2017 Fiscal Year, and at all times thereafter [Member]
Debt Instrument [Line Items]
Debt Instrument, Maximum Leverage Ratio	4.75

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Commitments and Contingencies (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013
Commitment And Contingencies [Line Items]
2014	$ 382
2015	382
2016	382
2017	382
2018	420
Thereafter	420
Total minimum lease payments	2,368
Less amount representing interest	634
Total minimum rental payments	$ 1,734

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Investment in Piceance Energy (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
ASSETS
Current assets	$ 59,926	$ 544,501
Current liabilities	(69,977)	(453,388)
Oil, natural gas and natural gas liquids revenues	2,144	7,739
Loss from operations	(5,021)	(47,865)
Net loss	(8,839)	(79,173)
Piceance Energy [Member]
ASSETS
Current assets	6,275	5,901
Non-current assets	460,991	454,402
Current liabilities	(11,826)	(13,040)
Non-current liabilities	(94,369)	(96,738)
Oil, natural gas and natural gas liquids revenues	19,391	61,091
Loss from operations	(2,095)	(6,765)
Net loss	$ (3,975)	$ (10,546)

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Disclosures About Capitalized Costs, Costs Incurred (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	4 Months Ended		12 Months Ended		8 Months Ended
	Dec. 31, 2012 Company [Member]	Dec. 31, 2013 Company [Member]	Dec. 31, 2012 Company's Share of Piceance Energy [Member]		Dec. 31, 2013 Company's Share of Piceance Energy [Member]		Aug. 31, 2012 Predecessor [Member] Company [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Unproved properties acquisition costs			$ 206		$ 0
Development costs incurred on proved undeveloped reserves	0	0					1,613
Proved properties acquisition costs			32,519	[1]	0	[1]
Development costs - other	0	142	291		6,380		0
Total	$ 0	$ 142	$ 33,016		$ 6,380		$ 1,613

[1] Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.

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Fair Value Measurements (Details) (Detail) (USD $) In Thousands, unless otherwise specified	Aug. 31, 2012
Piceance Energy [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Investment in Piceance Energy	$ 105,300
Fair Value, Measurements, Nonrecurring [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Proved	4,587	[1],[2]
Fair Value, Measurements, Nonrecurring [Member] | Frac tanks [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Other assets	1,400	[3]
Fair Value, Measurements, Nonrecurring [Member] | Compressors [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Other assets	2,800	[3]
Fair Value, Measurements, Nonrecurring [Member] | Miscellaneous [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Other assets	39	[4]
Fair Value, Measurements, Nonrecurring [Member] | Piceance Energy [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Investment in Piceance Energy	$ 105,344	[5]

[1] Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.

[2] The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.

[3] The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.

[4] Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.

[5] The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves' future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

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Defined Contribution Plans (Details Textual) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	3.00%
Defined Contribution Plan, Employers Matching Contribution, Annual Vesting Percentage	6.00%
Defined Contribution Plan, Cost Recognized	$ 0
Defined Benefit Plan, Benefit Obligation, Period Increase (Decrease)	$ 502,000
Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	5.50%
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	8.50%

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Fair Value Measurements (Details 4) (Detail) (Fair Value, Measurements, Recurring [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Contingent consideration liability [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value Disclosure	$ (11,980)	$ 0
Prepaid and Other Current Assets [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value disclosure	0	(307)
Prepaid and Other Current Assets [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value disclosure	0	542
Derivative liabilities [Member] | Warrant [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value Disclosure	(17,336)	(10,900)
Derivative liabilities [Member] | Embedded Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value Disclosure	$ 0	$ (45)

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Commitments and Contingencies (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended		4 Months Ended		16 Months Ended		12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012 Customer One [Member]	Dec. 31, 2013 Predecessor [Member]	Aug. 31, 2012 Predecessor [Member] Customer One [Member]	Aug. 31, 2012 Predecessor [Member] Customer Two [Member]	Dec. 31, 2012 Wapiti Oil And Gas [Member]	Dec. 31, 2012 Wapiti Trust [Member]	Dec. 31, 2013 Wapiti Trust [Member]	Dec. 31, 2013 Tesoros [Member]	Dec. 31, 2013 Tesoros [Member] Hawaii Independent Energy LLC [Member]	Dec. 31, 2013 Texadian Energy Inc [Member]
Commitments and Contingencies [Line Items]
Renewable Fuel Usage Description		The RFS2 requires an increasing amount of renewable fuel usage, up to 36.0 billion gallons by 2022
Derivative Assets (Liabilities), at Fair Value, Net, Total										$ 15,000,000
Indemnification Obligation Limitation, Description											Tesoro's indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include 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.
Legal Fees		2,000,000
Loss Contingency, Damages Sought, Value		3,250,000
Recovery Trust Funded Amount		1,000,000
One Time Cash Payment As Consideration For Release Of Claims							1,500,000
Distribution From Trust								5,200,000	5,200,000
Percentage Of Beneficial Interest Owned		2.41934%
Loss Contingency, Claims Settled, Number		1,000
Loss Contingency, Estimate of Possible Loss	8,700,000	3,800,000
Shares Of Beneficial Interest Owned Per 1000 Of Claim				54.4
Contingency Reserve For Litigation		10,000,000
Lessee Leasing Arrangements, Capital Leases, Term of Contract		17 years
Lessee Leasing Arrangements, Capital Leases, Renewal Term Description		with four 5-year renewal options
Lessee Leasing Arrangements, Operating Leases, Term of Contract		32 years
Operating Leases, Rent Expense, Net, Total	61,000	6,200,000
Customer Revenue Description		no individual customer accounted for more than 10% of our consolidated revenue
Concentration Risk, Percentage			96.00%		59.00%	24.00%
Long-term Purchase Commitment, Amount												$ 28,000,000

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Fair Value Measurements (Details Textual) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013 Piceance Energy [Member]	Aug. 31, 2012 Piceance Energy [Member]	Dec. 31, 2013 Hawaii Independent Energy LLC [Member]	Aug. 31, 2012 Fair Value, Measurements, Nonrecurring [Member] Piceance Energy [Member]		Aug. 31, 2012 Fair Value, Measurements, Nonrecurring [Member] Proved Developed and Producing Reserves	Aug. 31, 2012 Fair Value, Measurements, Nonrecurring [Member] Proved Developed Non Producing Reserves	Aug. 31, 2012 Fair Value, Measurements, Nonrecurring [Member] Proved Undeveloped Reserves
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]
Cash flow model discount rate								10.00%	15.00%	20.00%
Equity Method investment ownership percentage			33.34%	33.34%		33.34%
Investment in Piceance Energy				$ 105,300,000		$ 105,344,000	[1]
Warrants Not Settleable In Cash Fair Value Disclosure, Per Share	$ 21.64	$ 11.30
Warrants Not Settleable in Cash, Fair Value Disclosure	17,300,000	10,900,000
Fair Value Assumptions Historical Volatilities Period1	10 years
Embedded Derivative, Fair Value of Embedded Derivative Liability		145,000
Business Combination, Contingent Consideration, Liability	$ 11,980,000				$ 11,980,000
Fair Value Assumptions, Expected Current Yield	5.72%	5.72%

[1] The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves' future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

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Debt (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
2014	$ 3,250
2015	2,600
2016	22,080
2017	54,400
2018	2,600
Thereafter	12,350
Total	$ 97,280	$ 42,391

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Segment Information

12 Months Ended

Dec. 31, 2013

Segment Information

Note 17 - Segment Information

Following our acquisitions of HIE and Texadian, we have three business segments: (i) Refining, Distribution and Marketing, (ii) Natural Gas and Oil Operations and (iii) Commodity Marketing and Logistics. Corporate and Other includes trust litigation and settlements and other administrative costs. Summarized financial information concerning reportable segments consists of the following (in thousands):

For the year ended December 31, 2013	Refining, Distribution and Marketing			Natural Gas and Oil Operations		Commodity Marketing and Logistics			Corporate and Other			Total
Sales and operating revenues	$	778,126		$	7,739	$	100,149		$	—		$	886,014
Depreciation, depletion, amortization and accretion		2,267			1,686		2,009			20			5,982
Operating income (loss)		(27,870	)		246		9,126			(29,367	)		(47,865	)
Loss from unconsolidated affiliate													(2,941	)
Interest expense and financing costs, net													(19,471	)
Other income (expense)													808
Change in value of common stock warrants													(10,114	)
Gain on derivative instruments													410
Loss before income taxes													(79,173	)
Income tax benefit													—
Net loss												$	(79,173	)
Capital expenditures, including acquisitions	$	567,332		$	471	$	(1,300	)	$	544		$	567,047

Following our acquisition of Texadian, at December 31, 2012, we had two business segments: (i) Natural Gas and Oil Operations and (ii) Commodity Marketing and Logistics. For the period from September 1 through December 31, 2012, all of the operations as reported on our consolidated statement of operations related to Natural Gas and Oil Operations. For the period from September 1 through December 31, 2012, expenditures for long term assets, including goodwill and other intangible assets by segment were as follows (in thousands):

	Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
Capital expenditures, including acquisitions	$	415	$	17,439	$	—	$	17,854

Total assets by segment were as follows (in thousands):

	Refining, Distribution and Marketing		Natural Gas and Oil Operations		Commodity Marketing and Logistics		Corporate and Other		Total
At December 31, 2013	$	641,840	$	109,316	$	52,048	$	10,009	$	813,213
At December 31, 2012	$	—	$	116,034	$	62,754	$	10,794	$	189,582

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Introductory Note (Textual) (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Quantifying Misstatement in Current Year Financial Statements [Line Items]
Understatement of net loss per common share	$ 0.44
Cost of revenues [Member]
Quantifying Misstatement in Current Year Financial Statements [Line Items]
Understatement of cost of revenues	$ 8.6

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Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2013

Schedule Of Reorganization Distributions To Satisfy Allowed Claims

At December 31, 2013 and 2012, we have reserved approximately $3.8 million and $8.7 million, respectively, representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end. A summary of claims is as follows (in thousands, except number of filed claims):

	Emergence-Date August 31, 2012				From Emergence-Date through December 31, 2012
	Filed Claims				Settled Claims								Remaining Filed Claims
									Consideration
	Count		Amount		Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		3	$	22,364		—	$	—	$	—		—		3	$	22,364
Former Employee Claims		32		16,380		13		3,685		230		20		19		12,695
Macquarie Capital (USA) Inc.		1		8,672		—		—		—		—		1		8,672
Swann and BuzzardCreek RoyaltyTrust		1		3,200		—		—		—		—		1		3,200
Other Various Claims*		75		23,114		12		2,915		29		—		63		20,199
Total		112	$	73,730		25	$	6,600	$	259		20		87	$	67,130

	For the Year Ended December 31, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364
Former Employee Claims		19		12,695		340		162		—		—
Macquarie Capital (USA) Inc.		1		8,672		2,500		—		—		—
Swann and Buzzard Creek Royalty Trust		1		3,200		2,000		—		—		—
Other Various Claims(1)		37		2,339		543		47		26		17,860
Total		59	$	26,906	$	5,383		209		28	$	40,224

(1) Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Schedule of Future Minimum Lease Payments for Capital Leases

Minimum annual lease payments including interest, for capital leases are as follows (in thousands):

2014	$	382
2015		382
2016		382
2017		382
2018		420
Thereafter		420
Total minimum lease payments		2,368
Less amount representing interest		634
Total minimum rental payments	$	1,734

Schedule of Future Minimum Rental Payments for Operating Leases

Minimum annual lease payments extending to 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):

2014	$	22,724
2015		13,277
2016		12,362
2017		10,375
2018		9,244
Thereafter		25,614
Total minimum rental payments	$	93,596

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Debt (Details 4) (Detail)	12 Months Ended
	Dec. 31, 2013
Leverage Ratio Less Than 4.00 [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Fee Percentage	0.25%
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	1.75%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	(0.25%)
Leverage Ratio 4.00-5.00 [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Fee Percentage	0.375%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	2.00%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	0.00%
Leverage Ratio Grater Than 5.00 [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Fee Percentage	0.50%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	2.25%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Revolver Applicable Margin	0.25%

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Income Tax Rate Reconciliation (Detail)	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012 Predecessor [Member]
Income Tax Rate Reconciliation [Line Items]
Federal statutory rate	(35.00%)	(35.00%)	(35.00%)
State income taxes, net of federal benefit	0.00%	0.10%	0.00%
Change in valuation allowance	(2.00%)	23.10%	(33.00%)
Professional fees related to bankruptcy reorganization	8.00%	0.00%	17.00%
Revenue from Wapiti Trust settlement	5.00%	0.00%	0.00%
Cancellation of debt tax attribute reduction	0.00%	0.00%	51.00%
Permanent Items	0.00%	3.70%	0.00%
Provision to return adjustments	0.00%	8.10%	0.00%
Actual income tax rate	(24.00%)	0.00%	0.00%

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Asset Retirement Obligation Disclosure (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Change in Asset Retirement Obligation

The following is a reconciliation of our AROs (in thousands):

	Successor				Predecessor
			September 1		January 1
	Year Ended		through		through
	December 31, 2013		December 31, 2012		August 31, 2012
Asset retirement obligation - beginning of period	$	512	$	476	$	3,799
Obligation acquired		2,601		—		—
Accretion expense		59		36		178
Change in estimate		—		—		437
Settlement upon transfer to Piceance Energy		—		—		(3,938	)
Asset retirement obligation - end of period	$	3,172	$	512	$	476

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Overview (Details Textual) (Detail) (USD $)		1 Months Ended			12 Months Ended		12 Months Ended
	Dec. 31, 2013	Jan. 23, 2014 Subsequent Event [Member]	Dec. 31, 2012 Piceance Energy [Member]	Dec. 31, 2012 Delta Petroleum [Member]	Dec. 31, 2013 Hawaii Independent Energy LLC [Member]	Dec. 31, 2013 Hawaii Independent Energy LLC [Member] Tesoro Acquisition [Member]	Dec. 31, 2012 Texadian Energy Inc [Member]
Unsecured Debt				$ 265,000,000
Payments to Acquire Businesses, Gross					75,000,000		14,000,000
Business Combination, Contingent Consideration, Liability	11,980,000				11,980,000	40,000,000
Business Combination, start-up expenses					24,300,000
Noncontrolling Interest, Ownership Percentage by Parent			33.34%
Business Combination, Consideration Transferred, Liabilities Incurred							$ 3,000,000
Stockholders Equity Reverse Stock Split		1:10 reverse stock split

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Finite-lived Intangible Assets Amortization Expense (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
2014	$ 3,571
2015	2,471
2016	2,151
2017	908
2018	258
Thereafter	1,811
Amortized intangible assets, Net	$ 11,170	$ 8,809

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Disclosures About Capitalized Costs, Costs Incurred (Details 2) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012 Company [Member]	Dec. 31, 2013 Company [Member]	Dec. 31, 2012 Company's Share of Piceance Energy [Member]	Dec. 31, 2013 Company's Share of Piceance Energy [Member]	Aug. 31, 2012 Predecessor [Member]	Aug. 31, 2012 Predecessor [Member] Company [Member]
Revenue:
Oil and gas revenues	$ 2,144	$ 7,739	$ 2,144	$ 7,739	$ 6,464	$ 20,364	$ 23,079	$ 23,079
Expenses:
Production costs			1,688	5,696	3,033	9,885		16,980
Depletion and amortization			370	1,593	2,808	8,855		16,041
Exploration			0	0				2
Abandoned and impaired properties			0	0				151,347
Results of operations of oil and gas producing activities			86	450	623	1,624		(161,291)
Total Company and Piceance Energy income from operations of oil and gas producing activities					$ 709	$ 2,074

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Property, Plant and Equipment (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Land	$ 39,800	$ 0
Buildings and equipment	65,878	0
Other	1,945	1,415
Property, plant and equipment	107,623	1,415
Proved oil and gas properties	4,949	4,804
Less: accumulated depreciation, depletion and amortization	(3,968)	(373)
Property and equipment, net	$ 108,604	$ 5,846

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Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Tables)

12 Months Ended

Dec. 31, 2013

Schedule Of Reorganization Items and Fresh Start Accounting

The following condensed consolidated balance sheet presents the implementation of the Plan and the adoption of fresh-start reporting as of the Effective Date. Reorganization adjustments have been recorded within the condensed consolidated balance sheet to reflect the effects of the Plan, including discharge of liabilities subject to compromise and the adoption of fresh-start reporting.

	August 31, 2012
	Predecessor			Plan of Reorganization Adjustments			Fresh Start Reporting Adjustments			Successor
	(in thousands)
ASSETS
Current assets
Cash and cash equivalents	$	1,954		$	74,167	(a)	$			$	4,882
					(45,035	)(c)
					(24,204	)(d)
					(2,000	)(e)
Trust assets		—			3,446	(e)					3,446
Restricted cash		—			20,359	(d)					20,359
Trade accounts receivable, net		3,708			(1,727	)(a)		(1,981	)(g)		—
Prepaid assets		4,777						(4,777	)(g)		—
Prepaid reorganization costs		1,326						(1,326	)(g)		—
Total current assets		11,765									28,687
Property and equipment
Oil and gas properties
Unproved		84						(84	)(g)		—
Proved		759,755			(740,392	)(a)		(14,776	)(g)		4,587
Land		4,000			(4,000	)(a)					—
Other		73,021			(47,493	)(a)		(21,289	)(g)		4,239
Total property and equipment		836,860									8,826
Less accumulated depreciation and depletion		(642,172	)		607,603	(a)		34,569	(g)		—
Property and equipment, net		194,688									8,826
Long-term assets:
Investments in unconsolidated affiliates		3,629			105,344	(a)		(3,629	)(g)		105,344
Other long-term assets		307						(253	)(g)		54
Total long-term assets		3,936									105,398
Total assets	$	210,389								$	142,911
LIABILITIES AND EQUITY
Current liabilities
Liabilities not subject to compromise
Debtor in possession financing	$	56,535			(56,535	)(c)				$	—
Accounts payable and other accrued liabilities		4,897									4,897
Other accrued liabilities		9,224			(2,685	)(b)					2,640
					(1,500	)(c)
					(3,845	)(d)
					1,446	(e)
Accrued reorganization and trustee expense		70,656									7,537
Liabilities subject to compromise
3 3⁄4% Senior notes		115,000			(115,000	)(b)					—
7% Senior convertible notes		150,000			(150,000	)(b)					—
Accounts payable and other accrued liabilities		17,203			(2,560	)(a)		(1,981	)(g)		12,336
					(3,526	)(d)		3,200	(g)
Total current liabilities		352,859									19,873
Long-term liabilities
Liabilities not subject to compromise
Long - term debt		—			6,335	(c)					6,335
Derivative liabilities		—			6,665	(c)					6,665
Asset retirement obligations		4,414			(3,938	)(a)					476
Total liabilities		357,273									33,349
Stockholders’ equity
Common stock		288			1,457	(b)		(288	)(f)		1,477
					20	(d)
Additional paid-in capital		1,643,285			100,084	(b)		288	(f)		108,085
					1,318	(d)		(1,636,890	)(h)
Retained earnings (accumulated deficit)		(1,790,457	)		166,144	(b)		(14,765	)(g)		—
					2,188	(d)		1,636,890	(h)
Total stockholders’ equity (deficit)		(146,884	)								109,562
Total liabilities and equity (deficit)	$	210,389								$	142,911

Notes to Plan of Reorganization and Fresh Start Accounting Adjustments

(a) Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.

(b) Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(c) Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.

(d) Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(e) Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).

(f) Reflects the cancellation of Predecessor common stock.

(g) Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(h) Reflects the elimination of Predecessor’s accumulated deficit.

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Overview

12 Months Ended

Dec. 31, 2013

Overview

Note 1 - Overview

We are a diversified energy holding company based in Houston, Texas (OTCQB:PARR). We were created through the successful reorganization of Delta Petroleum in August 2012. The reorganization converted approximately $265 million of unsecured debt to equity and allowed us to preserve significant tax attributes. Currently, we operate in three segments: (i) refining, distribution and marketing, (ii) natural gas and oil operations and (iii) commodity marketing and logistics operations.

Our refining, distribution and marketing segment consists of a refinery in Kapolei, Hawaii. The refinery produces ultra-low sulfur diesel, gasoline, jet fuel, marine fuel and other associated refined products primarily for consumption in Hawaii. Our refinery logistics assets include refined products terminals, pipelines, a single point mooring and other associated logistics assets. In addition, we distribute products though 31 branded retail outlets located across the islands of Oahu, Maui and Hawaii. The refining, distribution and marketing segment was established through the acquisition of Hawaii Independent Energy, LLC (“HIE”) (formerly known as Tesoro Hawaii, LLC (“Tesoro Hawaii”)) in September 2013 for approximately $75 million in cash, plus net working capital and inventories and certain contingent earn out payments of up to approximately $40 million (the “HIE Acquisition”). As part of the purchase price, we also funded $24.3 million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing.

Our natural gas and oil operations consist primarily of a 33.34% interest in Piceance Energy, LLC (“Piceance Energy”) (Note 3 - Investment in Piceance Energy). Piceance Energy is a joint venture with Laramie Energy II, LLC (“Laramie”), who owns the remaining interest and manages the day to day operations of the joint venture. Laramie is a Denver-based company primarily focused on finding and developing natural gas reserves from unconventional gas reservoirs within the Rocky Mountain region. Piceance Energy was formed and capitalized in August 2012 when we and Laramie Energy contributed oil and natural gas assets, surface real estate, and other related assets located in the Piceance Basin geological province of Colorado to the joint venture entity.

Our commodity marketing and logistics segment focuses on sourcing, marketing, transportation and distribution of crude oil and refined products. Our logistics capability consists of historical pipeline shipping status, a rail car fleet, and expertise in contracted chartering of tows and barges, with the capability of moving crude oil from land-locked locations in the Western U.S. and Canada to the refining hubs in the Midwest, the Gulf Coast, and the East Coast regions of the U.S. The commodity marketing and logistics operations segment was established through the acquisition of Texadian Energy, Inc. (“Texadian”) (formerly known as SEACOR Energy, Inc.) in December 2012 for approximately $14 million in cash, plus approximately $3 million in working capital.

As a result of these transactions, our results of operations for any period after December 31, 2013 will not be comparable to any prior period.

On January 23, 2014, we amended and restated our certificate of incorporation to implement a one-for-ten (1:10) reverse stock split of our issued and outstanding common stock, par value $0.01 per share. All references in the financial statements to the number of shares of common stock or warrants, price per share and weighted average number of common stock outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor (see Note 20 - Subsequent Events).

To generate earnings and cash flows from operations, the Company’s refining, distribution and marketing segment is primarily dependent upon processing crude oil and selling refined petroleum products at margins sufficient to cover fixed and variable costs and other expenses. Crude oil and refined petroleum products are commodities and factors largely out of the Company’s control can cause prices to vary over time.

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Asset Retirement Obligations (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012 Predecessor [Member]
Asset Retirement Obligations [Line Items]
Asset retirement obligation - beginning of period	$ 476	$ 512	$ 3,799
Obligation acquired	0	2,601	0
Accretion expense	36	59	178
Change in estimate	0	0	437
Settlement upon transfer to Piceance Energy	0	0	(3,938)
Asset retirement obligation - end of period	$ 512	$ 3,172	$ 476

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Stockholders' Equity (Tables)

12 Months Ended

Dec. 31, 2013

Schedule Of Equity Incentive Plan Disclosures

For the year ended December 31, 2013, the following activity occurred under our Incentive Plan (in thousands, except per share amounts):

	Shares			Weighted- Average Grant Date Fair Value
Non vested balance, beginning of period		219		$	12.00
Granted		356			18.32
Vested		(51	)		12.00
Forfeited		—			—
Non vested balance, end of period		524		$	16.29
Available for grant		1,025

Schedule of Share-based Compensation, Stock Options, Activity

A summary of the stock option activity under the Predecessor’s various plans and related information for the period from January 1 through August 31, 2012 follows:

	Period from January 1 through August 31, 2012
	Options			Weighted-Average Exercise Price			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic Value
Outstanding-beginning of year		150,300		$	75.00
Granted		—			—
Exercised		—			—
Expired / canceled		(150,300	)		(75.00	)
Outstanding-end of year		—		$	—			—	$	—
Exercisable-end of year		—		$	—			—	$	—

Schedule of Nonvested Share Activity

A summary of the restricted stock (nonvested stock) activity under the Predecessor’s plan and related information for the period from January 1 through August 31, 2012 follows (in thousands, except share and per share amounts):

	Period from January 1 through August 31, 2012
	Nonvested Stock			Weighted-Average Grant-Date Fair Value			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic Value
Nonvested-beginning of year		558,301		$	7.45
Granted		—			—
Vested		—			—
Expired / canceled		(558,301	)		(7.45	)
Nonvested-end of year		—		$	—			—	$	—

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Disclosures About Capitalized Costs, Costs Incurred (Unaudited)

12 Months Ended

Dec. 31, 2013

Disclosures About Capitalized Costs, Costs Incurred (Unaudited)

Note 21 - Disclosures About Capitalized Costs, Costs Incurred (Unaudited)

Capitalized costs related to oil and gas activities are as follows (in thousands):

	Successor						Predecessor
	December 31, 2013			December 31, 2012			August 31, 2012
Company:
Unproved properties	$	—		$	—		$	84
Proved properties		4,949			4,804			759,755
		4,949			4,804			759,839
Accumulated depreciation and depletion		(1,868	)		(337	)		(642,172	)
	$	3,081		$	4,467		$	117,667
Company’s Share of Piceance Energy:
Unproved properties	$	15,763		$	16,180
Proved properties		168,378			134,638
		184,141			150,818
Accumulated depreciation and depletion		(38,452	)		(2,808	)
	$	145,689		$	148,010

(1) The capitalized cost amounts presented are as of August 31, 2012 for the Predecessor and exclude adjustments resulting from the plan or reorganization and fresh-start reporting (see Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan).

Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Company:
Development costs incurred on proved undeveloped reserves	$	—	$	—	$	1,613
Development costs - other		142		—		—
Total	$	142	$	—	$	1,613
Company’s Share of Piceance Energy:
Unproved properties acquisition costs	$	—	$	206
Proved properties acquisition costs(1)		—		32,519
Development costs - other		6,380		291
Total	$	6,380	$	33,016

(1) Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.

At December 31, 2011, the company had $8,770 of suspended exploratory well cost subject to evaluation. Upon the emergency from Bankruptcy on August 31, 2012 all capitalized oil and natural gas property costs, including suspended exploratory well cost, were transferred to Piceance in exchange for cash and a 33.34% equity interest in Piceance. For the period from September 1, 2012 through December 31, 2012 and for the year ended December 31, 2013 neither the company or Piceance incurred exploratory well costs so no amounts were capitalized or expensed during these respective periods. Accordingly, there were no suspended exploratory well costs at December 31, 2012 and 2013 that were being evaluated.

A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows:

	Successor				Predecessor
	Year Ended December 31, 2013		September 1 through December 31, 2012		January 1 through August 31, 2012
Company:
Revenue:
Oil and gas revenues	$	7,739	$	2,144	$	23,079
Expenses:
Production costs		5,696		1,688		16,980
Depletion and amortization		1,593		370		16,041
Exploration		—		—		2
Abandoned and impaired properties		—		—		151,347
Results of operations of oil and gas producing activities	$	450	$	86	$	(161,291	)
Company’s share of Piceance Energy:
Revenue:
Oil and gas revenues	$	20,364	$	6,464
Expenses:
Production costs		9,885		3,033
Depletion and amortization		8,855		2,808
Results of operations of oil and gas producing activities	$	1,624	$	623
Total Company and Piceance Energy income from operations of oil and gas producing activities	$	2,074	$	709

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Subsequent Events

12 Months Ended

Dec. 31, 2013

Subsequent Events

Note 20 - Subsequent Events

On the January 23, 2014 and in connection with the consummation of the Reverse Stock Split as described in Note 1-Overview, we and certain of our subsidiaries entered into an Eleventh Amendment to our Loan Agreement pursuant to which the Lender consented to Fractional Share Cash Payments.

As a result of the Reverse Stock Split, every ten pre-split shares of Common Stock issued prior to January 29, 2014, the effective date of the reverse stock split for trading purposes, were exchanged for one post-split share of Common Stock, with fractional shares paid in cash at an amount equal to the product obtained by multiplying (a) the closing price of the Common Stock as reported on the OTCQB Marketplace on January 23, 2014, by (b) the fraction of one share owned by the stockholder. Further, the number of shares of Common Stock issued and outstanding was reduced from approximately 301,141,520 on January 23, 2014 to approximately 30,114,352. The number of authorized shares of Common Stock will remain at 500,000,000 and the par value of the Common Stock will remain at $0.01 per share. All references in the financial statements to the number of shares of common stock or warrants, price per share and weighted average number of common stock outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor.

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Weighted Average Potentially Dilutive Securities (Detail) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012 Stock Issuable upon Conversion of Convertible Notes [Member]	Dec. 31, 2013 Stock Issuable upon Conversion of Convertible Notes [Member]	Dec. 31, 2012 Stock Options and Warrants [Member]	Dec. 31, 2013 Stock Options and Warrants [Member]	Dec. 31, 2012 Non-Vested Restricted Stock [Member]	Dec. 31, 2013 Non-Vested Restricted Stock [Member]	Aug. 31, 2012 Predecessor [Member]	Aug. 31, 2012 Predecessor [Member] Stock Issuable upon Conversion of Convertible Notes [Member]	Aug. 31, 2012 Predecessor [Member] Stock Options and Warrants [Member]	Aug. 31, 2012 Predecessor [Member] Non-Vested Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total potentially dilutive securities	0	523	0	0	0	0	0	523	1,087	379	150	558

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Investment in Piceance Energy (Details) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Beginning balance		$ 104,434
Loss from unconsolidated affiliates		(2,941)
Ending balance		101,796
Piceance Energy [Member]
Schedule of Equity Method Investments [Line Items]
Beginning balance	105,344	104,434
Loss from unconsolidated affiliates	(1,325)	(3,516)
Accretion of basis difference	0	575
Capitalized drilling costs obligation paid	415	303
Ending balance	$ 104,434	$ 101,796

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Components of Income Tax Expense (Benefit)

Income tax expense (benefit) consisted of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Current:
U.S. - Federal	$	—		$	—		$	—
U.S. - State		(179	)		—			—
Deferred:
U.S. - Federal		(14	)		(2,757	)		—
U.S. - State		193			—			—
Total	$	—		$	(2,757	)	$	—

Schedule of Effective Income Tax Rate Reconciliation

Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate of 35% to pretax income as a result of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Federal statutory rate		(35.0	)%		(35.0	)%		(35.0	)%
State income taxes, net of federal benefit		0.1	%		—			—
Change in valuation allowance		23.1	%		(2.0	)%		(33.0	)
Professional fees related to bankruptcy reorganization		—			8.0	%		17.0	%
Revenue from Wapiti Trust settlement		—			5.0	%		—
Cancellation of debt tax attribute reduction		—			—			51.0	%
Permanent Items		3.7	%
Provision to return adjustments		8.1	%		—			—
Actual income tax rate		—	%		(24.0	)%		—	%

Schedule of Deferred Tax Assets and Liabilities

Deferred tax assets (liabilities) are comprised of the following at December 31, 2013 and 2012 (in thousands):

	2013			2012
Deferred tax assets:
Net operating loss	$	544,377		$	450,195
Capital loss carry forwards		26,141			26,141
Property and equipment		34,683			23,045
Investment in Piceance Energy		32,138			45,172
Derivative instruments		—			1,498
Accrued bonuses		—			—
Trust liability		1,327			—
Other		1,183			1,506
Total deferred tax assets		639,849			547,557
Valuation allowance		(637,464	)		(544,442	)
Net deferred tax assets	$	2,385		$	3,115
Deferred tax liabilities:
Property and equipment	$	5		$	—
Texadian Energy intangibles		2,380			3,083
Prepaid insurance, marketable securities and other		—			32
State liabilities		216			—
Total deferred tax liabilities	$	2,601		$	3,115
Total deferred tax liability, net	$	(216	)	$	—

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Information Regarding Proved Oil and Gas Reserves (Unaudited)

12 Months Ended

Dec. 31, 2013

Information Regarding Proved Oil and Gas Reserves (Unaudited)

Note 22 - Information Regarding Proved Oil and Gas Reserves (Unaudited)

There are numerous uncertainties inherent in estimating quantities of proved crude oil and natural gas reserves. Crude oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be precisely measured. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of crude oil and natural gas that are ultimately recovered.

Estimates of the company’s oil and natural gas reserves and present values as of December 31, 2013 and 2012, and August 31, 2012 were prepared by Netherland, Sewell & Associates, Inc., independent reserve engineers.

A summary of changes in estimated quantities of proved reserves for the year ended December 31, 2013 and for respective periods in 2012 is as follows:

	Gas (MMcf)			Oil (MBbl)			NGLS (MBb1)			Total (MMcfe)(5)
Company:
Estimated Proved Reserves: Balance at January 1, 2012 (Predecessor)(1)		87,209			494			—			90,173
Revisions of quantity estimate		—			85			—			512
Sale/disposition of properties(2)		(82,357	)		(235	)		—			(83,770	)
Production		(4,852	)		(67	)		—			(5,256	)
Estimated Proved Reserves: Balance at August 31, 2012 (Successor)		—			277			—			1,659
Revisions of quantity estimate		456			31			—			643
Production		(10	)		(22	)		—			(139	)
Estimated Proved Reserves: Balance at December 31, 2012 (Successor)		446			286			—			2,163
Revisions of quantity estimate		460			16			—			557
Extensions and discoveries		9			3			—			25
Production		(253	)		(69	)		—			(667	)
Estimated Proved Reserves: Balance at December 31, 2013 (Successor)		662			236			—			2,078
Company’s Share of Piceance Energy:
Estimated Proved Reserves: Balance at September 1, 2012		—			—			—			—
Transfer from investees(3)		83,915			560			4,228			112,639
Revisions of quantity estimate		8,053			41			387			10,621
Extensions and discoveries		32,073			236			1,778			44,151
Production		(1,391	)		(6	)		(48	)		(1,711	)
Estimated Proved Reserves: Balance at December 31, 2012		122,650			831			6,345			165,700
Revisions of quantity estimate		72,436			174			2,818			90,387
Extensions and discoveries		3,599			(374	)		(1,334	)		(6,643	)
Production		(12,088	)		(47	)		(428	)		(14,935	)
Estimated Proved Reserves: Balance at December 31, 2013		186,597			584			7,401			234,509
Total Estimated Proved Reserves: Balance at December 31, 2013		187,259			820			7,401			236,587
Proved developed reserves
December 31, 2012		158			286			—			1,875
December 31, 2012 - Company Share of Piceance Energy		48,680			237			2,253			63,617
Total December 31, 2012		48,838			523			2,253			65,492
Proved undeveloped reserves
December 31, 2012		288			—			—			288
December 31, 2012 - Company Share of Piceance Energy		73,970			594			4,092			102,083
Total December 31, 2012		74,258			594			4,092			102,371
Proved developed reserves
December 31, 2013		662			236			—			2,078
December 31, 2013 - Company Share of Piceance Energy		45,072			165			1,627			55,829
Total December 31, 2013		45,734			401			1,627			57,907
Proved undeveloped reserves
December 31, 2013		—			—			—			—
December 31, 2013 - Company Share of Piceance Energy		141,525			419			5,774			178,680
Total December 31, 2013		141,525			419			5,774			178,680

	CIG per Mbtu		WTI per Bbl
Base pricing, before adjustments for contractual differentials:(4)
August 31, 2012	$	2.75	$	90.85
December 31, 2012	$	2.56	$	91.21
December 31, 2012 - Piceance	$	2.56	$	91.21
December 31, 2013	$	3.53	$	96.91
December 31, 2013 - Piceance	$	3.53	$	96.91

⁽¹⁾  At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.

⁽²⁾  On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).

⁽³⁾  On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).

⁽⁴⁾  Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.

⁽⁵⁾  MMcfe is based on a ratio of 6 Mcf to 1 barrel.

Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests.

	Successor						Predecessor
	December 31,						August 31,
	2013			2012			2012
	(in thousands)						(in thousands)
Company:
Future net cash flows	$	26,861		$	30,444		$	28,691
Future costs:
Production		21,999			20,596			19,973
Development and abandonment		319			319			319
Income taxes1		—			—			—
Future net cash flows		4,543			9,529			8,399
10% discount factor		(1,006	)		(1,519	)		(1,176	)
Standardized measure of discounted future net cash flows	$	3,537		$	8,010		$	7,223
Company’s Share of Piceance Energy:
Future net cash flows	$	984,205		$	568,706
Future costs:
Production		430,506			199,277
Development and abandonment		234,905			154,054
Income taxes1		—			—
Future net cash flows		318,794			215,375
10% discount factor		(229,469	)		(143,416	)
Standardized measure of discounted future net cash flows	$	89,325		$	71,959
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues	$	92,862		$	79,969

¹  No income tax provision is included in the standardized measure calculation shown above as the company does not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.

The principal sources of changes in the standardized measure of discounted net cash flows for the year ended December 31, 2013 and for the respective periods during 2012 are as follows (in thousands):

	Successor
	December 31,			Company Share of Piceance Energy December 31,			Total
	2013			2013			2013
Beginning of the year
Beginning of the period	$	8,010		$	71,959		$	79,969
Sales of oil and gas production during the period, net of production costs		(2,044	)		(10,478	)		(12,522	)
Net change in prices and production costs		(3,833	)		(2,588	)		(6,421	)
Changes in estimated future development costs		—			8,831			8,831
Extensions, discoveries and improved recovery		147			15,471			15,618
Revisions of previous quantity estimates, estimated timing of development and other		395			(4,948	)		(4,553	)
Previously estimated development and abandonment costs incurred during the period		—			3,142			3,142
Other		61			740			801
Accretion of discount		801			7,196			7,997
End of period	$	3,537		$	89,325		$	92,862

	Successor									Predecessor
	Period from September 1, through December 31,			Company Share of Piceance Energy September 1, through December 31,			Total			January 1, through August 31,
	2012			2012			2012			2012
Beginning of the year										$	129,695
Beginning of the period	$	7,223		$	—		$	7,223			—
Transfer from investees		—			55,253			55,253			—
Sales of oil and gas production during the period, net of production costs		(456	)		(3,639	)		(4,095	)		(5,954	)
Net change in prices and production costs		(667	)		(139	)		(806	)		378
Changes in estimated future development costs		—			5			5			—
Extensions, discoveries and improved recovery		763			569			1,332			—
Revisions of previous quantity estimates, estimated timing of development and other		648			13,708			14,356			(7,439	)
Sales/disposition of reserves in place		—			—			—			(118,104	)
Other		258			4,360			4,618			—
Accretion of discount		241			1,842			2,083			8,647
End of period	$	8,010		$	71,959		$	79,969		$	7,223

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2013

Organization Consolidation And Presentation Of Financial Statements Disclosure, Policy

Principles of Consolidation and Basis of Presentation

The consolidated financial statements include the accounts of Par Petroleum Corporation and its consolidated subsidiaries. All inter-company balances and transactions have been eliminated in consolidation. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.

Our wholly-owned subsidiaries include Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”) which acquired all of the outstanding membership interests of HIE on September 25, 2013 (see Note 4 - Acquisitions and Dispositions), Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3 - Investment in Piceance Energy) and Texadian, which we acquired on December 31, 2012 (see Note 4 - Acquisitions and Dispositions). Certain amounts from prior periods have been reclassified to conform to the current presentation.

Use Of Estimates, Policy

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include fair value of assets and liabilities recorded in connection with the application of fresh-start reporting or acquisitions, natural gas and oil reserves, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, bad debts, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

Reorganization, Policy

Fresh-Start Reporting and the Effects of the Plan

Certain companies qualify for fresh-start reporting in connection with their emergence from bankruptcy. Fresh-start reporting is appropriate on the emergence from bankruptcy if the reorganization value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims, and if the holders of existing voting shares immediately before confirmation receive less than 50 percent of the voting shares of the emerging entity. We met these requirements on August 31, 2012 and adopted fresh-start reporting resulting in the creation of a new reporting entity.

The bankruptcy court issued a confirmation order approving our plan of reorganization (the “Plan”) on August 15, 2012 and we met the requirements of the Plan on August 31, 2012. Under the requirements of fresh-start reporting, we have adjusted our assets and liabilities to their estimated fair values as of August 31, 2012 in conformity with the guidance for the acquisition method of accounting for business combinations. The net effect of all fresh-start adjustments, including the effects of implementing the plan, resulted in a gain of approximately $154 million, which is reflected in the 2012 Predecessor Period. The application of the fresh-start reporting provisions created a new reporting entity having no retained earnings nor accumulated deficit.

Our fresh-start adjustments consisted primarily of (i) estimates of the fair value of our minority interest in Piceance Energy and (ii) of the fair value of our remaining existing fixed assets and liabilities. A description of the adjustments and amounts is provided in Note 19 - Reorganization under Chapter 11, Fresh-Start Reporting and the Effects of the Plan.

Cash And Cash Equivalents, Policy

Cash and Cash Equivalents

Cash and cash equivalents consist of demand deposits and funds invested in highly liquid short-term investments with original maturities of three months or less.

Cash And Cash Equivalents Restricted Cash And Cash Equivalents, Policy

Restricted Cash

Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to bankruptcy matters and cash held at commercial banks to support letter of credit facilities.

Receivables Trade And Other Accounts Receivable Allowance For Doubtful Accounts, Policy

Allowance for Doubtful Accounts

We establish provisions for losses on trade receivables if it becomes probable we will not collect all or part of the outstanding balances. We review collectability and establish or adjust our allowance as necessary using the specific identification method. As of December 31, 2013 and 2012, we had no significant allowance for doubtful accounts.

Refined Product Exchanges Policy

Refined Product Exchanges

We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.

Inventory, Policy

Inventories

Commodity inventories are stated at the lower of cost or market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 9 - Supply and Exchange Agreements. The crude oil remains in the legal title of Barclays and is stored in HIE’s storage tanks governed by a storage agreement. Legal title to the crude oil passes to HIE at the tank outlet. After processing, Barclays takes title to the refined products when the refined products enter the tanks which are then stored in HIE’s storage tanks until sold to HIE’s retail locations or to third parties. We record the inventory owned by Barclays on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties.

Investments In Unconsolidated Entities, Policy

Investment in Unconsolidated Affiliate

We account for our investment in unconsolidated affiliate using the equity method as we have the ability to exert significant influence, but do not control the operating and financial policies. Our proportionate share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations. Investment in unconsolidated affiliate is reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

At December 31, 2013 and 2012, our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3 - Investment in Piceance Energy.)

Property Plant And Equipment, Policy

Property, Plant and Equipment (Other than Natural Gas and Oil Properties)

We capitalize the cost of additions, major improvements and modifications to property, plant and equipment. The cost of repairs and normal maintenance of property, plant and equipment is expensed as incurred. Major improvements and modifications of property, plant and equipment are those expenditures that either extend the useful life, increase the capacity or improve the operating efficiency of the asset, or improve the safety of our operations. We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of each asset as follows:

Assets	Lives in Years
Refining	8 to 47
Logistic	3 to 30
Retail	14 to 18
Corporate	3 to 7
Software	3

We record property under capital leases at the lower of the present value of minimum lease payments using our incremental borrowing rate or the fair value of the leased property at the date of lease inception. We depreciate leasehold improvements and property acquired under capital leases over the shorter of the lease term or the economic life of the asset.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.

Oil and Gas Properties Policy

Natural Gas and Oil Properties

We account for our natural gas and oil exploration and development activities using the successful efforts method of accounting. Under such method, costs of productive exploratory wells, development dry holes and productive wells and undeveloped leases are capitalized. Natural gas and oil lease acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological or geophysical expenses and delay rentals for natural gas and oil leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, then evaluated quarterly and charged to expense if and when the well is determined not to have found reserves in commercial quantities. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of producing properties.

Unproved properties with significant acquisition costs are assessed quarterly on a property-by-property basis and any impairment in value is charged to expense. If the unproved properties are determined to be productive, the related costs are transferred to proved oil and natural gas properties and are depleted. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain or loss until all costs have been recovered.

Depreciation, depletion and amortization of capitalized acquisition, exploration and development costs is computed using the units-of-production method by individual fields (common reservoirs) using proved producing natural gas and oil reserves as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based on total proved natural gas and oil reserves as the related reserves are produced.

Our natural gas and oil assets are reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

Goodwill And Intangible Assets, Policy

Goodwill and Other Intangible Assets

Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a two-step quantitative test is required. If required, we will review the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment indicator exists and an estimate of the impairment loss is calculated.

Our intangible assets include relationships with suppliers and shippers, favorable railcar leases, trade names and trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist. When we believe impairment indicators may exist, projections of the undiscounted future cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values.

Asset Retirement Obligations, Policy

Asset Retirement Obligations

We record asset retirement obligations (“AROs”) in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the liability. Our AROs arise from our refining, distribution and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and oil operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in depreciation, depletion and amortization expense on our consolidated statement of operations and the related capitalized cost is depreciated over the asset’s useful life. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments in our statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives.

We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos), and removal or dismantlement requirements associated with the closure of our refining facility, terminal facilities or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines or other equipment.

Environmental Costs, Policy

Environmental Matters

We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and environmental expenses are recorded in operating expenses in our consolidated statements of operations.

Derivatives, Policy

Derivatives and Other Financial instruments

We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange traded futures contracts, collar agreements, swaps or options. The purpose of the transactions is to provide a measure of stability to our cash flows in an environment of volatile commodity prices.

Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle. Should we not designate a contract as a normal purchase or normal sale then the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. As of December 31, 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.

In addition, from time to time we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.

As a part of the Plan of Reorganization, we issued warrants (see Note 10 - Debt) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in change in value of common stock warrants and loss on derivative instruments, net respectively, on our consolidated statement of operations.

Settlements, Policy

Accrued Settlement Claims

We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy (See Note 13 - Commitments and Contingencies). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.

Income Tax, Policy

Income Taxes

We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard, and to the extent this threshold is not met, a valuation allowance is recorded.

We recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2010, 2011, and 2012. However, since we have net operating loss carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.

Share Based Compensation Option And Incentive Plans, Policy

Stock Based Compensation

We recognize the cost of share-based payments over the period the employee provides service, generally the vesting period, and include such costs in general and administrative expense in the consolidated statements of operations. The fair value of equity instruments issued to employees is measured on the grant date and recognized over the service period on a straight-line basis.

Revenue Recognition, Policy

Revenue Recognition

We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met. These transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.

Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2013 and 2012, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of rail cars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the purchaser, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.

Refining, Distribution and Marketing. We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title and risk of loss is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We include transportation fees charged to customers in revenues in our statements of consolidated operations, while the related transportation costs are included in cost of sales. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.

Earnings Per Share, Policy

Loss Per Share

Basic loss per share (“EPS”) is computed by dividing net loss by the sum of the weighted average number of common shares outstanding, and the weighted average number of shares issuable under the Warrants (see Note 16 - Loss Per Share). The Warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation of basic EPS as these shares are not considered earned until vesting occurs.

Foreign Currency Transactions And Translations, Policy

Foreign Currency Transactions

We may, on occasion, enter into transactions denominated in currencies other than our functional currency (“U.S. $”). Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in other income (expense) in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.

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Introductory Note

12 Months Ended

Dec. 31, 2013

Introductory Note

Introductory Note

These consolidated financial statements reflect the restatement of our previously issued financial statements included in our Annual Report on Form 10-K and Amendment No. 1 on Form 10-K/A for the period ended December 31, 2013. The restatement relates to an $8.6 million understatement of cost of revenues and net loss ($0.44 per common share). The restatement had no impact on net cash flow used in operations.

We determine our inventory balance and our obligations under supply and exchange agreements based on physical inventory observations each reporting period. During May 2014, we determined that we did not appropriately consider an adjustment to the measurements taken during the physical inventory observation that occurred on December 31, 2013. This overstatement of inventory volumes also impacted our monthly settlement under our supply and exchange agreements, resulting in a decrease to our trade receivables. The increase in net loss had no impact on income tax expense due to the valuation allowance on our deferred tax assets.

The table below summarizes the effects of the error on our consolidated financial statements (in thousands):

	As Previously Reported			Adjustment			As Restated
Consolidated Balance Sheet
Trade accounts receivable	$	122,913		$	(5,420	)	$	117,493
Inventories		389,075			(8,452	)		380,623
Total current assets		558,373			(13,872	)		544,501
Total assets		827,085			(13,872	)		813,213
Obligations under supply and exchange agreements		390,839			(5,320	)		385,519
Total current liabilities		458,708			(5,320	)		453,388
Total liabilities		590,269			(5,320	)		584,949
Accumulated deficit		(79,460	)		(8,552	)		(88,012	)
Total stockholders’ equity		236,816			(8,552	)		228,264
Total liabilities and stockholders’ equity	$	827,085		$	(13,872	)	$	813,213
Consolidated Statement of Operations
Cost of revenues	$	848,924		$	8,552		$	857,476
Total operating expenses		925,327			8,552			933,879
Operating loss		(39,313	)		(8,552	)		(47,865	)
Loss before income taxes and reorganization items		(70,621	)		(8,552	)		(79,173	)
Loss before reorganization items		(70,621	)		(8,552	)		(79,173	)
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Basic loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Diluted loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Consolidated Statement of Cash Flows
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Net changes in operating assets and liabilities:
Trade accounts receivable		(45,698	)		5,420			(40,278	)
Inventories		40,141			8,452			48,593
Supply and exchange agreements	$	(13,061	)	$	(5,320	)	$	(18,381	)

Please note that these financial statements and the notes thereto do not reflect events occurring after March 31, 2014 (the date of the original Form 10-K). For a description of these events, please read our Exchange Act reports filed since March 31, 2014, including our Current Reports on Form 8-K and any amendments thereto.

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Introductory Note (Tables)

12 Months Ended

Dec. 31, 2013

Summary of Effects of Error on Consolidated Financial Statements

The table below summarizes the effects of the error on our consolidated financial statements (in thousands):

	As Previously Reported			Adjustment			As Restated
Consolidated Balance Sheet
Trade accounts receivable	$	122,913		$	(5,420	)	$	117,493
Inventories		389,075			(8,452	)		380,623
Total current assets		558,373			(13,872	)		544,501
Total assets		827,085			(13,872	)		813,213
Obligations under supply and exchange agreements		390,839			(5,320	)		385,519
Total current liabilities		458,708			(5,320	)		453,388
Total liabilities		590,269			(5,320	)		584,949
Accumulated deficit		(79,460	)		(8,552	)		(88,012	)
Total stockholders’ equity		236,816			(8,552	)		228,264
Total liabilities and stockholders’ equity	$	827,085		$	(13,872	)	$	813,213
Consolidated Statement of Operations
Cost of revenues	$	848,924		$	8,552		$	857,476
Total operating expenses		925,327			8,552			933,879
Operating loss		(39,313	)		(8,552	)		(47,865	)
Loss before income taxes and reorganization items		(70,621	)		(8,552	)		(79,173	)
Loss before reorganization items		(70,621	)		(8,552	)		(79,173	)
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Basic loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Diluted loss per common share	$	(3.57	)	$	(0.44	)	$	(4.01	)
Consolidated Statement of Cash Flows
Net loss	$	(70,621	)	$	(8,552	)	$	(79,173	)
Net changes in operating assets and liabilities:
Trade accounts receivable		(45,698	)		5,420			(40,278	)
Inventories		40,141			8,452			48,593
Supply and exchange agreements	$	(13,061	)	$	(5,320	)	$	(18,381	)

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Fair Value Measurements (Details 6) (Detail) (Fair Value, Measurements, Recurring [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Liabilities
Derivative Fair Value Of Derivative Liability	$ (29,316)	$ (11,252)
Contingent consideration liability [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	(11,980)
Commodity Contract [Member] | Exchange Traded Futures [Member]
Assets
Commodities - exchange traded futures		542
Commodity Contract [Member] | Physical Forward Contracts [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		(307)
Warrant [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	(17,336)	(10,900)
Debt Prepayment Derivative [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		(45)
Fair Value Inputs Level 1 [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 1 [Member] | Contingent consideration liability [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0
Fair Value Inputs Level 1 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]
Assets
Commodities - exchange traded futures		542
Fair Value Inputs Level 1 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		0
Fair Value Inputs Level 1 [Member] | Warrant [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 1 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		0
Fair Value Inputs Level 2 [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0	(307)
Fair Value Inputs Level 2 [Member] | Contingent consideration liability [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0
Fair Value Inputs Level 2 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]
Assets
Commodities - exchange traded futures		0
Fair Value Inputs Level 2 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		(307)
Fair Value Inputs Level 2 [Member] | Warrant [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 2 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		0
Fair Value Inputs Level 3 [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	(29,316)	(10,945)
Fair Value Inputs Level 3 [Member] | Contingent consideration liability [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	(11,980)
Fair Value Inputs Level 3 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]
Assets
Commodities - exchange traded futures		0
Fair Value Inputs Level 3 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		0
Fair Value Inputs Level 3 [Member] | Warrant [Member]
Liabilities
Derivative Fair Value Of Derivative Liability	(17,336)	(10,900)
Fair Value Inputs Level 3 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Derivative Fair Value Of Derivative Liability		$ (45)

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Information Regarding Proved Oil and Gas Reserves (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended		12 Months Ended		4 Months Ended		12 Months Ended		8 Months Ended
	Dec. 31, 2012 Company [Member]		Dec. 31, 2013 Company [Member]		Dec. 31, 2012 Company's Share of Piceance Energy [Member]		Dec. 31, 2013 Company's Share of Piceance Energy [Member]		Aug. 31, 2012 Predecessor [Member] Company [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future net cash flows	$ 30,444		$ 26,861		$ 568,706		$ 984,205		$ 28,691
Future costs: Production	20,596		21,999		199,277		430,506		19,973
Future costs: Development and abandonment	319		319		154,054		234,905		319
Income taxes	0	[1]	0	[1]	0	[1]	0	[1]	0	[1]
Future net cash flows	9,529		4,543		215,375		318,794		8,399
10% discount factor	(1,519)		(1,006)		(143,416)		(229,469)		(1,176)
Standardized measure of discounted future net cash flows	8,010		3,537		71,959		89,325		7,223
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues					$ 79,969		$ 92,862

[1] No income tax provision is included in the standardized measure calculation shown above as the company does not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.

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Debt (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Debt

Our debt is as follows (in thousands):

	December 31,
	2013			2012
Tranche B Loan	$	19,480		$	35,000
Delayed Draw Term Loan Agreement		—			13,465
ABL Facility		51,800			—
Retail Credit Agreement		26,000			—
Less: unamortized debt discount - warrants		—			(6,014	)
Less: unamortized debt discount - embedded derivative		—			(60	)
Total debt, net of unamortized debt discount		97,280			42,391
Less: current maturities		(3,250	)		(35,000	)
Long-term debt, net of current maturities and unamortized discount	$	94,030		$	7,391

Contractual Obligation, Fiscal Year Maturity Schedule

Annual maturities of our long-term debt are due during the following years (in thousands):

Year	Amount Due
2014	$	3,250
2015		2,600
2016		22,080
2017		54,400
2018		2,600
Thereafter		12,350
	$	97,280

Schedule of Maximum Leverage Ratio

Such covenants require HIE Retail to maintain a maximum Leverage Ratio (as defined in the Retail Credit Agreement) as follows:

Period (during and as of the last day of)	Maximum Leverage Ratio
2013 Fiscal Year	5.75 to 1.00
2014 Fiscal Year	5.50 to 1.00
2015 Fiscal Year	5.25 to 1.00
2016 Fiscal Year	5.00 to 1.00
2017 Fiscal Year, and at all times thereafter	4.75 to 1.00

Schedule Of Applicable Margin For Debt Instrument

The Applicable Margin for each fiscal quarter is the applicable rate per annum set forth below, such amount to be determined as of the last day of the immediately preceding fiscal quarter.

Level	Leverage Ratio	Applicable Margin for LIBOR Loans			Applicable Margin for Base Rate Loans
1	<4.00x		2	%		0	%
2	4.00x-5.00x		2.25	%		.25	%
3	>5.00x		2.5	%		.50	%

Schedule Of Revolver Applicable Margin for Debt Instrument

The Revolver Applicable Margin and the Unused Fee, for each quarter is determined, on the last date of the immediately preceding fiscal quarter:

Level	Leverage Ratio	Unused Fee			Revolver Applicable Margin for LIBOR Loans			Revolver Applicable Margin for Base Rate Loans
1	<4.00x		.25	%		1.75	%		-.25	%
2	4.00x-5.00x		.375	%		2.00	%		0	%
3	>5.00x		.50	%		2.25	%		.25	%

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Summary of Significant Accounting Policies (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012 Predecessor [Member]	Dec. 31, 2012 Predecessor [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Income Tax Expense Benefit	$ (2,757,000)	$ 0	$ 0	$ 154,000,000
Allowance for Doubtful Accounts Receivable	$ 0	$ 0

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Debt (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended			12 Months Ended		12 Months Ended		4 Months Ended	12 Months Ended	8 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013 ABL Facility [Member]	Dec. 27, 2012 Financial Standby Letter Of Credit [Member]	Dec. 31, 2013 ABL Revolving Credit Facility [Member]	Sep. 25, 2013 ABL Revolving Credit Facility [Member]	Dec. 31, 2013 Texadian Uncommitted Credit Agreement [Member]	Dec. 27, 2012 Letter Of Credit Facility [Member]	Dec. 31, 2013 Warrant Issuance Agreement [Member]	Dec. 31, 2013 Warrant Issuance Agreement [Member]	Aug. 31, 2012 Delayed Draw Term Loan Agreement [Member]	Dec. 31, 2013 Delayed Draw Term Loan Agreement [Member]	Oct. 31, 2013 Delayed Draw Term Loan Agreement [Member] Tranche B Loan [Member]	Dec. 31, 2013 Delayed Draw Term Loan Agreement [Member] Tranche B Loan [Member]	Dec. 31, 2013 HIE Retail [Member] Term Loan [Member] Retail Credit Agreement [Member]	Dec. 31, 2013 HIE Retail [Member] Revolving Credit Facility [Member] Retail Credit Agreement [Member]
Debt Disclosure [Line Items]
Proceeds From Lines Of Credit	$ 35,000,000	$ 159,800,000									$ 13,000,000	$ 30,000,000		$ 65,000,000	$ 26,000,000
Interest rate under credit facility													9.75%	14.75%
Debt Instrument, Face Amount												17,000,000
Extinguishment of Debt, Amount												6,100,000
Interest rate after an event of default														2.50%
Debt instrument principal prepayment amount														100,000
Line credit maximum borrowing amount					125,000,000		50,000,000	30,000,000							30,000,000	5,000,000
Line of Credit Facility, Capacity Available for Specific Purpose Other than for Trade Purchases					50,000,000
Line Of Credit Facility Amount Outstanding						15,000,000
Total capacity at period end					83,300,000
Debt Instrument, Interest Rate Terms					Outstanding balances on the ABL Facility bear interest at the base rate specified below ("Base Rate") plus a margin (based on a sliding scale of 1.00% to 1.50% depending on the borrowing base usage) or the adjusted LIBO rate specified below ("LIBO Rate") plus a margin (based on a sliding scale of 2.00% to 2.50% depending on the borrowing base usage). The margin was 1.25% for Base Rate loans and 2.25% for LIBO Rate loans during 2013. The Base Rate is equal to the highest of (i) the prime lending rate of the ABL Agent, (ii) the Federal Funds Rate plus 0.5% per annum, and (iii) the LIBO Rate for a LIBO Rate loan denominated in dollars with a one-month interest period commencing on such day plus 1.00%.
Debt, Weighted Average Interest Rate			3.13%
Debt Instrument, Fee					The ABL Borrowers agreed to pay commitment fees for the ABL Facility equal to 0.375% if the borrowing base usage is greater than 50% and 0.500% if the borrowing base usage is less than or equal to 50%. Outstanding letters of credit will be charged a participation fee at a per annum rate equal to the margin applicable to LIBO Rate loans, a facing fee and customary administrative fees.
Debt Instrument, Covenant Description					The ABL Facility requires HIE and its subsidiaries and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting its business and operations, including compliance by HIE in certain circumstances with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization ("EBITDA"), as adjusted, to total fixed charges of 1.0 to 1.0.
Advances To Be Received Upon Compliance Of Requirements															4,000,000
Fixed Charge Coverage Ratio To Be Maintained															1.15:1.00
Line of Credit Facility, Interest Rate Description															The Term Loan will bear interest, at HIE Retail's election, at a rate equal to (i) 30, 90 and 180 day LIBOR plus the Applicable Margin (as specified below) for LIBOR Loans (as defined in the Retail Credit Agreement), or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Applicable Margin.	Advances under the Revolver will bear interest, at HIE Retail's election, at a rate equal to (a) 30, 90 and 180 day LIBOR plus the Revolver Applicable Margin (as defined below) for LIBOR Loans, or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Revolver Applicable Margin.
Effective interest rate															2.50%
Excess Cash Flow Recapture Description															Fifty percent of annual Excess Cash Flow (as defined in the Retail Credit Agreement) will be applied to the outstanding principal balance of the Term Loan beginning with Excess Cash Flow for fiscal year 2014 to the extent the leverage ratio is equal to or greater than 4.50:1.00.
Line of Credit Facility, Commitment Fee Percentage																2.00%
Letters Of Credit Outstanding Amount				11,700,000			41,600,000
Line of Credit Facility, Collateral							Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian's assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian.
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted									14,859	959,213
Common stock warrant exercise price									0.10	0.10
Common stock warrant expiration period									Aug. 31, 2022	Aug. 31, 2022
Stock Issued To Settle Bankruptcy Claims										228,735
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Exercised										183,389
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Beginning Balance									790,683	790,683
Fair value of warrant on grant date										$ 6,600,000

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Current assets
Cash and cash equivalents	$ 38,061	$ 6,185
Restricted cash	802	23,970
Trade accounts receivable	117,493	17,730
Inventories	380,623	10,466
Prepaid and other current assets	7,522	1,575
Total current assets	544,501	59,926
Property and equipment
Property, plant and equipment	107,623	1,415
Proved oil and gas properties, at cost, successful efforts method of accounting	4,949	4,804
Total property and equipment	112,572	6,219
Less accumulated depreciation, depletion and amortization	(3,968)	(373)
Property and equipment, net	108,604	5,846
Long-term assets
Investments in unconsolidated affiliate	101,796	104,434
Intangible assets, net	11,170	8,809
Goodwill	20,603	7,756
Assets held for sale	0	2,800
Other long-term assets	26,539	11
Total assets	813,213	189,582
Current liabilities
Current maturities of long-term debt	3,250	35,000
Obligations under supply and exchange agreements	385,519	0
Accounts payable	28,870	25,329
Other accrued liabilities	31,956	981
Accrued settlement claims	3,793	8,667
Total current liabilities	453,388	69,977
Long-term liabilities
Long-term debt	94,030	7,391
Derivative liabilities	17,336	10,945
Long-term capital lease obligations	1,526	0
Deferred tax liability	216	0
Contingent consideration liability	11,980	0
Other liabilities	6,473	512
Total liabilities	584,949	88,825
Commitments and contingencies (Note 13)
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 and 300,000,000 shares authorized at December 31, 2013 and 2012, respectively, 30,151,000 shares and 15,008,092 shares issued at December 31, 2013 and 2012, respectively	301	150
Additional paid-in capital	315,975	109,446
Accumulated deficit	(88,012)	(8,839)
Total stockholders' equity	228,264	100,757
Total liabilities and stockholders' equity	$ 813,213	$ 189,582

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Loss Per Share (Tables)

12 Months Ended

Dec. 31, 2013

Schedule Of Computation Of Basic And Diluted Earnings Per Share

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

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1 through August 31, 2012
Net loss attributable to common stockholders	$	(79,173	)	$	(8,839	)	$	(45,437	)
Basic weighted-average common shares outstanding		19,740			15,734			28,841
Add: dilutive effects of stock options and unvested stock grants(1)		—			—			—
Diluted weighted-average common stock outstanding		19,740			15,734			28,841
Basic loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)
Diluted loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)

(1) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

Weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding include the following (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		523		—		558
Total potentially dilutive securities		523		—		1,087

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Income Taxes Expense (Benefit) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012 Predecessor [Member]	Dec. 31, 2012 Predecessor [Member]
Current:
U.S. - Federal	$ 0	$ 0	$ 0
U.S. - State	0	(179)	0
Deferred:
U.S. - Federal	(2,757)	(14)	0
U.S. - State	0	193	0
Total	$ (2,757)	$ 0	$ 0	$ 154,000

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Information Regarding Proved Oil and Gas Reserves (Details Textual) (Detail)	Dec. 31, 2013 MMcf		Dec. 31, 2013 Piceance Energy [Member]	Aug. 31, 2012 Piceance Energy [Member]	Aug. 31, 2012 Reorganized Delta Petroleum [Member] Piceance Energy [Member]	Aug. 31, 2012 Laramie [Member] Piceance Energy [Member]	Dec. 31, 2013 Company [Member] MMcf		Dec. 31, 2012 Company [Member] MMcf		Aug. 31, 2012 Company [Member] MMcf		Dec. 31, 2013 Natural Gas [Member] MMcf	Dec. 31, 2011 Natural Gas [Member] Weighted Average MMcf	Dec. 31, 2013 Natural Gas [Member] Company [Member] MMcf	Dec. 31, 2012 Natural Gas [Member] Company [Member] MMcf	Aug. 31, 2012 Natural Gas [Member] Company [Member] MMcf	Dec. 31, 2013 Natural Gas Liquids [Member] MBbls	Dec. 31, 2011 Natural Gas Liquids [Member] Weighted Average MBbls	Dec. 31, 2013 Natural Gas Liquids [Member] Company [Member] MBbls	Dec. 31, 2012 Natural Gas Liquids [Member] Company [Member] MBbls	Aug. 31, 2012 Natural Gas Liquids [Member] Company [Member] MBbls
Reserve Quantities [Line Items]
Proved Developed And Undeveloped Reserves Net	236,587	[1]					2,078	[1]	2,163	[1]	1,659	[1]	187,259	70,982	662	446	0	7,401	4,057	0	0	0
Ownership interest held in Piceance Energy, percentage			33.34%	33.34%	33.34%	66.66%
Discount Rate Used To Present Value Future Net Revenues From Proved Reserves									10.00%

[1] MMcfe is based on a ratio of 6 Mcf to 1 barrel.

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CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Payments of Stock Issuance Costs	$ 830

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Stockholders' Equity (Details 2) (Detail) (Predecessor [Member], USD $)	8 Months Ended
	Aug. 31, 2012
Predecessor [Member]
Nonvested Stock
Non vested balance, beginning of period	558,301
Granted	0
Vested	0
Expired / canceled	(558,301)
Non vested balance, end of period	0
Weighted-Average Grant-Date Fair Value
Non vested balance, beginning of period	$ 7.45
Granted	$ 0
Vested	$ 0
Expired / canceled	$ (7.45)
Non vested balance, end of period	$ 0
Weighted-Average Remaining Contractual Term
Nonvested-end of year	0 years
Aggregate Intrinsic Value
Nonvested-end of year	$ 0

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Acquisitions and Dispositions (Details) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Goodwill	$ 20,603	$ 7,756
Contingent consideration liability	(11,980)
Texadian Energy Inc [Member]
Goodwill	6,990
Intangible assets	8,809
Net non cash-working capital	3,097
Deferred tax liabilities	(2,757)
Total	16,139
Hawaii Independent Energy LLC [Member]
Inventory	418,750
Trade accounts receivable	59,485
Prepaids and other current assets	1,978
Property, plant and equipment	58,782
Land	39,800
Goodwill	13,613
Intangible assets	4,689
Accounts payable and other current liabilities	(18,154)
Contingent consideration liability	(11,980)
Other noncurrent liabilities	(6,384)
Total	$ 560,579

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Basic and Diluted Loss Per Share (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	4 Months Ended		12 Months Ended		8 Months Ended
	Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012 Predecessor [Member]
Schedule Of Computation Of Basic And Diluted Earnings Per Common Share [Line Items]
Net loss attributable to common stockholders	$ (8,839)		$ (79,173)		$ (45,437)
Basic weighted-average common shares outstanding	15,734		19,740		28,841
Add: dilutive effects of stock options and unvested stock grants	0	[1]	0	[1]	0	[1]
Diluted weighted-average common stock outstanding	15,734		19,740		28,841
Basic loss per common share attributable to common stockholders:
Net loss	$ (0.56)	[1]	$ (4.01)	[1]	$ (1.57)	[1]
Diluted loss per common share attributable to common stockholders:
Net loss	$ (0.56)	[1]	$ (4.01)	[1]	$ (1.57)	[1]

[1] Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

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Business Combination Disclosure (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

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

Intangible assets	$	8,809
Goodwill		6,990
Net non cash-working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	16,139

Schedule Of Purchase Price Allocation Preliminary Estimated Fair Value Of The Assets Acquired And Liabilities Assumed

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

Inventory	$	418,750
Trade accounts receivable		59,485
Prepaids and other current assets		1,978
Property, plant and equipment		58,782
Land		39,800
Goodwill		13,613
Intangible assets		4,689
Accounts payable and other current liabilities		(18,154	)
Contingent consideration liability		(11,980	)
Other noncurrent liabilities		(6,384	)
Total	$	560,579

Business Acquisition, Pro Forma Information

The unaudited pro forma financial information presented below assumes that the Texadian and HIE acquisitions occurred as of January 1, 2012 and combines the Predecessor and Successor periods to include a full year of results for the year ended December 31, 2012. We did not include any adjustments related to the application of fresh-start reporting for the year ended December 31, 2012.

	2013			2012
(in millions)
Revenues	$	2,986.8		$	3,811.1
Net loss	$	(122.0	)	$	(12.0	)

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Schedule of Finite-Lived Intangible Assets (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	$ 13,498	$ 8,809
Amortized intangible assets, Accumulated Amortization	(2,328)	0
Amortized intangible assets, Net	11,170	8,809
Supplier relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	3,360	3,360
Amortized intangible assets, Accumulated Amortization	(258)	0
Amortized intangible assets, Net	3,102	3,360
Rail car leases [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	3,249	3,249
Amortized intangible assets, Accumulated Amortization	(650)	0
Amortized intangible assets, Net	2,599	3,249
Historical Shipper Status [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	2,200	2,200
Amortized intangible assets, Accumulated Amortization	(1,100)	0
Amortized intangible assets, Net	1,100	2,200
Trade names and trademarks [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	4,689	0
Amortized intangible assets, Accumulated Amortization	(320)	0
Amortized intangible assets, Net	$ 4,369	$ 0

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Stockholders' Equity

12 Months Ended

Dec. 31, 2013

Stockholders' Equity

Note 14 - Stockholders’ Equity

Pursuant to the Plan, on the Emergence Date, (i) all shares of our common stock outstanding prior to the Effective Date were cancelled, (ii) each holder of our 7% senior unsecured notes due 2015 and our 3 ³⁄₄% senior convertible notes due 2037 received, in exchange for its total claim (including principal and interest), its pro rata portion of 14,573,608 shares of our common stock, (iii) each holder of an allowed general unsecured claim received, in exchange for its total claim, its pro rata portion of 191,973 shares of our common stock, and (iii) the Lenders under the Loan Agreement received warrants to purchase up to an aggregate of 959,213 shares of our common stock (which number of shares may be increased to an aggregate of 1,220,000 shares of our common stock pursuant to the terms of the Warrant Issuance Agreement).

Amendments to the Certificate of Incorporation and Bylaws

Pursuant to the Plan, on the Emergence Date, our certificate of incorporation and bylaws were amended and restated in their entirety.

Under the restated certificate of incorporation, the total number of all shares of capital stock that we are authorized to issue is 303 million shares, consisting of 300 million shares of common stock and 3 million shares of preferred stock, par value $0.01 per share. The restated certificate of incorporation contains restrictions on the transfer of certain of our securities in order to preserve the net operating loss carryovers, capital loss carryovers, general business credit carryovers, alternative minimum tax credit carryovers and foreign tax credit carryovers, as well as any “net unrealized built-in loss” within the meaning of Section 382 of the Code, of us or any direct or indirect subsidiary thereof.

On November 25, 2013, our amended and restated certificate of incorporation was further amended to (i) increase the authorized shares of Common Stock from 300,000,000 to 500,000,000 and (ii) revise certain provisions regarding approval by the company’s Board of Directors of transfers of Common Stock by holders of five percent or more of the outstanding Common Stock.

Preferred Stock

As of December 31, 2013 and 2012, no shares of preferred stock were outstanding.

Common Stock

On December 31, 2012, a total of 3,052 shares of our common stock were issued to members of our Board of Directors in lieu of a cash fee for their service on the Board. We recognized compensation costs of approximately $33 thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $10.00 to $12.00 per share of common stock. Due to our limited daily trading activity, we believe that this represents a more accurate reflection of the fair value of our common stock.

On September 13, 2013, we entered into a Common Stock Purchase Agreement pursuant to which we agreed to sell shares of our common stock at a price of $13.90 per share, as adjusted to reflect the one for ten reverse stock split effective for trading purposes on January 29, 2014 (the “Reverse Stock Split”), in a private placement transaction (the “Private Placement”) in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933. Certain purchasers, namely, ZCOF Par Petroleum Holdings, L.L.C., an affiliate of Zell Credit Opportunities Master Fund, L.P. (“ZCOF”), and affiliates of Whitebox Advisors, LLC (“Whitebox”), each owned 10% or more of the our common stock directly or through affiliates prior to the execution of the Common Stock Purchase Agreement and are deemed to be our affiliates as a result of such ownership. ZCOF and Whitebox have representatives on our board of directors.

On September 25, 2013, we completed the Private Placement and issued approximately 14.4 million shares of common stock resulting in aggregate gross proceeds to us of approximately $200 million. We did not engage any investment advisors with respect to the Private Placement, and no finders’ fees or commissions were paid to any party in connection therewith. The proceeds from the Private Placement were used to fund a portion of the purchase price of the HIE acquisition.

During the year ended December 31, 2013, we issued approximately 208,512 shares of our common stock for settlement of bankruptcy claims, approximately 183,390 shares due to the exercise of Warrants and approximately 5,585 shares of unrestricted common stock to certain key employees and directors. We recognized compensation costs of approximately $90 thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $12.22 to $19.87 per share of common stock.

Registration Rights Agreements

Pursuant to the Plan, on the Effective Date, we entered into a registration rights agreement (the “Registration Rights Agreement”) providing the stockholders party thereto (the “Stockholders”) with certain registration rights.

The Registration Rights Agreement states that, among other things, at any time after the earlier of the consummation of a qualified public offering or 60 days after the Effective Date, any Stockholder or group of Stockholders that, together with its or their affiliates, holds more than fifteen percent of the Registrable Shares (as defined in the Registration Rights Agreement), will have the right to require us to file with the SEC a registration statement on Form S-1 or S-3, or any other appropriate form under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, for a public offering of all or part of its Registrable Shares (each a “Demand Registration”), by delivery of written notice to the company (each, a “Demand Request”).

Within 90 days after receiving the Demand Request, we must file with the SEC the registration statement, on any form for which we then qualify and which is available for the sale of the Registrable Shares in accordance with the intended methods of distribution thereof, with respect to the Demand Registration. We are required to use commercially reasonable efforts to cause the registration statement to be declared effective as soon as practicable after such filing. We will not be obligated (i) to effect a Demand Registration within 90 days after the effective date of a previous Demand Registration, other than for a shelf registration, or (ii) to effect a Demand Registration unless the Demand Request is for a number of Registrable Shares with an expected market value that is equal to at least (x) $15 million as of the date of such Demand Request or is for one hundred percent of the demanding Stockholder’s Registrable Shares with respect to any Demand Registration made on Form S-1 or (y) $5 million as of the date of such Demand Request with respect to any Demand Registration made on Form S-3.

Upon receipt of any Demand Request, we are required to give written notice, within ten (10) days of such Demand Registration, to all other holders of Registrable Shares, who will have the right to elect to include in such Demand Registration such portion of their Registrable Shares as they may request, subject to certain exceptions.

In addition, subject to certain exceptions, if we propose to register any class of common stock for sale to the public, we are required, subject to certain conditions, to include all Registrable Shares with respect to which we have received written requests for inclusion.

The rights of a holder of Registrable Shares may be transferred, assigned or otherwise conveyed on to any transferee or assignee of such Registrable Shares, subject to applicable state and federal securities laws and regulations, our Certificate of Incorporation and the Stockholders Agreement. We will be responsible for expenses relating to the registrations contemplated by the Registration Rights Agreement.

The registration rights granted in the Registration Rights Agreement are subject to customary indemnification and contribution provisions, as well as customary restrictions such as suspension periods and, if a registration is for an underwritten offering, limitations on the number of shares to be included in the underwritten offering imposed by the managing underwriter.

In connection with the closing of the sale of the Private Placement, we entered into an additional registration rights agreement with the purchasers of the shares. Under this registration rights agreement, we agreed to file a registration statement relating to the shares of common stock with the U.S. Securities and Exchange Commission within 60 days after the closing date of the sale which would be declared effective within 180 days of the closing date of the sale. We also agreed to use commercially reasonable efforts to keep the registration statement effective until the earliest to occur of (i) the disposition of all registrable securities, (ii) the availability under Rule 144 of the Securities Act of 1933, as amended, for each holder of registrable securities to immediately freely resell such registrable securities without volume restrictions or (iii) the third anniversary of the effective date of the registration statement.

This registration rights agreement also provides the right for a holder or group of holders of more than $50 million of registrable securities to demand that we conduct an underwritten public offering of the registrable securities. However, the demanding holders are limited to a total of three such underwritten offerings, with no more than one demand request for an underwritten offering made in any 365 day period. Additionally, this registration rights agreement contains customary indemnification rights and obligations for both us and the holders of registrable securities.

If this registration statement (i) is not filed with the SEC on or prior to the applicable deadline (ii) is not declared effective by the SEC prior to the applicable deadline, or (iii) does not remain effective for the applicable effectiveness period described above then from the that date until cured, we must pay, as liquidated damages and not as a penalty, an amount in cash equal to 0.25% of the purchaser’s allocated purchase price per calendar month, not to exceed 0.75% of the allocated purchase price. We will accrue an obligation for this registration rights agreement when it is probable that an obligation has been incurred and the amount can be reasonably determined.

Incentive Plan

On December 20, 2012, our Board of Directors (the “Board”) approved the Par Petroleum Corporation 2012 Long Term Incentive Plan (the “Incentive Plan”). Under the Incentive Plan, the Board, or a committee of the Board, may issue up to 1.6 million shares of our common stock, or incentive stock options, nonstatutory stock options or restricted stock to our employee or directors, or other individuals providing services to us. In general, the terms of any award issue will be determined by the committee upon grant. In addition, in December 2012, we approved a new compensation plan for our directors. Our directors receive an annual retainer of $50 thousand, paid quarterly in cash or shares of our common stock at the election of the director. In addition, the Chairman of the Audit Committee receives an additional annual retainer of $15 thousand and the members of the Audit Committee (other than the Chairman) receive an annual retainer of $5 thousand, such retainers paid quarterly in cash or shares of our common stock at the election of the director. There are no fees for the members of any other committee or for attendance at meetings. Our directors are also entitled to receive an annual grant of restricted stock on the last day of each calendar year with a target value of $75 thousand, with the number of shares determined by the 60-day volume weighted average share price as of the day prior to the grant date.

On December 31, 2012, a total of 219,183 shares of restricted common stock were granted to members of the Board of Directors and certain employees. During the year ended December 31, 2013, an additional 355,481 shares of restricted stock were granted to certain employees. Restricted stock granted to members of the Board vests in full after one year from the date of grant, while most restricted stock granted to employees vests on a pro-rata basis over five years. For the year ended December 31, 2013, the following activity occurred under our Incentive Plan (in thousands, except per share amounts):

	Shares			Weighted- Average Grant Date Fair Value
Non vested balance, beginning of period		219		$	12.00
Granted		356			18.32
Vested		(51	)		12.00
Forfeited		—			—
Non vested balance, end of period		524		$	16.29
Available for grant		1,025

For the year ended December 31, 2013, we recognized compensation costs of approximately $1.2 million related to restricted stock awards. As of December 31, 2013, there is approximately $8.1 million of total unrecognized compensation costs related to restricted stock awards, which are expected to be recognized on a straight-line basis over a weighted average period of 4.37 years. The grant date fair value was estimated using the previous 20 days average trading price of our common stock.

Predecessor Stock Compensation Plans

On December 22, 2009, the Predecessor’s stockholders approved its 2009 Performance and Equity Plan (the “2009 Plan”). On June 21, 2011, the Predecessor granted 489,227 shares of non-vested common stock to certain employees. The shares vested in full on the earlier of a change in control or July 1, 2012. In conjunction with this grant, the Predecessor agreed to establish a “floor” price for the value of the shares on the date of vesting equal to the value of the shares on the grant date ($5.50 per share). In the event that the market price of the shares on the date of vesting was lower than the floor price on the date of vesting, the difference would be paid to the employees in cash. The compensation expense for the shares consists of a fixed equity component ($5.50 per share) and a variable liability component (based on the difference between the market price of the shares, if lower, and the floor price of the shares), both of which are included as a component of general and administrative expense in the accompanying Predecessor consolidated statement of operations. The Predecessor recognized stock compensation expense of approximately $1.9 million for the period from January 1, 2012 through August 31, 2012, which is included in general and administrative expenses. Under the terms of the Plan, the Predecessor’s stock compensation plans, and all awards issued under such plans, were canceled.

A summary of the stock option activity under the Predecessor’s various plans and related information for the period from January 1 through August 31, 2012 follows:

	Period from January 1  through August 31, 2012
	Options			Weighted-Average Exercise  Price			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic  Value
Outstanding-beginning of year		150,300		$	75.00
Granted		—			—
Exercised		—			—
Expired / canceled		(150,300	)		(75.00	)
Outstanding-end of year		—		$	—			—	$	—
Exercisable-end of year		—		$	—			—	$	—

A summary of the restricted stock (nonvested stock) activity under the Predecessor’s plan and related information for the period from January 1 through August 31, 2012 follows (in thousands, except share and per share amounts):

	Period from January 1  through August 31, 2012
	Nonvested Stock			Weighted-Average Grant-Date Fair  Value			Weighted-Average Remaining Contractual Term		Aggregate Intrinsic  Value
Nonvested-beginning of year		558,301		$	7.45
Granted		—			—
Vested		—			—
Expired / canceled		(558,301	)		(7.45	)
Nonvested-end of year		—		$	—			—	$	—

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Property, Plant and Equipment Disclosure (Tables)

12 Months Ended

Dec. 31, 2013

Property, Plant and Equipment

Major classes of property, plant and equipment consist of the following (in thousands):

	December 31,
	2013			2012
Land	$	39,800		$	—
Buildings and equipment		65,878			—
Other		1,945			1,415
Property, plant and equipment		107,623			1,415
Proved oil and gas properties		4,949			4,804
Less: accumulated depreciation, depletion and amortization		(3,968	)		(373	)
	$	108,604		$	5,846

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Deferred Tax Asset (Liabilities) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Deferred tax assets:
Net operating loss	$ 544,377	$ 450,195
Capital loss carry forwards	26,141	26,141
Property and equipment	34,683	23,045
Investment in Piceance Energy	32,138	45,172
Derivative instruments	0	1,498
Accrued bonuses	0	0
Trust liability	1,327	0
Other	1,183	1,506
Total deferred tax assets	639,849	547,557
Valuation allowance	(637,464)	(544,442)
Net deferred tax assets	2,385	3,115
Deferred tax liabilities:
Property and equipment	5	0
Texadian Energy intangibles	2,380	3,083
Prepaid insurance, marketable securities and other	0	32
State liabilities	216	0
Total deferred tax liabilities	2,601	3,115
Total deferred tax liability, net	$ (216)	$ 0

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Loss Per Share

12 Months Ended

Dec. 31, 2013

Loss Per Share

Note 16 - Loss Per Share

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

	Successor						Predecessor
	Year Ended December 31, 2013			September 1 through December 31, 2012			January 1 through August 31, 2012
Net loss attributable to common stockholders	$	(79,173	)	$	(8,839	)	$	(45,437	)
Basic weighted-average common shares outstanding		19,740			15,734			28,841
Add: dilutive effects of stock options and unvested stock grants(1)		—			—			—
Diluted weighted-average common stock outstanding		19,740			15,734			28,841
Basic loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)
Diluted loss per common share attributable to common stockholders:
Net loss(1)	$	(4.01	)	$	(0.56	)	$	(1.57	)

(1) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

Weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding include the following (in thousands):

	Successor				Predecessor
	Year Ended December 31, 2013		Period from September 1 through December 31, 2012		Period from January 1 through August 31, 2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		523		—		558
Total potentially dilutive securities		523		—		1,087

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Schedule of Goodwill (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Goodwill [Line Items]
Balance at beginning of period	$ 7,756
Additions	13,613
Texadian purchase price adjustments	(766)
Balance at end of period	$ 20,603

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Disclosures About Capitalized Costs, Costs Incurred (Details) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013 Company [Member]	Dec. 31, 2012 Company [Member]	Dec. 31, 2013 Company's Share of Piceance Energy [Member]	Dec. 31, 2012 Company's Share of Piceance Energy [Member]	Aug. 31, 2012 Predecessor [Member] Company [Member]
Oil and Gas In Process Activities [Line Items]
Unproved properties			$ 0	$ 0	$ 15,763	$ 16,180	$ 84
Proved properties	4,949	4,804	4,949	4,804	168,378	134,638	759,755
Oil and Gas Property, Successful Effort Method, Gross, Total			4,949	4,804	184,141	150,818	759,839
Accumulated depreciation and depletion			(1,868)	(337)	(38,452)	(2,808)	(642,172)
Oil and gas property, successful efforts method			$ 3,081	$ 4,467	$ 145,689	$ 148,010	$ 117,667

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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012 Predecessor [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$ (8,839)	$ (79,173)	$ (45,437)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation, depletion, amortization and accretion	401	5,982	16,041
Non cash interest expense	1,056	16,742	2,989
Change in asset values due to fresh - start accounting adjustments	0	0	14,765
Gain on extinguishment of senior debt	0	0	(166,144)
Gain on settlement of liabilities	0	0	(2,188)
(Gain) loss on property sales	(82)	(50)	126
Dry hole costs and impairments	0	0	151,347
Stock-based compensation	34	1,161	1,895
Change in value of common stock warrants	4,280	10,114	0
Loss from unconsolidated affiliates	1,325	2,941	20
Deferred income tax expense (benefit)	(2,757)	179	0
Other	0	0	(699)
Net changes in operating assets and liabilities:
Trade accounts receivable	(2,234)	(40,278)	3,472
Prepaids and other current assets	(538)	(2,569)	(1,378)
Inventories	0	48,593	0
Accounts payable	2,718	15,829	(4,187)
Supply and exchange agreements	0	(18,381)	0
Settlement liability	0	1,898	0
Accrued reorganization costs	0	0	9,116
Other accrued liabilities	0	1,335	0
Net cash used in operating activities	(4,636)	(35,677)	(20,262)
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	0	(7,768)	(1,613)
Acquisitions, net of cash acquired	(17,439)	(559,279)	0
Proceeds from asset sales	0	2,850	74,209
Proceeds from sale of other fixed assets	39	0	26
Capitalized drilling costs paid to operator	(415)	(303)	0
Proceeds from sale of unconsolidated affiliates	125	0	0
Net cash (used in) provided by investing activities	(17,690)	(564,500)	72,622
CASH FLOWS FROM FINANCING ACTIVITIES:
Funding of purchase of HIE from supply and exchange agreements	0	378,238	0
Proceeds from sale of common stock, net of offering costs	0	199,170	0
Proceeds from exercise of common stock warrants	0	18	0
Proceeds from borrowings	35,000	159,800	23,000
Repayments of borrowings	0	(121,909)	(59,535)
Payment of deferred loan costs	0	(2,264)	0
Fund distribution agent account	0	0	(21,805)
Proceeds from (funding of) Wapiti and General Recovery Trusts	2,446	0	(2,000)
Recoveries from bankruptcy settlements	5,183	0	0
Restricted cash released from (held to) secure letter of credits	(19,000)	19,000	0
Net cash provided by (used in) financing activities	23,629	632,053	(60,340)
Net increase (decrease) in cash and cash equivalents	1,303	31,876	(7,980)
Cash at beginning of period	4,882	6,185	12,862
Cash at end of period	6,185	38,061	4,882
SUPPLEMENTAL CASH FLOW INFORMATION
Cash paid for interest and financing costs	0	2,186	3,745
NON-CASH INVESTING AND FINANCING ACTIVITIES
Stock issued used to settle bankruptcy claims	0	2,605	0
Interest payable capitalized to principal balance	0	6,096	0
Non-cash additions to property, plant and equipment	$ 209	$ 0	$ 0

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CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized	3,000,000	3,000,000
Preferred stock, shares issued	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	300,000,000
Common stock, shares issued	30,151,000	15,008,092

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Supply and Exchange Agreements

12 Months Ended

Dec. 31, 2013

Supply and Exchange Agreements

Note 9 - Supply and Exchange Agreements

HIE entered into several agreements with Barclays Bank PLC (“Barclays”), referred to collectively as the Supply and Exchange Agreements, on September 25, 2013 in connection with the acquisition of HIE. We entered into the Supply and Exchange Agreements for the purpose of managing our working capital and the crude oil and refined product inventory at the refinery.

Pursuant to the Supply and Exchange Agreements, Barclays holds title to all of the crude oil in the tanks at the refinery. Additionally, Barclays holds title to a majority of our refined product inventory in our tanks at the refinery. Barclays also prepaid us for certain inventory held at locations outside of our refinery. We hold title to the inventory during the refining process. Barclays sells the crude oil as it is discharged out of the refinery’s tanks. We exchange refined product owned by Barclays stored in our tanks for equal volumes of refined product produced by our refinery when we execute third party sales of refined product. We currently market and sell the refined product independently to third parties. The Supply and Exchange Agreements have an initial term of three years with two one-year renewal options.

As described in Note 2 - Summary of Significant Accounting Policies, we record the inventory owned by Barclays on our behalf because we maintain the risk of loss until the refined products are sold to third parties. Because we do not hold legal title to the crude oil inventory until it enters the refinery, we record a liability in an amount equal to the carrying value of the crude oil inventory. In accordance with the terms of the Supply and Exchange Agreements, the volume of refined products purchased by Barclays in connection with the acquisition of HIE is known as the “Block Volume”. To the extent we have refined products inventory volumes at period-end in excess of the Block Volume, we record a liability for the Block Volume valued at the per barrel carrying value of the refined product inventory owned by Barclays. From time to time, we may sell refined product inventory that causes our refined product inventory to be less than the Block Volume. To the extent of this shortfall, we record a liability for the volumes that we would need to purchase at current market prices in order to meet the Block Volume requirement. The liability related to the Supply and Exchange Agreements is included in obligations under supply and exchange agreements on our consolidated balance sheet.

For the year ended December 31, 2013, we incurred approximately $3.7 million in handling fees related to the Supply and Exchange Agreements, which is included in cost of revenues on our consolidated statement of operations. For the year ended December 31, 2013, interest expense and financing costs, net includes $1.4 million of expense related to the Supply and Exchange Agreements.

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Segment Information (Details 1) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Assets	$ 813,213	$ 189,582
Refining Distribution and Marketing [Member]
Assets	641,840	0
Natural Gas and Oil Operations [Member]
Assets	109,316	116,034
Commodity Marketing And Logistics [Member]
Assets	52,048	62,754
Corporate and Other [Member]
Assets	$ 10,009	$ 10,794

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Stockholders' Equity (Details 1) (Detail) (Predecessor [Member], USD $)	8 Months Ended
	Aug. 31, 2012
Predecessor [Member]
Options
Outstanding-beginning of year	150,300
Granted	0
Exercised	0
Expired / canceled	(150,300)
Outstanding-end of year	0
Exercisable-end of year	0
Weighted-Average Exercise Price
Outstanding-beginning of year	$ 75.00
Granted	$ 0
Exercised	$ 0
Expired / canceled	$ (75.00)
Outstanding-end of year	$ 0
Exercisable-end of year	$ 0
Weighted-Average Remaining Contractual Term
Outstanding-end of year	0 years
Exercisable-end of year	0 years
Aggregate Intrinsic Value
Outstanding-end of year	$ 0
Exercisable-end of year	$ 0

XML

Stockholders' Equity (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended		12 Months Ended						1 Months Ended	12 Months Ended			12 Months Ended		8 Months Ended	1 Months Ended		12 Months Ended					12 Months Ended					12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 20, 2012	Dec. 31, 2013 Common Stock [Member]	Dec. 31, 2013 Common Stock [Member] Settlement Of Bankruptcy Claims [Member]	Dec. 31, 2013 Common Stock [Member] Exercise of Warrants [Member]	Dec. 31, 2013 Common Stock [Member] Employees and Directors [Member]	Dec. 31, 2013 Restricted Stock [Member]	Dec. 31, 2012 Restricted Stock [Member]	Jan. 23, 2014 Subsequent Event [Member]	Dec. 31, 2012 Board Of Directors [Member]	Dec. 31, 2013 Board Of Directors [Member] Restricted Stock [Member]	Dec. 31, 2013 Restatement	Dec. 31, 2013 Form S-1	Dec. 31, 2013 Form S-3	Aug. 31, 2012 Predecessor [Member]	Jun. 21, 2011 Predecessor [Member] Common Stock [Member]	Dec. 31, 2012 Incentive Plans [Member]	Dec. 31, 2012 Incentive Plans [Member]	Dec. 31, 2012 Incentive Plans [Member] Chairperson Of Audit Committee [Member]	Dec. 31, 2012 Incentive Plans [Member] Non Chairman Audit Committee [Member]	Dec. 31, 2013 7% Senior Unsecured Notes, due 2015 [Member]	Dec. 31, 2013 3 3/4% Senior Convertible Notes, due 2037 [Member]	Dec. 31, 2013 Senior Unsecured Note [Member]	Dec. 31, 2013 Unsecured Debt [Member]	Dec. 31, 2013 Minimum [Member] Employees and Directors [Member]	Dec. 31, 2012 Minimum [Member] Board Of Directors [Member]	Dec. 31, 2013 Maximum [Member]	Dec. 31, 2013 Maximum [Member] Employees and Directors [Member]	Dec. 31, 2012 Maximum [Member] Board Of Directors [Member]
Class of Stock [Line Items]
Interest percentage of senior notes																						7.00%	3.75%
Maturity period																						2015	2037
Shares allotted to note holders																								14,573,608	191,973
Number of shares issuable under warrants		959,213																										1,220,000
Number of shares authorized			1,600,000										303,000,000
Common Stock Shares Authorized	300,000,000	500,000,000											300,000,000
Preferred stock, shares authorized	3,000,000	3,000,000											3,000,000
Preferred stock, par value	$ 0.01	$ 0.01											$ 0.01
Common shares Issued											3,052
Common shares Issued amount	$ 34,000	$ 1,164,000									$ 33,000
Share Price	$ 12.00	$ 22.30																									$ 10.00			$ 12.00
Stockholders Equity Reverse Stock Split										1:10 reverse stock split
Stock Repurchase Program, Price of Common Stock		$ 13.90
Stock Issued During Period, Shares, New Issues				14,400,000	208,512	183,390	5,585
Proceeds from Issuance of Common Stock	0	199,170,000		200,000,000												0
Share Based Compensation	34,000	1,161,000					90,000	1,200,000								1,895,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value																										$ 12.22			$ 19.87
Expected Market Value Of Registrable Shares														15,000,000	5,000,000
Maximum Amount of Repurchase Rights Agreement		50,000,000
Annual retainer to amount																			50,000	15,000	5,000
Annual grant of restricted stock																		75,000	75,000
Period of volume weighted average share price																		60 years
Non-vested shares Granted								355,481	219,183							0	489,227
Vesting period								5 years				1 year
Unrecognized compensation cost								8,100,000
Weighted average period								4 years 4 months 13 days
Value of shares on the grant date, floor																	$ 5.50
Stock compensation expense																$ 1,900,000

XML

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Mar. 26, 2014	Jun. 28, 2013
Document Information [Line Items]
Document Type	10-K/A
Amendment Flag	true
AmendmentDescription	Par Petroleum Corporation (the “Company,” “we,” “our,” and “us”) is filing this Amendment No. 2 on Form 10-K/A (this “Amendment No. 2”) to amend its Annual Report on Form 10-K for the fiscal year ended December 31, 2013, as originally filed with the U.S. Securities and Exchange Commission (the “SEC”) on March 31, 2014 (the “Original Form 10-K”), to reflect the effect of an $8.6 million understatement of its cost of revenues and net loss ($0.44 per common share) for the year ended December 31, 2013 due to miscalculating our crude inventory volumes on hand as of December 31, 2013. See the Introductory Note to the accompanying consolidated financial statements beginning on page F-9 for additional information. In accordance with Rule 12b-15 under the Securities and Exchange Act of 1934, as amended, the following items of the Original Form 10-K are hereby amended and restated in their entirety: Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations Item 8. Financial Statements and Supplementary Data Item 9A. Controls and Procedures Item 15. Exhibits, Financial Statement Schedules This Amendment No. 2 does not amend or otherwise update any other information in the Original Form 10-K. Accordingly, this Amendment No. 2 should be read in conjunction with the Original Form 10-K and with our subsequent filings with the SEC. All capitalized terms used but not defined herein shall have the meanings ascribed to them in the Original Form 10-K.
Document Period End Date	Dec. 31, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	FY
Trading Symbol	PARR
Entity Registrant Name	PAR PETROLEUM CORP/CO
Entity Central Index Key	0000821483
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		30,159,039
Entity Public Float			$ 55,000,000

XML

Debt

12 Months Ended

Dec. 31, 2013

Debt

Note 10 - Debt

Our debt is as follows (in thousands):

	December 31,
	2013			2012
Tranche B Loan	$	19,480		$	35,000
Delayed Draw Term Loan Agreement		—			13,465
ABL Facility		51,800			—
Retail Credit Agreement		26,000			—
Less: unamortized debt discount - warrants		—			(6,014	)
Less: unamortized debt discount - embedded derivative		—			(60	)
Total debt, net of unamortized debt discount		97,280			42,391
Less: current maturities		(3,250	)		(35,000	)
Long-term debt, net of current maturities and unamortized discount	$	94,030		$	7,391

Annual maturities of our long-term debt are due during the following years (in thousands):

Year	Amount Due
2014	$	3,250
2015		2,600
2016		22,080
2017		54,400
2018		2,600
Thereafter		12,350
	$	97,280

Delayed Draw Term Loan Credit Agreement

Pursuant to the Plan, on the Emergence Date, we and certain of our subsidiaries (the “Guarantors” and, together with the company, the “Loan Parties”) entered into a Delayed Draw Term Loan Credit Agreement (the “Loan Agreement”) with Jefferies Finance LLC, as administrative agent (the “Agent”) for the lenders party thereto from time to time, including WB Delta, Ltd., Waterstone Offshore ER Fund, Ltd., Prime Capital Master SPC, GOT WAT MAC Segregated Portfolio, 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 (collectively, the “Lenders”), pursuant to which the Lenders agreed to extend credit to us in the form of term loans (each, a “Loan” and collectively, the “Loans”) of up to $30 million. We borrowed $13 million on the Emergence Date in order to, along with the proceeds from the Contribution Agreement: (i) repay the loans and obligations due under the Predecessor’s secured debtor-in-possession credit facility, and (ii) pay allowed but unpaid administrative expenses to the Debtors related to the Plan. During 2013, we borrowed an additional $17 million for general corporate use. In November 2013, we repaid in full and terminated all of our obligations under the Loan Agreement, other than the New Tranche B Loans described below. Included in interest expense and financing cost, net on the consolidated statements of operations is $6.1 million recorded as loss on extinguishment of debt related to the November 2013 repayment.

Amendment to the Loan Agreement

On December 28, 2012, in order to fund a portion of the purchase price for our acquisition of Texadian Energy, the Loan Parties entered into an amendment to the Loan Agreement with the Agent and the Lenders, pursuant to which certain lenders (the “Tranche B Lenders”) agreed to extend additional borrowings to us (the “Tranche B Loan”). The total commitment of the Tranche B Loan of $35 million was drawn at closing. In addition to funding a portion of the purchase price of the acquisition of Texadian, the Tranche B Loan provided cash collateral for our former cash collateralized letter of credit facility. Pursuant to the Eighth Amendment to the Loan Agreement entered into on June 24, 2013, the Lenders refinanced and replaced the Tranche B Loan with new Tranche B Loans in the aggregate principal amount of $65 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Tranche B Loan, to make payments due under the membership interests purchase agreement in connection with the acquisition of HIE (the “HIE Purchase Agreement”), and for working capital and general corporate purposes.

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to the Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the HIE Purchase Agreement and the use of a portion of the proceeds from the Private Placement to fund a portion of the consideration for the acquisition of HIE and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the HIE Purchase Agreement, (iii) increased the interest rate applicable to certain of the loans, and (iv) amended certain provisions of the Loan Agreement and the other loan documents in connection with the consummation of the transactions contemplated by the HIE Purchase Agreement and the Private Placement (see Note 14 - Stockholder’s Equity).

The consent provided by the Lenders was conditioned on, among other things, (i) the repayment in full of the New Tranche B Loans owing to all Lenders except for ZCOF Par Petroleum Holdings, L.L.C., and a partial repayment of the New Tranche B Loans owing to ZCOF Par Petroleum Holdings, L.L.C. from a portion of the proceeds from the Private Placement and (ii) a portion of the proceeds from the Private Placement being used to consummate the transactions contemplated by the HIE Purchase Agreement.

The New Tranche B Loans bear interest (a) from June 24, 2013 through October 31, 2013 at a rate equal to 9.75% per annum payable, at the election of the company, either (i) in cash or (ii) in kind, and (b) from and after November 1, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in kind. Additionally, we agreed to pay the New Tranche B Lenders a nonrefundable exit fee equal to 2.5% of the aggregate amount of the New Tranche B Loans. The exit fee is earned in full and payable on the maturity date of the Tranche B Loans or, if earlier, the date on which the New Tranche B Loans are paid in full.

The New Tranche B Loans mature and are payable in full on August 31, 2016. We may prepay the New Tranche B Loans at any time, provided that any prepayment is in an integral multiple of $100,000 and not less than $100,000 or, if less, the outstanding principal amount of the New Tranche B Loans. Amounts to be applied to prepayment of New Tranche B Loans shall be applied (i) first, towards payment of interest then outstanding and fees then due, and (ii) second, towards payment of principal then outstanding.

The New Tranche B Loans are secured by a lien on substantially all of our assets and our subsidiaries, excluding Texadian, Texadian Energy Canada Limited (“Texadian Canada”), certain of our immaterial subsidiaries, and Hawaii Pacific Energy and its subsidiaries. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

ABL Facility

On September 25, 2013 and in connection with the with the acquisition of HIE, HIE and its subsidiary (the “ABL Borrowers”) and Hawaii Pacific Energy entered into an asset-based revolving credit facility (the “ABL Facility”) to provide the ABL Borrowers with a senior secured revolving credit facility of up to $125.0 million under which the ABL Borrowers may borrow amounts from time to time based on the available borrowing base as determined in accordance with the ABL Facility. The ABL Facility also allows the ABL Borrowers to use up to $50 million of availability under the ABL Facility for the issuances of letters of credit. The ABL Borrowers borrowed $15 million on September 25, 2013 under the ABL Facility in order to, in part, (i) fund the purchase price under the Purchase Agreement, and (ii) provide working capital to the ABL Borrowers. The proceeds from any future amounts borrowed pursuant to the ABL Facility will be used for general corporate purposes and to fund the working capital of the ABL Borrowers. As of December 31, 2013, the total capacity of the ABL Facility was $83.3 million.

Outstanding balances on the ABL Facility bear interest at the base rate specified below (“Base Rate”) plus a margin (based on a sliding scale of 1.00% to 1.50% depending on the borrowing base usage) or the adjusted LIBO rate specified below (“LIBO Rate”) plus a margin (based on a sliding scale of 2.00% to 2.50% depending on the borrowing base usage). The margin was 1.25% for Base Rate loans and 2.25% for LIBO Rate loans during 2013. The Base Rate is equal to the highest of (i) the prime lending rate of the ABL Agent, (ii) the Federal Funds Rate plus 0.5% per annum, and (iii) the LIBO Rate for a LIBO Rate loan denominated in dollars with a one-month interest period commencing on such day plus 1.00%. The effective weighted-average interest rate for 2013 was 3.13%.

The amounts borrowed pursuant the ABL Facility and all obligations arising under the ABL Facility are secured by a lien in favor of the ABL Agent on substantially all of HIE’s assets.

The ABL Borrowers agreed to pay commitment fees for the ABL Facility equal to 0.375% if the borrowing base usage is greater than 50% and 0.500% if the borrowing base usage is less than or equal to 50%. Outstanding letters of credit will be charged a participation fee at a per annum rate equal to the margin applicable to LIBO Rate loans, a facing fee and customary administrative fees.

All loans and other obligations outstanding under the ABL Facility are payable in full on September 25, 2017.

The ABL Facility requires HIE and its subsidiaries and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting its business and operations, including compliance by HIE in certain circumstances with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”), as adjusted, to total fixed charges of 1.0 to 1.0.

HIE Retail Credit Agreement

On November 14, 2013 , HIE Retail, LLC (“HIE Retail”), our subsidiary, entered into a Credit Agreement (the “Retail Credit Agreement”) in the form of a senior secured term loan of up to $30 million the (“Term Loan”) and a senior secured revolving line of credit of up to $5 million (the “Revolver”). HIE Retail initially borrowed $26 million of the Term Loan at the closing and an additional $4 million of the Term Loan upon HIE Retail’s compliance with certain liquor licensing requirements, if such requirements are satisfied prior to December 31, 2014, will be available. The proceeds of the Term Loan are available for general corporate purposes.

Loans made under the Retail Credit Agreement are secured by a first priority security interest in substantially all of the assets of HIE Retail consisting primarily of 31 distribution outlets, selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii.

The Retail Credit Agreement requires HIE Retail to comply with various financial covenants that are measured on a quarterly basis commencing with the fiscal quarter ending March 31, 2014 and are calculated on a trailing four-quarter basis. Such covenants require HIE Retail to maintain a maximum Leverage Ratio (as defined in the Retail Credit Agreement) as follows:

Period (during and as of the last day of)	Maximum Leverage Ratio
2013 Fiscal Year	5.75 to 1.00
2014 Fiscal Year	5.50 to 1.00
2015 Fiscal Year	5.25 to 1.00
2016 Fiscal Year	5.00 to 1.00
2017 Fiscal Year, and at all times thereafter	4.75 to 1.00

HIE Retail is also required to maintain a Fixed Charge Coverage Ratio of 1.15:1.00.

Term Loan

Principal on the Term Loan will be repaid in 28 quarterly principal payments over the term through November 14, 2020.

The Term Loan will bear interest, at HIE Retail’s election, at a rate equal to (i) 30, 90 and 180 day LIBOR plus the Applicable Margin (as specified below) for LIBOR Loans (as defined in the Retail Credit Agreement), or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Applicable Margin. The effective interest rate for 2013 on the outstanding loan was 2.5%.

Interest is payable at the end of the selected interest period, but no less frequently than quarterly. The Applicable Margin for each fiscal quarter is the applicable rate per annum set forth below, such amount to be determined as of the last day of the immediately preceding fiscal quarter.

Level	Leverage Ratio	Applicable Margin for LIBOR Loans			Applicable Margin for Base Rate Loans
1	<4.00x		2	%		0	%
2	4.00x-5.00x		2.25	%		.25	%
3	>5.00x		2.5	%		.50	%

Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.

Fifty percent of annual Excess Cash Flow (as defined in the Retail Credit Agreement) will be applied to the outstanding principal balance of the Term Loan beginning with Excess Cash Flow for fiscal year 2014 to the extent the leverage ratio is equal to or greater than 4.50:1.00.

Revolver

The Revolver matures on November 14, 2016. Letters of credit issued under the Revolver are not to expire beyond the maturity date of the Revolver.

Advances under the Revolver will bear interest, at HIE Retail’s election, at a rate equal to (a) 30, 90 and 180 day LIBOR plus the Revolver Applicable Margin (as defined below) for LIBOR Loans, or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Revolver Applicable Margin.

HIE Retail agreed to pay a fee (the “Unused Fee”), based on the leverage ratio on the last date of the immediately preceding quarter as set forth below, based on the unused portion of the Revolver and calculated on the average of the unused amount for the quarter. The Unused Fee is payable quarterly in arrears commencing on the November 14, 2013.

The Revolver Applicable Margin and the Unused Fee, for each quarter is determined, on the last date of the immediately preceding fiscal quarter:

Level	Leverage Ratio	Unused Fee			Revolver Applicable Margin for LIBOR Loans			Revolver Applicable Margin for Base Rate Loans
1	<4.00x		.25	%		1.75	%		-.25	%
2	4.00x-5.00x		.375	%		2.00	%		0	%
3	>5.00x		.50	%		2.25	%		.25	%

Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.

Commitment fees for Standby Letters of Credit issued under the Revolver are due quarterly in arrears and will be equal to 2.00% per annum on the letter of credit amount payable. Fees for the issuance and negotiation of Commercial Letters of Credit will be based on the Agent’s standard fee schedule then in effect.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly-owned subsidiary Texadian Canada entered into an uncommitted credit agreement to provide for loans and letters of credit, on an uncommitted and absolutely discretionary basis, in an aggregate amount at any one time outstanding not to exceed $50 million. Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian’s assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian. Texadian agreed to pay certain fees with respect to the loans and letters of credit made available to it under the Uncommitted Credit Agreement, including an up-front fee, an origination fee, a minimum compensation fee, a collateral audit fee, and fees with respect to letters of credit. The Uncommitted Credit Agreement requires Texadian to comply with various affirmative and negative covenants affecting its business, and Texadian must comply with certain financial maintenance covenants, including among other things, covenants regarding the minimum net working capital and minimum tangible net worth of Texadian. The Uncommitted Credit Facility does not permit, at any time, Texadian’s consolidated leverage ratio to be greater than 5.00 to 1.00 or its consolidated gross asset coverage to be equal to or less than zero. As of December 31, 2013, we had $41.6 million of letters of credit outstanding related to this agreement.

Letter of Credit Facility

On December 27, 2012, we entered into a letter of credit facility agreement (the “Letter of Credit Facility”). The Letter of Credit Facility provided for a letter of credit facility in an aggregate principal amount of $30 million that was available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries.

In connection with the acquisition of Texadian, we issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.7 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that certain letters of credit were drawn. Those letters of credit have been terminated and released. The Letter of Credit Facility was terminated on June 17, 2013.

Cross Default Provisions

Included within each of the 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 December 31, 2013, we are in compliance with all of our credit agreements.

Warrant Issuance Agreement

Pursuant to the Plan of Reorganization, on the Emergence Date, we issued to the Lenders warrants (the “Warrants”) to purchase up to an aggregate of 959,213 shares of our common stock (the “Warrant Shares”). In connection with the issuance of the Warrants, we also entered into a Warrant Issuance Agreement, dated as of the Emergence Date (the “Warrant Issuance Agreement”). Subject to the terms of the Warrant Issuance Agreement, the holders are entitled to purchase shares of common stock upon exercise of the Warrants at an exercise price of $0.10 per share of common stock (the “Exercise Price”), subject to certain adjustments from time to time as provided in the Warrant Issuance Agreement. The Warrants expire on the earlier of (i) August 31, 2022 or (ii) the occurrence of certain merger or consolidation transactions specified in the Warrant Issuance Agreement. A holder may exercise the Warrants by paying the applicable exercise price in cash or on a cashless basis.

The number of shares of our common stock issuable upon exercise of the Warrants and the exercise prices of the Warrants will be adjusted in connection with certain issuances or sales of shares of the company’s common stock and convertible securities, or any subdivision, reclassification or combinations of common stock. Additionally, in the case of any reclassification or capital reorganization of the capital stock of the company, the holder of each Warrant outstanding immediately prior to the occurrence of such reclassification or reorganization shall have the right to receive upon exercise of the applicable Warrant, the kind and amount of stock, other securities, cash or other property that such holder would have received if such Warrant had been exercised.

From the Emergence Date through December 31, 2013, we issued an additional 228,735 shares of our common stock to settle bankruptcy matters. This entitled the Lenders to receive an additional 14,859 Warrant Shares through December 31, 2013. On December 12, 2013, Warrants to purchase 183,389 Warrant Shares were exercised. At December 31, 2013, Warrants to purchase an aggregate of 790,683 Warrant Shares were outstanding.

Based on certain anti-dilution provisions in the Warrant Issuance Agreement, we have concluded that the Warrants are not indexed to our equity. Accordingly, on the Emergence Date we estimated the fair value of the Warrants on the date of grant to be approximately $6.6 million and recorded the estimated fair value of the Warrants as a derivative liability with the offset to debt discount. The debt discount was being amortized over the life of the Loan Agreement, using the effective interest method until repayment of the delayed draw term loan in November 2013. Subsequent changes in the fair value of the Warrants are reflected in earnings (see Note 11 - Fair Value Measurements).

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Fair Value Measurements (Details 3) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Fair Value Measurements [Line Items]
Stock price	$ 22.30	$ 12.00
Initial exercise price	$ 0.1	$ 0.1
Term (years)	8 years 8 months 1 day	9 years 8 months 1 day
Risk-free rate	2.78%	1.68%
Expected volatility	52.90%	75.00%

XML

Commitments and Contingencies (Details 2) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013
Commitment And Contingencies [Line Items]
2014	$ 22,724
2015	13,277
2016	12,362
2017	10,375
2018	9,244
Thereafter	25,614
Total minimum rental payments	$ 93,596

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Thousands, except Per Share data, unless otherwise specified	4 Months Ended		12 Months Ended		8 Months Ended
	Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012 Predecessor [Member]
Revenues
Refining, distribution and marketing revenues	$ 0		$ 778,126		$ 0
Commodity marketing and logistics revenues	0		100,149		0
Oil and gas sales	2,144		7,739		23,079
Total operating revenues	2,144		886,014		23,079
Operating expenses
Cost of revenues	0		857,476		0
Operating expense, excluding depreciation, depletion and amortization expense shown separately below	0		27,251		0
Lease operating expense	1,684		5,627		9,038
Transportation expense	0		0		6,963
Production taxes	4		49		979
Exploration expense	0		0		2
Dry hole costs and impairments	0		0		151,347
Depreciation, depletion and amortization	401		5,982		16,041
Trust litigation and settlements	0		6,206		0
General and administrative expense	4,520		21,494		9,386
Acquisition and integration costs	556		9,794		0
Total operating expenses	7,165		933,879		193,756
Operating loss	(5,021)		(47,865)		(170,677)
Other income and (expense):
Interest expense and financing costs, net	(1,056)		(19,471)		(6,852)
Other income	86		808		516
Change in value of common stock warrants	(4,280)		(10,114)		0
Gain on derivative instruments, net	0		410		0
Loss from unconsolidated affiliates	(1,325)		(2,941)		(20)
Total other expense	(6,575)		(31,308)		(6,356)
Loss before income taxes and reorganization items	(11,596)		(79,173)		(177,033)
Income tax benefit	(2,757)		0		0
Loss before reorganization items	(8,839)		(79,173)		(177,033)
Reorganization items
Professional fees and administrative costs	0		0		22,354
Changes in asset fair values due to fresh start accounting adjustments	0		0		14,765
Gain on settlement of senior debt	0		0		(166,144)
Gain on settlement of liabilities	0		0		(2,571)
Net loss	$ (8,839)		$ (79,173)		$ (45,437)
Basic loss per common share (in dollars per share)	$ (0.56)	[1]	$ (4.01)	[1]	$ (1.57)	[1]
Diluted loss per common share (in dollars per share)	$ (0.56)	[1]	$ (4.01)	[1]	$ (1.57)	[1]
Weighted average number of shares outstanding:
Basic (in shares)	15,734		19,740		28,841
Diluted (in shares)	15,734		19,740		28,841

[1] Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

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Business Combination Disclosure

12 Months Ended

Dec. 31, 2013

Business Combination Disclosure

Note 4 - Acquisitions and Dispositions

We made our acquisitions in furtherance of our growth strategy that focuses on the acquisition of income producing businesses in order to monetize our net operating loss carryforwards.

Texadian Energy, Inc.

On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for $14 million plus estimated net working capital of approximately $3 million at closing resulting in approximately $17 million of cash paid at closing. Texadian operates an oil transportation, distribution and marketing business with significant logistics capabilities. The purchase price for the acquisition was funded with a combination of cash and additional borrowings under the Tranche B Loan (see Note 10 - Debt). During 2013, the purchase price was reduced by $1.3 million due to funds received from SEACOR Holdings, Inc. for certain employee-related benefits.

The purchase was accounted for as a business combination whereby the purchase price is allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Texadian’s, and specifically utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. In addition, we recorded certain other identifiable intangible assets. These include relationships with suppliers and shippers and favorable railcar leases. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.

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

Intangible assets	$	8,809
Goodwill		6,990
Net non cash-working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	16,139

None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs of approximately $556 thousand are included in our consolidated statements of operations for the period ended December 31, 2012.

Hawaii Independent Energy, LLC

On June 17, 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, entered into a membership interest purchase agreement (the “HIE Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the HIE Purchase Agreement, Tesoro Hawaii. Pursuant to the HIE Purchase Agreement, on September 25, 2013 (the “Effective Date”), Hawaii Pacific Energy purchased from the Seller all of the issued and outstanding units representing the membership interests in Tesoro Hawaii (the “Purchased Units”), and indirectly thereby also acquired Tesoro Hawaii’s wholly-owned subsidiary, Smiley’s Super Service, Inc. Tesoro Hawaii owns and operates (i) a petroleum refinery located at the Campbell Industrial Park in Kapolei, Hawaii (the “Refinery”), (ii) certain pipeline assets, floating pipeline mooring equipment, and refined products terminals, and (iii) retail assets selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii. Following the acquisition, Tesoro Hawaii was renamed Hawaii Independent Energy, LLC (“HIE”).

Hawaii Pacific Energy acquired the Purchased Units for $75 million, paid in cash at the closing of the HIE Purchase Agreement, plus net working capital and inventories at closing and plus certain contingent earnout payments of up to $40 million. As a part of the purchase price, we also funded approximately $24.3 million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing. The earnout payments, if any, are to be paid annually following each of the three calendar years beginning January 1, 2014 through the year ending December 31, 2016, in an amount equal to 20% of the consolidated annual gross margin of HIE in excess of $165 million during such calendar years, with an annual cap of $20 million. In the event that the Refinery ceases operations or in the event Hawaii Pacific Energy disposes of any facility used in the acquired business, Hawaii Pacific Energy’s obligation to make earnout payments could be modified and/or accelerated as provided in the HIE Purchase Agreement. The purchase price was paid with a portion of the net proceeds from the sale of the shares of our common stock in a private transaction (see Note 14 - Stockholders’ Equity), amounts received pursuant to the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements) and the ABL Facility (see Note 10 - Debt).

We accounted for the acquisition of HIE as a business combination whereby the purchase price has been preliminary allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with HIE’s, and utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. In addition, we recorded certain other identifiable intangible assets. These include trade names and trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.

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

Inventory	$	418,750
Trade accounts receivable		59,485
Prepaids and other current assets		1,978
Property, plant and equipment		58,782
Land		39,800
Goodwill		13,613
Intangible assets		4,689
Accounts payable and other current liabilities		(18,154	)
Contingent consideration liability		(11,980	)
Other noncurrent liabilities		(6,384	)
Total	$	560,579

We are continuing to evaluate certain liabilities assumed in the acquisition, including those related to employee benefits. We have recorded a preliminary estimate of the liability and expect to finalize the purchase price allocation during 2014.

The acquisition was partially funded from proceeds totaling approximately $378.2 million from the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements). None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs totaled approximately $7 million are included in acquisition and integration costs our consolidated statement of operations for the year ended December 31, 2013.

Pro Forma Effects of the Acquisitions

The unaudited pro forma financial information presented below assumes that the Texadian and HIE acquisitions occurred as of January 1, 2012 and combines the Predecessor and Successor periods to include a full year of results for the year ended December 31, 2012. We did not include any adjustments related to the application of fresh-start reporting for the year ended December 31, 2012.

	2013			2012
(in millions)
Revenues	$	2,986.8		$	3,811.1
Net loss	$	(122.0	)	$	(12.0	)

Revenue and earnings for HIE subsequent to the acquisition are included in Note 17 - Segment Information.

Assets Contributed to Piceance Energy

At December 31, 2011, Delta’s oil and gas assets were classified as held for use and no impairment charges resulted from the analysis performed at December 31, 2011 as the estimated undiscounted net cash flows exceeded carrying amounts for all properties. In August 2012, the Bankruptcy Court approved a plan of sale of substantially all of the Predecessor’s assets and accordingly these assets were classified as held for sale and an impairment of approximately $151.3 million was recognized for the period from January 1, 2012 through August 31, 2012 to write-down these assets to fair value due to the application of fresh-start reporting. The assets were then contributed to Piceance Energy in accordance with our Plan of Reorganization.

Assets Held for Sale

As of December 31, 2012, we classified certain compressors as held for sale, which were recorded at the lower of cost or estimated net realizable value. On February 20, 2013, these compressors were sold for approximately $2.9 million resulting in a gain of $50 thousand.

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Equity Method Investments Disclosure

12 Months Ended

Dec. 31, 2013

Equity Method Investments Disclosure

Note 3 - Investment in Piceance Energy

We account for our 33.34% ownership interest in Piceance Energy using the equity method of accounting because we are able to exert significant influence but do not control the operating and financial policies. The Piceance Energy LLC Agreement provides that its sole manager may make a written capital call such that each member shall make additional capital contributions up to an aggregate combined total capital contribution of $60 million ($20 million to our interest), if approved by a majority of its board. If any member does not fund its share of the capital call, its interest may be reduced or diluted by the amount of the shortfall. In addition, Piceance Energy has a $400 million secured revolving credit facility secured by a lien on its natural gas and oil properties and related assets with a borrowing base currently set at $120 million. As of December 31, 2013, the balance outstanding on the revolving credit facility was approximately $90.2 million. We are guarantors of Piceance Energy’s credit facility, with recourse limited to the pledge of our equity interests of Par Piceance Energy. Under the terms of its credit facility, Piceance Energy is generally prohibited from making future cash distributions to its owners, including us.

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

				September 1
	Year Ended			through
	December 31, 2013			December 31, 2012
Beginning balance	$	104,434		$	105,344
Loss from unconsolidated affiliates		(3,516	)		(1,325	)
Accretion of basis difference		575			—
Capitalized drilling costs obligation paid		303			415
Ending balance	$	101,796		$	104,434

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

	December 31, 2013			December 31, 2012
Assets
Current assets	$	5,901		$	6,275
Non-current assets		454,402			460,991
Current liabilities		(13,040	)		(11,826	)
Non-current liabilities		(96,738	)		(94,369	)

	Year Ended			September 1 through
	December 31, 2013			December 31, 2012
	100%			100%
Oil, natural gas and natural gas liquids revenues	$	61,091		$	19,391
Loss from operations		(6,765	)		(2,095	)
Net loss		(10,546	)		(3,975	)

The net loss for the year ended December 31, 2013 includes $26.6 million and $770 thousand in DD&A expense and losses on derivative instruments, respectively. The net loss for the period from September 1 through December 31, 2012 include $8.5 million and $917 thousand of DD&A expense and losses on derivative instruments, respectively.

At December 31, 2013 and 2012, our equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment by approximately $15.1 million and $15.9 million, respectively. This difference arose due to lack of control and marketability discounts and we attributed it to natural gas and oil properties and will amortize the difference over 15 years based on the estimate of proved reserves at the date Piceance Energy was formed.

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Income Taxes

12 Months Ended

Dec. 31, 2013

Income Taxes

Note 15 - Income Taxes

Under the Plan of Reorganization, our prepetition debt securities, primarily prepetition notes, were extinguished. Absent an exception, a debtor recognizes cancellation of debt income (“CODI”) upon discharge of its outstanding indebtedness for an amount of consideration that is less than its adjusted issue price. Tax regulations provide that a debtor in a bankruptcy case may exclude CODI from income but must reduce certain of its tax attributes by the amount of any CODI realized as a result of the consummation of a plan of reorganization. The amount of CODI realized by a taxpayer is the adjusted issue price of any indebtedness discharged less the sum of (i) the amount of cash paid, (ii) the issue price of any new indebtedness issued and (iii) the fair market value of any other consideration, including equity, issued. As a result of the market value of our equity upon emergence from Chapter 11 bankruptcy proceedings, we were able to retain a significant portion of our NOLs and other “Tax Attributes” after reduction of the Tax Attributes for CODI realized on emergence from Chapter 11 and certain prior interest payments on debt converted to equity. Our NOLs have been reduced by approximately $225 million of CODI as a result of emergence from Chapter 11.

Pursuant to the Plan, on the Emergence Date, the existing equity interests of the Predecessor were extinguished. New equity interests were issued to creditors in connection with the terms of the Plan, resulting in an ownership change as defined under Section 382 of the Code. Section 382 generally places a limit on the amount of net operating losses and other tax attributes arising before the change that may be used to offset taxable income after the ownership change. We believe, however, that we will qualify for an exception to the general limitation rules. This exception under Code Section 382(l)(5) provides for substantially less restrictive limitations on our net operating losses; however the net operating losses are eliminated should another ownership change occur within two years. Our amended and restated certificate of incorporation places restrictions upon the ability of the equity interest holders to transfer their ownership in us. These restrictions are designed to provide us with the maximum assurance that another ownership change does not occur that could adversely impact our net operating loss carry forwards.

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 the current and prior periods, and projections for future results of operations over the periods in which the deferred tax assets are deductible, among other factors, management concluded that we did not meet the “more likely than not” requirement of ASC 740 in order to recognize deferred tax assets and a valuation allowance has been recorded for the full amount of our net deferred tax assets at December 31, 2013 and 2012.

During the years ended December 31, 2013 and 2012, no adjustments were recognized for uncertain tax benefits.

Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our NOL carry forwards will not always be available to offset taxable income apportioned to the various states. The states from which Texadian’s revenues and HIE’s 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 Texadian’s and HIE’s operations.

During 2014 and thereafter, 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 improve, the amount of the deferred tax asset considered more likely than not to be realizable could be increased.

Income tax expense (benefit) consisted of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Current:
U.S. - Federal	$	—		$	—		$	—
U.S. - State		(179	)		—			—
Deferred:
U.S. - Federal		(14	)		(2,757	)		—
U.S. - State		193			—			—
Total	$	—		$	(2,757	)	$	—

Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate of 35% to pretax income as a result of the following:

	Successor						Predecessor
	Year Ended December 31, 2013			Period from September 1 through December 31, 2012			Period from January 1 through August 31, 2012
Federal statutory rate		(35.0	)%		(35.0	)%		(35.0	)%
State income taxes, net of federal benefit		0.1	%		—			—
Change in valuation allowance		23.1	%		(2.0	)%		(33.0	)
Professional fees related to bankruptcy reorganization		—			8.0	%		17.0	%
Revenue from Wapiti Trust settlement		—			5.0	%		—
Cancellation of debt tax attribute reduction		—			—			51.0	%
Permanent Items		3.7	%
Provision to return adjustments		8.1	%		—			—
Actual income tax rate		—	%		(24.0	)%		—	%

Deferred tax assets (liabilities) are comprised of the following at December 31, 2013 and 2012 (in thousands):

	2013			2012
Deferred tax assets:
Net operating loss	$	544,377		$	450,195
Capital loss carry forwards		26,141			26,141
Property and equipment		34,683			23,045
Investment in Piceance Energy		32,138			45,172
Derivative instruments		—			1,498
Accrued bonuses		—			—
Trust liability		1,327			—
Other		1,183			1,506
Total deferred tax assets		639,849			547,557
Valuation allowance		(637,464	)		(544,442	)
Net deferred tax assets	$	2,385		$	3,115
Deferred tax liabilities:
Property and equipment	$	5		$	—
Texadian Energy intangibles		2,380			3,083
Prepaid insurance, marketable securities and other		—			32
State liabilities		216			—
Total deferred tax liabilities	$	2,601		$	3,115
Total deferred tax liability, net	$	(216	)	$	—

We have net operating loss carryovers as of December 31, 2013 of $1.3 billion for federal income tax purposes. If not utilized, the tax net operating loss carryforwards will expire during 2027 through 2032. Our capital loss carryovers as of December 31, 2013 are $74.7 million. If not utilized, these carryovers will expire during 2015 and 2016. We also have Alternative Minimum Tax Credit Carryovers of $0.8 million. These credits do not expire; however, we must first generate regular taxable income before they can be used. We will not likely generate regular taxable income utilized our net operating loss carry over.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2013

Fair Value Measurements

Note 11 - Fair Value Measurements

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are categorized with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority given to unobservable inputs. The three levels of the fair value hierarchy are as follows:

Level 1 -	Assets or liabilities for which the item is valued based on quoted prices (unadjusted) for identical assets or liabilities in active markets.
Level 2 -	Assets or liabilities valued based on observable market data for similar instruments.
Level 3 -	Assets or liabilities for which significant valuation assumptions are not readily observable in the market; instruments valued based on the best available data, some of which is internally-developed, and considers risk premiums that a market participant would require.

The level in the fair value hierarchy within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. Our policy is to recognize transfers in and/or out of fair value hierarchy as of the end of the reporting period for which the event or change in circumstances caused the transfer. We have consistently applied the valuation techniques discussed below for the periods presented. We use data from peers as well as external sources in the determination of the volatility and risk free rates used in our fair value calculations. A sensitivity analysis is performed as well to determine the impact of inputs on the ending fair value estimate.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Fresh-Start Reporting - The fair value of the Successor was based on its estimated enterprise value post-bankruptcy using valuation techniques described in notes (a) through (e) below. The individual components consist of the estimated enterprise value of Piceance Energy and the sum of the estimated fair value of the assets we retained. The estimates of fair value of the net assets were reflected in the Successor’s consolidated balance sheet as of August 31, 2012.

	Fair Value at August 31, 2012		Fair Value Technique
	(in thousands)
Oil and gas properties
Proved	$	4,587		(a)(b)
Other assets
Frac tanks		1,400		(c)
Compressors		2,800		(c)
Miscellaneous		39		(d)
Investment in Piceance Energy		105,344		(e)

(a) Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.

(b) The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.

(c) The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.

(d) Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.

(e) The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves’ future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

Purchase Price Allocation of Texadian - The fair values of the assets acquired and liabilities assumed as a result of the Texadian acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (f) described below.

	Fair Value at December 31, 2012			Fair Value Technique
	(in thousands)
Net non-cash working capital	$	3,631			(a)
Supplier relationship		3,360			(b)
Historical shipper status		2,200			(c)
Railcar leases		3,249			(d)
Goodwill		7,756			(e)
Deferred tax liabilities		(2,757	)		(f)
	$	17,439

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

Purchase Price Allocation of HIE - The preliminary fair values of the assets acquired and liabilities assumed as a result of the HIE acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (g) described below.

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,059			(a)
Property, plant and equipment		58,782			(b)
Land		39,800			(c)
Trade names and trade marks		4,689			(d)
Goodwill		13,613			(e)
Contingent consideration liability		(11,980	)		(f)
Other noncurrent liabilities		(6,384	)		(g)
	$	560,579

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the property, plant and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and external obsolescence. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the trade names and trademarks was estimated using a form of the income approach, the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) The estimated fair value of the liability for contingent consideration was estimated using Monte Carlo Simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.

(g) Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.

Assets and Liabilities Measure at Fair Value on a Recurring Basis

Common stock warrants - We estimate the fair value of our outstanding Warrants using a Monte Carlo Simulation analysis, which is considered to be Level 3 fair value measurement. Significant inputs used in the Monte Carlo Simulation Analysis include:

	December 31,
	2013			2012
Stock price	$	22.30		$	12.00
Initial exercise price	$	0.1		$	0.1
Term (years)		8.67			9.67
Risk-free rate		2.78	%		1.68	%
Expected volatility		52.9	%		75.0	%

The expected volatility is based on the 10-year historical volatilities of comparable public companies. Based on the Monte Carlo Simulation Analysis, the estimated fair value of the Warrants was $21.64 and $11.30 per share, or approximately $17.3 million and $10.9 million, as of December 31, 2013 and 2012, respectively. Since the Warrants were in the money upon issuance, we do not believe that changes in the inputs to the Monte Carlo Simulation Analysis will have a significant impact to the value of the Warrants other than changes in the value of our common stock. Increases in the value of our common stock will directly be correlated to increases in the value of the Warrants. Likewise, a decrease in the value of our common stock will result in a decrease in the value of the Warrants.

Debt Prepayment Derivative - Our Loan Agreement contained mandatory repayments subject to premiums as set forth in the agreement. Factors such as the sale of assets, distributions from our investment in Piceance Energy, issuance of additional debt or issuance of additional equity may result in a mandatory prepayment. We considered the contingent prepayment feature to be an embedded derivative which was bifurcated from the loan and accounted for as a derivative. The fair value of the embedded derivative was estimated using an income valuation technique and a Crystal Ball forecast. The fair value measurement is considered to be a Level 3 fair value measurement. We do not believe that changes to the inputs in the model would have a significant impact on the valuation of the embedded derivative, other than a change to the estimate of the probability that a triggering event would occur. An increase in the probability of a triggering event occurring would cause an increase in the fair value of the embedded derivative. Likewise, a decrease in the probability of a triggering event occurring would cause a decrease in the value of the embedded derivative. At December 31, 2012, we estimated the fair value of the embedded derivative to be $145 thousand based on the probability of us repaying the loan prior to maturity. In November 2013, we repaid in full and terminated all of our obligations, including any repayment premiums, under this Loan Agreement (other than the new Tranche B loans described above) extinguishing the liability (see Note 10 - Debt).

Derivative instruments - With the acquisition of Texadian, we assumed certain open positions consisting of non-exchange traded fixed price physical contracts. These contracts were not treated as normal purchase or normal sales contracts and changes in fair value were recorded in earnings. In addition, we had certain exchange traded oil contracts that settled during the period and had no open positions as of December 31, 2013. The fair value of our commodity derivatives is measured using the closing market price at the end of the reporting period obtained from the New York Mercantile Exchange and from third party broker quotes and pricing providers. As of December 31, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts for which we have not elected the normal purchase or normal sale exception.

Contingent consideration liability - As described in Note 4, the purchase price for our acquisition of HIE may be increased pursuant to an earn out provision. The initial value of the contingent consideration was estimated to be approximately $12.0 million. The liability is re-measured at the end of each reporting period using the valuation technique as described above. We do not believe that there has been a material change in the liability from September 25, 2013 through December 31, 2013.

Financial Statement Impact

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their placement with our consolidated balance sheet consist of the following (in thousands):

	Location on Consolidated Balance Sheet	Fair Value at December 31, 2013			Fair Value at December 31, 2012
Commodities - physical forward contracts	Prepaid and other current assets	$	—		$	(307	)
Commodities - exchange traded futures	Prepaid and other current assets		—			542
Warrant derivatives	Derivative liabilities		(17,336	)		(10,900	)
Contingent consideration liability	Contingent consideration liability		(11,980	)		—
Debt repayment derivative	Derivative liabilities		—			(45	)

The following table summarizes the pre-tax effect resulting from changes in fair value of derivative instruments charged directly to earnings (in thousands):

		December 31, 2013			September 1 through December 31, 2012
	Income Statement Classification	Gain (loss) recognized in income			Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Change in value of warrants	$	(10,114	)	$	(4,280	)
Debt repayment derivative	Interest expense and financing costs, net		45			—
Commodities - exchange traded futures	Gain on derivative instruments, net		104			—
Commodities - physical forward contracts	Gain on derivative instruments, net		306			—

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their level within the fair value hierarchy is as follows (in thousands):

	December 31, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Warrants derivative	$	(17,336	)	$	—	$	—	$	(17,336	)
Contingent consideration liability		(11,980	)		—		—		(11,980	)
	$	(29,316	)	$	—	$	—	$	(29,316	)

	December 31, 2012
	Fair Value			Level 1		Level 2			Level 3
Assets
Commodities - exchange traded futures	$	542		$	542	$	—		$	—
Liabilities
Warrants derivative	$	(10,900	)	$	—	$	—		$	(10,900	)
Debt prepayment derivative		(45	)		—		—			(45	)
Commodities - physical forward contracts		(307	)		—		(307	)		—
	$	(11,252	)	$	—	$	(307	)	$	(10,945	)

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

Description	2013			2012
Balance, at beginning of period	$	(10,945	)	$	(6,665	)
Settlements		3,723			—
Acquired		(11,980	)		—
Total unrealized losses included in earnings		(10,114	)		(4,280	)
Transfers		—			—
Balance, at end of period	$	(29,316	)	$	(10,945	)

The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2013 and 2012 is as follows (in thousands):

	December 31, 2013
	Carrying Value		Fair Value(1)
Tranche B	$	19,480	$	18,800
ABL Facility		51,800		51,800
HIE Retail Credit Agreement		26,000		26,000
Warrants		17,336		17,336
Contingent consideration liability		11,980		11,980

	December 31, 2012
	Carrying Value		Fair Value(1)
Long-term debt	$	7,391	$	10,900
Warrants		10,900		10,900
Debt repayment derivative		45		45

⁽¹⁾ The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.

The fair value of all non-derivative financial instruments included in current assets, including cash and cash equivalents, restricted cash and trade accounts receivable, current liabilities and accounts payable approximate their carrying value due to their short term nature.

We estimate our long term debt’s fair value using a discounted cash flow analysis and an estimate of the current yield of 5.72% and 5.72% as of December 31, 2013 and 2012, respectively, by reference to market interest rates for term debt of comparable companies.

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Fair Value Measurements (Details 7) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance, at beginning of period	$ (10,945)	$ (6,665)
Settlements	3,723	0
Acquired	(11,980)	0
Total unrealized losses included in earnings	(10,114)	(4,280)
Transfers	0	0
Balance, at end of period	$ (29,316)	$ (10,945)

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Inventories

12 Months Ended

Dec. 31, 2013

Inventories

Note 7 - Inventories

The following is a summary of our inventory (in thousands):

	December 31, 2013						December 31, 2012
	Titled Inventory		Supply and Exchange Agreements		Total		Titled Inventory
Crude oil and feedstocks	$	—	$	137,706	$	137,706	$	10,466
Refined products and blend stock		67,532		161,554		229,086		—
Spare parts, materials and supplies, and merchandise		13,831		—		13,831		—
	$	81,363	$	299,260	$	380,623	$	10,466

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Acquisitions and Dispositions (Details 1) (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Business Acquisition [Line Items]
Revenues	$ 2,986.8	$ 3,811.1
Net loss	$ (122.0)	$ (12.0)

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Disclosures About Capitalized Costs, Costs Incurred (Details Textual) (Detail) (USD $)	4 Months Ended	8 Months Ended
	Dec. 31, 2012	Aug. 31, 2012
Piceance Energy [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Proved properties acquisition costs	$ 24,200,000
Capitalized Exploratory Well Costs, Suspended, Percentage of Equity Interest		33.34%
Suspended exploratory well cost		8,770
Laramie [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Proved properties acquisition costs	$ 8,300,000

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Property, Plant and Equipment Disclosure

12 Months Ended

Dec. 31, 2013

Property, Plant and Equipment Disclosure

Note 5 - Property, Plant and Equipment

Major classes of property, plant and equipment consist of the following (in thousands):

	December 31,
	2013			2012
Land	$	39,800		$	—
Buildings and equipment		65,878			—
Other		1,945			1,415
Property, plant and equipment		107,623			1,415
Proved oil and gas properties		4,949			4,804
Less: accumulated depreciation, depletion and amortization		(3,968	)		(373	)
	$	108,604		$	5,846

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Asset Retirement Obligation Disclosure

12 Months Ended

Dec. 31, 2013

Asset Retirement Obligation Disclosure

Note 6 - Asset Retirement Obligations

The following is a reconciliation of our AROs (in thousands):

	Successor				Predecessor
			September 1		January 1
	Year Ended		through		through
	December 31, 2013		December 31, 2012		August 31, 2012
Asset retirement obligation - beginning of period	$	512	$	476	$	3,799
Obligation acquired		2,601		—		—
Accretion expense		59		36		178
Change in estimate		—		—		437
Settlement upon transfer to Piceance Energy		—		—		(3,938	)
Asset retirement obligation - end of period	$	3,172	$	512	$	476

As the result of the contribution of assets to Piceance Energy during the reorganization, approximately $3.9 million of our AROs was deemed settled as of the Emergence Date.

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Intangible assets

12 Months Ended

Dec. 31, 2013

Intangible assets

Note 8 - Intangible assets

Our intangible assets consist of the following (in thousands):

	December 31,
	2013			2012
Amortized intangible assets:
Gross carrying amount:
Supplier relationships	$	3,360		$	3,360
Rail car leases		3,249			3,249
Historical shipper status		2,200			2,200
Trade names and trademarks		4,689			—
Subtotal		13,498			8,809
Accumulated amortization
Supplier relationships		(258	)		—
Rail car leases		(650	)		—
Historical shipper status		(1,100	)		—
Trade name and trademarks		(320	)		—
Subtotal		(2,328	)		—
Net:
Supplier relationships		3,102			3,360
Rail car leases		2,599			3,249
Historical shipper status		1,100			2,200
Trade name and trademarks		4,369			—
Total amortized intangible assets, net	$	11,170		$	8,809

Amortization expense was approximately $2.3 million for the year ended December 31, 2013. There was no amortization expense during 2012. Expected future amortization expense for each of the next five years and thereafter is as follows (in thousands):

Year Ended	Amount
2014	$	3,571
2015		2,471
2016		2,151
2017		908
2018		258
Thereafter		1,811
	$	11,170

During the year ended December 31, 2013 the changes in the carrying amount of goodwill for the year ended December 31, 2013 were as follows (in thousands):

Balance at beginning of period	$	7,756
Additions		13,613
Texadian purchase price adjustments		(766	)
Balance at end of period	$	20,603

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Inventories (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Crude oil and feedstocks	$ 137,706
Refined products and blend stock	229,086
Spare parts, materials and supplies, and merchandise	13,831
Inventory, Net, Total	380,623	10,466
Titled Inventory [Member]
Crude oil and feedstocks	0	10,466
Refined products and blend stock	67,532	0
Spare parts, materials and supplies, and merchandise	13,831	0
Inventory, Net, Total	81,363	10,466
Supply and Exchange Agreements [Member]
Crude oil and feedstocks	137,706
Refined products and blend stock	161,554
Spare parts, materials and supplies, and merchandise	0
Inventory, Net, Total	$ 299,260

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Fair Value Measurements (Details 8) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, Carrying Value	$ 94,030		$ 7,391
Warrants, Carrying Value	17,336		10,945
Debt repayment derivative, Carrying Value			45
Contingent consideration liability, Carrying Value	11,980
Long-term Debt, Fair Value			10,900	[1]
Warrants, Fair Value	17,336	[1]	10,900	[1]
Debt repayment derivative, Fair Value			45	[1]
Contingent consideration liability, Fair Value	11,980	[1]
Tranche B [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit, Noncurrent	19,480
Lines of Credit, Fair Value Disclosure	18,800	[1]
ABL Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit, Noncurrent	51,800		0
Lines of Credit, Fair Value Disclosure	51,800	[1]
HIE Retail Credit Agreement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit, Noncurrent	26,000
Lines of Credit, Fair Value Disclosure	$ 26,000	[1]

[1] The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.

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Intangible assets (Textual) (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
Amortization of Intangible Assets	$ 2.3	$ 0

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Segment Information (Details) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Sales and operating revenues	$ 2,144	$ 886,014
Depreciation, depletion, amortization and accretion	401	5,982
Operating income (loss)	(5,021)	(47,865)
Loss from unconsolidated affiliate		(2,941)
Interest expense and financing costs, net	(1,056)	(19,471)
Other income (expense)	86	808
Change in value of common stock warrants	(4,280)	(10,114)
Gain on derivative instruments	0	410
Loss before income taxes	(11,596)	(79,173)
Income tax benefit	(2,757)	0
Net loss	(8,839)	(79,173)
Capital expenditures, including acquisitions	17,854	567,047
Refining Distribution and Marketing [Member]
Sales and operating revenues		778,126
Depreciation, depletion, amortization and accretion		2,267
Operating income (loss)		(27,870)
Capital expenditures, including acquisitions		567,332
Natural Gas and Oil Operations [Member]
Sales and operating revenues		7,739
Depreciation, depletion, amortization and accretion		1,686
Operating income (loss)		246
Capital expenditures, including acquisitions	415	471
Commodity Marketing And Logistics [Member]
Sales and operating revenues		100,149
Depreciation, depletion, amortization and accretion		2,009
Operating income (loss)		9,126
Capital expenditures, including acquisitions	17,439	(1,300)
Corporate and Other [Member]
Sales and operating revenues		0
Depreciation, depletion, amortization and accretion		20
Operating income (loss)		(29,367)
Capital expenditures, including acquisitions	$ 0	$ 544

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Asset Retirement Obligations (Textual) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012
Asset Retirement Obligations [Line Items]
Asset Retirement Obligation	$ 3,172	$ 512	$ 476
Piceance Energy [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligation	$ 3,900

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Stockholders' Equity (Details) (Detail) (Long Term Incentive Plan, USD $)	12 Months Ended
	Dec. 31, 2013
Long Term Incentive Plan
Stock Awards, Shares
Non vested balance, beginning of period	219,000
Granted	356,000
Vested	(51,000)
Forfeited	0
Non vested balance, end of period	524,000
Available for grant	1,025,000
Stock Awards, Weighted-Average Grant Date Fair Value
Non vested balance, beginning of period	$ 12.00
Granted	$ 18.32
Vested	$ 12.00
Forfeited	$ 0
Non vested balance, end of period	$ 16.29

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Equity Method Investments Disclosure (Tables)

12 Months Ended

Dec. 31, 2013

Equity Method Investments

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

				September 1
	Year Ended			through
	December 31, 2013			December 31, 2012
Beginning balance	$	104,434		$	105,344
Loss from unconsolidated affiliates		(3,516	)		(1,325	)
Accretion of basis difference		575			—
Capitalized drilling costs obligation paid		303			415
Ending balance	$	101,796		$	104,434

Equity Method Investees Financial Information

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

	December 31, 2013			December 31, 2012
Assets
Current assets	$	5,901		$	6,275
Non-current assets		454,402			460,991
Current liabilities		(13,040	)		(11,826	)
Non-current liabilities		(96,738	)		(94,369	)

	Year Ended			September 1 through
	December 31, 2013			December 31, 2012
	100%			100%
Oil, natural gas and natural gas liquids revenues	$	61,091		$	19,391
Loss from operations		(6,765	)		(2,095	)
Net loss		(10,546	)		(3,975	)

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Summary of Effects of Error on Consolidated Financial Statements (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	4 Months Ended		12 Months Ended
	Dec. 31, 2012		Dec. 31, 2013
Trade accounts receivable	$ 17,730		$ 117,493
Inventories	10,466		380,623
Total current assets	59,926		544,501
Total assets	189,582		813,213
Obligations under supply and exchange agreements	0		385,519
Total current liabilities	69,977		453,388
Total liabilities	88,825		584,949
Accumulated deficit	(8,839)		(88,012)
Total stockholders' equity	100,757		228,264
Total liabilities and stockholders' equity	189,582		813,213
Cost of revenues	0		857,476
Total operating expenses	7,165		933,879
Operating loss	(5,021)		(47,865)
Loss before income taxes and reorganization items	(11,596)		(79,173)
Loss before reorganization items	(8,839)		(79,173)
Net loss	(8,839)		(79,173)
Basic loss per common share	$ (0.56)	[1]	$ (4.01)	[1]
Diluted loss per common share	$ (0.56)	[1]	$ (4.01)	[1]
Net loss	(8,839)		(79,173)
Trade accounts receivable	(2,234)		(40,278)
Inventories	0		48,593
Supply and exchange agreements	0		(18,381)
As Previously Reported [Member]
Trade accounts receivable			122,913
Inventories			389,075
Total current assets			558,373
Total assets			827,085
Obligations under supply and exchange agreements			390,839
Total current liabilities			458,708
Total liabilities			590,269
Accumulated deficit			(79,460)
Total stockholders' equity			236,816
Total liabilities and stockholders' equity			827,085
Cost of revenues			848,924
Total operating expenses			925,327
Operating loss			(39,313)
Loss before income taxes and reorganization items			(70,621)
Loss before reorganization items			(70,621)
Net loss			(70,621)
Basic loss per common share			$ (3.57)
Diluted loss per common share			$ (3.57)
Net loss			(70,621)
Trade accounts receivable			(45,698)
Inventories			40,141
Supply and exchange agreements			(13,061)
Adjustment [Member]
Trade accounts receivable			(5,420)
Inventories			(8,452)
Total current assets			(13,872)
Total assets			(13,872)
Obligations under supply and exchange agreements			(5,320)
Total current liabilities			(5,320)
Total liabilities			(5,320)
Accumulated deficit			(8,552)
Total stockholders' equity			(8,552)
Total liabilities and stockholders' equity			(13,872)
Cost of revenues			8,552
Total operating expenses			8,552
Operating loss			(8,552)
Loss before income taxes and reorganization items			(8,552)
Loss before reorganization items			(8,552)
Net loss			(8,552)
Basic loss per common share			$ (0.44)
Diluted loss per common share			$ (0.44)
Net loss			(8,552)
Trade accounts receivable			5,420
Inventories			8,452
Supply and exchange agreements			$ (5,320)

[1] Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2013

Commitments and Contingencies

Note 13 - Commitments and Contingencies

Environmental Matters

Like other petroleum refiners and oil and gas 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. 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.

Regulation of Greenhouse Gases. The United States Environmental Protection Agency (“US EPA”) has begun regulating greenhouse gases under the Clean Air Act Amendments of 1990 (the “Clean Air Act”). New construction or material expansions that meet certain greenhouse gas emissions thresholds will likely require that, among other things, a greenhouse gas permit be issued in accordance with the Clean Air Act 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 greenhouse gas emissions.

Furthermore, the US EPA is currently developing refinery-specific greenhouse gas regulations and performance standards that are expected to impose, on new and modified operations, greenhouse gas 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 cost of the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity.

In 2007, the State of Hawaii passed Act 234, which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed, the Hawaii Department of Health (“DOH”) 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 greenhouse gas emissions were reported to the US EPA under 40 CFR Part 98). Those rules are pending final approval by the Government of Hawaii. The refinery’s capacity to reduce fuel use and greenhouse gas emissions is limited. However, the state’s pending regulation allows, and the refinery should be able to demonstrate, that additional reductions are not cost-effective or necessary in light of the state’s current greenhouse gas inventory and future year projection. The pending regulation allows for “partnering” with other facilities (principally power plants) which 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 (“EISA”) which, 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 United States by model year 2020, and contained a second Renewable Fuel Standard (the “RFS2”). In August 2012, the US 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 36.0 billion gallons by 2022. In the near term, the RSF2 will be satisfied primarily with fuel ethanol blended into gasoline. The RSF2 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 US 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 Clean Air Act 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 US EPA issued a second waiver for the use of E15 in vehicles model year 2001-2006. There are numerous issues, including state and federal regulatory issues, which need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines. Since April 2006, the State of Hawaii has required that a minimum of 9.2% ethanol be blended into at least 85% of the gasoline pool, but the regulation also limited the amount of ethanol to no more than 10%. Consequently, unless either the state or federal regulations are revised, qualified Renewable Identification Numbers (“RINS”) will be required to fulfill the federal mandate for renewable fuels.

In March 2014, the US EPA published a final Tier 3 gasoline standard that lowers the allowable sulfur level in gasoline to 10 ppm and also lowers the allowable benzene, aromatics and olefins content of gasoline. The effective date for the new standard, January 1, 2017, gives refiners nation-wide little time to engineer, permit and implement substantial modifications. Along with credit and trading options, potential capital upgrades for the refinery are being evaluated. The American Petroleum Institute and American Fuel and Petrochemical Association may challenge the final regulation.

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. We may 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 (the “Closing Date”), Hawaii Pacific Energy (a wholly-owned subsidiary of Par created for purposes of the Tesoro Acquisition), Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities related to the acquisition of HIE, including the Consent Decree as described below.

Consent Decree. Tesoro is currently negotiating a consent decree with the US EPA and the United States Department of Justice concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (the “Consent Decree”), including the Hawaii refinery. It is anticipated that the Consent Decree will be finalized sometime during 2014 and will require certain capital improvements to our refinery to reduce emissions of air pollutants.

It is not possible at this time to estimate the cost of compliance with the ultimate decree. However, Tesoro is responsible under the Environmental Agreement for reimbursing HIE for all reasonable third party capital expenditures incurred for the construction, installation and commissioning of such capital projects and for the payment of any fines or penalties imposed on HIE arising from the Consent Decree to the extent related to acts or omission of Tesoro or HIE prior to the Closing Date. Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, the obligation relating to fines and penalties terminates on the third anniversary of the Closing Date.

Tank Replacements. Tesoro has agreed, at its expense, to replace the existing underground storage tanks at certain retail assets.

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 Environment 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 Closing Date, any fine, penalty or other cost assessed by a governmental authority in connection with violations of environmental laws by HIE prior to the Closing Date, certain groundwater remediation work, the replacement of underground storage tanks located at certain retail assets, fines or penalties imposed on HIE by the Consent Decree related to acts or omissions of Tesoro prior to the Closing Date and 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 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.

Helicopter Litigation.

HIE is the defendant in a lawsuit styled State of Hawaii Department of Transportation Airports Division et al. v. Tesoro Hawaii, Civil No. 09-2253-09 JHC. In this matter, the insurance company for the State of Hawaii is seeking reimbursement of the attorney’s fees and costs incurred by outside council to defend against Tesoro Hawaii’s third-party complaints for contribution in three previously-settled underlying litigation matters. The underlying litigation was filed by three helicopter tour operators flying on the Island of Kauau. The helicopter tour operators allege bad jet fuel caused the formation of coking deposits in their engines which resulted in millions of dollars of repair costs and lost income. There were no in-flight issues.

Tesoro Hawaii filed third-party complaints against the State of Hawaii in each of the three underlying lawsuits alleging that any fuel issues arose from improper design and maintenance of the underground pipeline and dispensers owned and maintained by the State of Hawaii. The helicopter operators settled with the State of Hawaii, and Tesoro Hawaii and its aviation liability insurers subsequently settled with the helicopter operators.

The lawsuit alleges that the State of Hawaii was entitled to a defense and indemnity under the terms of its lease for the Tesoro Hawaii facility at the Lihue airport. The suit alleges defense costs of approximately $2 million in the underlying lawsuits. The State of Hawaii and its insurance company have since demanded $3.25 million. The issue at trial is ultimately whether Tesoro Hawaii owed a contractual duty to pay for the State of Hawaii’s defense against Tesoro Hawaii’s third-party complaints against the State of Hawaii for the State’s own negligence. The case is set for a bench trial in September 2014.

There is a companion lawsuit by the State of Hawaii and its insurance company against Tesoro Hawaii’s former liability insurer on the same issues. The Court previously held by way of a Motion for Summary Judgment that Tesoro Hawaii’s insurer had a duty to defend the State of Hawaii against Tesoro Hawaii’s third-party complaints. That matter is going to trial in July 2014 on the issue of damages only (e.g. the reasonable amount of attorney’s fees and costs the State of Hawaii is entitled to for the defense of the third-Party Complaints in the underlying lawsuits).

We do not believe that any loss relating to this litigation is probable. However, should any loss become probable before the end of the measurement period, such loss would be reflected as a purchase price adjustment relating to the HIE Acquisition.

Recovery Trusts

On the date we emerged from bankruptcy, or the Emergence Date, two trusts were formed; the Wapiti Recovery Trust (the “Wapiti Trust”) and the Delta Petroleum General Recovery Trust (the “General Trust,” and together with the Wapiti Trust, the “Recovery Trusts”). The Recovery Trusts were formed to pursue certain litigation against third-parties or causes of action under the U.S. Bankruptcy Code, and other claims and potential claims that the Debtors hold against third parties. The Recovery Trusts were funded with $1.0 million each pursuant to the Plan.

In September 2012, the Wapiti Trust settled all causes of action against Wapiti Oil & Gas, LLC (“Wapiti Oil & Gas”). Wapiti Oil & Gas made a one-time cash payment in the amount of $1.5 million to the Wapiti Trust, as consideration for the release of claims against it. These proceeds were then distributed to us, along with funds remaining from the initial funding of the Wapiti Trust of approximately $1.0 million. The Wapiti Trust was liquidated during 2013.

The General Trust is pursuing all bankruptcy causes of action not otherwise vested in the Wapiti Trust, claim objections and resolutions, and all other responsibilities for winding-up the bankruptcy. The General Trust is overseen by a three person General Trust Oversight Board and our Chief Legal Officer is currently the trustee (the “Recovery Trustee”). Costs, expenses and obligations incurred by the General Trust are charged against assets in the General Trust. To conduct its operations and fulfill its responsibilities under the Plan and the trust agreements, the Recovery Trustee may request additional funding from us. Any litigation pending at the time we emerged from Chapter 11 was transferred to the General Trust for resolution and settlement in accordance with the Plan and the order confirming the Plan. We are the beneficiary of the General Trust, subject to the terms of the trust agreement and the Plan. Since the Emergence Date, the General Trust has filed various claims and causes of action against third parties before the Bankruptcy Court, which actions are ongoing. Upon liquidation of the various claims and causes of action held by the General Trust, the proceeds, less certain administrative reserves and expenses, will be transferred to us. It is unknown at this time what proceeds, if any, we will realize from the General Trust’s litigation efforts.

From the Emergence Date through December 31, 2013, the Recovery Trusts have released approximately $5.2 million to us, which is available for our general use, due to a negotiated reduction in certain fees and claims associated with the bankruptcy, as well as a favorable variance in actual expenses versus budgeted expenses. The entire $5.2 million was released prior to December 31, 2012.

Shares Reserved for Unsecured Claims

The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. On the Emergence Date, 112 claims totaling approximately $73.7 million had been filed in the bankruptcy. Pursuant to the Plan, between the Emergence Date and December 31, 2012, the Recovery Trustee settled 25 claims with an aggregate face amount of $6.6 million for approximately $259 thousand in cash and 20,275 shares of common stock. Pursuant to the Plan, during the year ended December 31, 2013, the Recovery Trustee settled an additional 59 claims with an aggregate face amount of $26.9 million for approximately $5.4 million in cash and 208,460 shares of common stock.

As of December 31, 2013, it is estimated that a total of 28 claims totaling approximately $40.2 million remain to be resolved by the Recovery Trustee. The largest remaining proof of claim was filed by the US 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. 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 the Predecessor company owned a 2.41934% 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. At December 31, 2013 and 2012, we have reserved approximately $3.8 million and $8.7 million, respectively, representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end. A summary of claims is as follows (in thousands, except number of filed claims):

	Emergence-Date August 31, 2012				From Emergence-Date through December 31, 2012
	Filed Claims				Settled Claims								Remaining Filed Claims
									Consideration
	Count		Amount		Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		3	$	22,364		—	$	—	$	—		—		3	$	22,364
Former Employee Claims		32		16,380		13		3,685		230		20		19		12,695
Macquarie Capital (USA) Inc.		1		8,672		—		—		—		—		1		8,672
Swann and BuzzardCreek RoyaltyTrust		1		3,200		—		—		—		—		1		3,200
Other Various Claims*		75		23,114		12		2,915		29		—		63		20,199
Total		112	$	73,730		25	$	6,600	$	259		20		87	$	67,130

	For the Year Ended December 31, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364
Former Employee Claims		19		12,695		340		162		—		—
Macquarie Capital (USA) Inc.		1		8,672		2,500		—		—		—
Swann and Buzzard Creek Royalty Trust		1		3,200		2,000		—		—		—
Other Various Claims(1)		37		2,339		543		47		26		17,860
Total		59	$	26,906	$	5,383		209		28	$	40,224

(1) Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Capital Leases

Within our refining, distribution and marketing segment, we have capital lease obligations related primarily to the leases of five retail stations with initial terms of 17 years, with four 5-year renewal options. Minimum annual lease payments including interest, for capital leases are as follows (in thousands):

2014	$	382
2015		382
2016		382
2017		382
2018		420
Thereafter		420
Total minimum lease payments		2,368
Less amount representing interest		634
Total minimum rental payments	$	1,734

Operating Leases

Within our refining, distribution and marketing segment, we have various cancellable and noncancellable operating leases related to land, vehicles, office and retail facilities and other facilities used in the storage, transportation and sale of crude oil and refined products. The majority of the future lease payments relate to retail stations and facilities used in the storage, transportation and sale of crude oil and refined products. We have operating leases for most of our retail stations with primary terms of up to 32 years, and generally containing renewal options and escalation clauses. Leases for facilities used in the storage, transportation and sale of crude oil and refined products have various expiration dates extending to 2027.

In addition, with our commodity marketing and logistics segment, we have various agreements to lease storage facilities, primarily along the Mississippi River, railcars, inland river tank barges and towboats and other equipment. These leasing agreements have been classified as operating leases for financial reporting purposes and the related rental fees are charged to expense over the lease term as they become payable. The leases generally range in duration of five years or less and contain lease renewal options at fair value. Our railcar leases contain an empty mileage indemnification provision whereby if the empty mileage exceeds the loaded mileage, we are charged for the empty mileage at the rate established by the tariff of the railroad on which the empty miles accrued.

Minimum annual lease payments extending to 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):

2014	$	22,724
2015		13,277
2016		12,362
2017		10,375
2018		9,244
Thereafter		25,614
Total minimum rental payments	$	93,596

Rent expense for the year ended December 31, 2013 and for the period from September 1, 2012 through December 31, 2012 was approximately $6.2 million and $61 thousand, respectively.

Major Customers

For the year ended December 31, 2013, no individual customer accounted for more than 10% of our consolidated revenue. For the period September 1, 2012 to December 31, 2012, we had one customer that accounted for 96% of our total oil and natural gas sales. During the period from January 1, 2012 to August 31, 2012, our Predecessor had two customers that accounted individually for 59% and 24%, respectively, of its total oil and natural gas sales.

Other

On April 22, 2013, Texadian entered into a terminaling and storage agreement whereby the operator will provide Texadian with storage facilities, access to a marine terminal and pipelines, and railcar offloading services. The initial term of the agreement is for a period of four years and Texadian’s minimum commitment during the initial term is approximately $28 million.

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Information Regarding Proved Oil and Gas Reserves (Details 2) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012 Company [Member]	Dec. 31, 2013 Company [Member]	Dec. 31, 2012 Company's Share of Piceance Energy [Member]	Dec. 31, 2013 Company's Share of Piceance Energy [Member]	Aug. 31, 2012 Predecessor [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Beginning of the period	$ 7,223	$ 79,969	$ 7,223	$ 8,010	$ 0	$ 71,959	$ 129,695
Transfer from investees	55,253		0		55,253		0
Sales of oil and gas production during the period, net of production costs	(4,095)	(12,522)	(456)	(2,044)	(3,639)	(10,478)	(5,954)
Net change in prices and production costs	(806)	(6,421)	(667)	(3,833)	(139)	(2,588)	378
Changes in estimated future development costs	5	8,831	0		5	8,831	0
Extensions, discoveries and improved recovery	1,332	15,618	763	147	569	15,471
Revisions of previous quantity estimates, estimated timing of development and other	14,356	(4,553)	648	395	13,708	(4,948)	(7,439)
Sales/disposition of reserves in place	0		0		0		(118,104)
Previously estimated development and abandonment costs incurred during the period		3,142				3,142
Other	4,618	801	258	61	4,360	740	0
Accretion of discount	2,083	7,997	241	801	1,842	7,196	8,647
End of period	$ 79,969	$ 92,862	$ 8,010	$ 3,537	$ 71,959	$ 89,325	$ 7,223

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Related Party Transactions

12 Months Ended

Dec. 31, 2013

Related Party Transactions

Note 18 - Related Party Transactions

Certain of our stockholders who are lenders under the Loan Agreement received Warrants exercisable for shares of common stock in connection with such loan (see Note 10 - Debt).

Certain of our stockholders and their affiliates who are owners of 10% or more of our common shares participated in the Stock Sale (see Note 14 - Stockholders’ Equity).

On September 17, 2013, we entered into letter agreements (the “Services Agreements”) with Equity Group Investments, an affiliate of ZCOF (“EGI”), and Whitebox. Pursuant to the Services Agreements, EGI and Whitebox 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 and Whitebox will not receive a fee for the provision of the strategic, advisory or consulting services set forth in the Services Agreements, 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 or Whitebox, as applicable, 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 or Whitebox’s, as applicable, services under the Services Agreements. In consideration of the services provided by EGI and Whitebox under the Services Agreements, we agreed to indemnity each of them for certain losses incurred by them relating to or arising out of the Services Agreements or the services provided thereunder.

The Services Agreements have 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 2013.

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Income Taxes (Textual) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013
Income Taxes [Line Items]
Reduction in operating loss	$ 225,000,000
Net operating loss carryovers	1,300,000,000
Capital Loss carryovers	74,700,000
Alternative minimum tax credit carryovers	$ 800,000
Minimum [Member]
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2027
Capital Loss carryovers, expiry year	2015
Maximum [Member]
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2032
Capital Loss carryovers, expiry year	2016

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Information Regarding Proved Oil and Gas Reserves (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities

A summary of changes in estimated quantities of proved reserves for the year ended December 31, 2013 and for respective periods in 2012 is as follows:

	Gas (MMcf)			Oil (MBbl)			NGLS (MBb1)			Total (MMcfe)(5)
Company:
Estimated Proved Reserves: Balance at January 1, 2012 (Predecessor)(1)		87,209			494			—			90,173
Revisions of quantity estimate		—			85			—			512
Sale/disposition of properties(2)		(82,357	)		(235	)		—			(83,770	)
Production		(4,852	)		(67	)		—			(5,256	)
Estimated Proved Reserves: Balance at August 31, 2012 (Successor)		—			277			—			1,659
Revisions of quantity estimate		456			31			—			643
Production		(10	)		(22	)		—			(139	)
Estimated Proved Reserves: Balance at December 31, 2012 (Successor)		446			286			—			2,163
Revisions of quantity estimate		460			16			—			557
Extensions and discoveries		9			3			—			25
Production		(253	)		(69	)		—			(667	)
Estimated Proved Reserves: Balance at December 31, 2013 (Successor)		662			236			—			2,078
Company’s Share of Piceance Energy:
Estimated Proved Reserves: Balance at September 1, 2012		—			—			—			—
Transfer from investees(3)		83,915			560			4,228			112,639
Revisions of quantity estimate		8,053			41			387			10,621
Extensions and discoveries		32,073			236			1,778			44,151
Production		(1,391	)		(6	)		(48	)		(1,711	)
Estimated Proved Reserves: Balance at December 31, 2012		122,650			831			6,345			165,700
Revisions of quantity estimate		72,436			174			2,818			90,387
Extensions and discoveries		3,599			(374	)		(1,334	)		(6,643	)
Production		(12,088	)		(47	)		(428	)		(14,935	)
Estimated Proved Reserves: Balance at December 31, 2013		186,597			584			7,401			234,509
Total Estimated Proved Reserves: Balance at December 31, 2013		187,259			820			7,401			236,587
Proved developed reserves
December 31, 2012		158			286			—			1,875
December 31, 2012 - Company Share of Piceance Energy		48,680			237			2,253			63,617
Total December 31, 2012		48,838			523			2,253			65,492
Proved undeveloped reserves
December 31, 2012		288			—			—			288
December 31, 2012 - Company Share of Piceance Energy		73,970			594			4,092			102,083
Total December 31, 2012		74,258			594			4,092			102,371
Proved developed reserves
December 31, 2013		662			236			—			2,078
December 31, 2013 - Company Share of Piceance Energy		45,072			165			1,627			55,829
Total December 31, 2013		45,734			401			1,627			57,907
Proved undeveloped reserves
December 31, 2013		—			—			—			—
December 31, 2013 - Company Share of Piceance Energy		141,525			419			5,774			178,680
Total December 31, 2013		141,525			419			5,774			178,680

	CIG per Mbtu		WTI per Bbl
Base pricing, before adjustments for contractual differentials:(4)
August 31, 2012	$	2.75	$	90.85
December 31, 2012	$	2.56	$	91.21
December 31, 2012 - Piceance	$	2.56	$	91.21
December 31, 2013	$	3.53	$	96.91
December 31, 2013 - Piceance	$	3.53	$	96.91

⁽¹⁾  At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.

⁽²⁾  On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).

⁽³⁾  On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).

⁽⁴⁾  Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.

⁽⁵⁾  MMcfe is based on a ratio of 6 Mcf to 1 barrel.

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure

Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests.

	Successor						Predecessor
	December 31,						August 31,
	2013			2012			2012
	(in thousands)						(in thousands)
Company:
Future net cash flows	$	26,861		$	30,444		$	28,691
Future costs:
Production		21,999			20,596			19,973
Development and abandonment		319			319			319
Income taxes1		—			—			—
Future net cash flows		4,543			9,529			8,399
10% discount factor		(1,006	)		(1,519	)		(1,176	)
Standardized measure of discounted future net cash flows	$	3,537		$	8,010		$	7,223
Company’s Share of Piceance Energy:
Future net cash flows	$	984,205		$	568,706
Future costs:
Production		430,506			199,277
Development and abandonment		234,905			154,054
Income taxes1		—			—
Future net cash flows		318,794			215,375
10% discount factor		(229,469	)		(143,416	)
Standardized measure of discounted future net cash flows	$	89,325		$	71,959
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues	$	92,862		$	79,969

¹  No income tax provision is included in the standardized measure calculation shown above as the company does not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows

The principal sources of changes in the standardized measure of discounted net cash flows for the year ended December 31, 2013 and for the respective periods during 2012 are as follows (in thousands):

	Successor
	December 31,			Company Share of Piceance Energy December 31,			Total
	2013			2013			2013
Beginning of the year
Beginning of the period	$	8,010		$	71,959		$	79,969
Sales of oil and gas production during the period, net of production costs		(2,044	)		(10,478	)		(12,522	)
Net change in prices and production costs		(3,833	)		(2,588	)		(6,421	)
Changes in estimated future development costs		—			8,831			8,831
Extensions, discoveries and improved recovery		147			15,471			15,618
Revisions of previous quantity estimates, estimated timing of development and other		395			(4,948	)		(4,553	)
Previously estimated development and abandonment costs incurred during the period		—			3,142			3,142
Other		61			740			801
Accretion of discount		801			7,196			7,997
End of period	$	3,537		$	89,325		$	92,862

	Successor									Predecessor
	Period from September 1, through December 31,			Company Share of Piceance Energy September 1, through December 31,			Total			January 1, through August 31,
	2012			2012			2012			2012
Beginning of the year										$	129,695
Beginning of the period	$	7,223		$	—		$	7,223			—
Transfer from investees		—			55,253			55,253			—
Sales of oil and gas production during the period, net of production costs		(456	)		(3,639	)		(4,095	)		(5,954	)
Net change in prices and production costs		(667	)		(139	)		(806	)		378
Changes in estimated future development costs		—			5			5			—
Extensions, discoveries and improved recovery		763			569			1,332			—
Revisions of previous quantity estimates, estimated timing of development and other		648			13,708			14,356			(7,439	)
Sales/disposition of reserves in place		—			—			—			(118,104	)
Other		258			4,360			4,618			—
Accretion of discount		241			1,842			2,083			8,647
End of period	$	8,010		$	71,959		$	79,969		$	7,223

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Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Details Textual) (Detail) (USD $)	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2012	Aug. 31, 2012	Dec. 31, 2013
Reorganization [Line Items]
Fresh Start Adjustments Pretax Loss		$ 14,800,000
Common Stock Shares Issued	15,008,092		30,151,000
Class Of Warrant Or Right Number Of Securities Called By Warrants Or Rights			959,213
Share Price	$ 12.00		$ 22.30
Gains Losses On Extinguishment Of Debt	0		0
Settlement Of Other Claims [Member]
Reorganization [Line Items]
Common Stock Shares Issued		191,973
Share Price		$ 7.00
Gains Losses On Extinguishment Of Debt		2,200,000
Secured Debt [Member]
Reorganization [Line Items]
Common Stock Shares Issued		14,573,608
Class Of Warrant Or Right Number Of Securities Called By Warrants Or Rights		959,213
Share Price		$ 7.00
Gains Losses On Extinguishment Of Debt		166,100,000
Reorganized Delta Petroleum [Member]
Reorganization [Line Items]
Line Of Credit Facility Amount Outstanding		13,000,000
Piceance Energy [Member]
Reorganization [Line Items]
Line Of Credit Facility Amount Outstanding		100,000,000	90,200,000
Equity Method investment ownership percentage		33.34%	33.34%
Equity Method Investments Fair Value Disclosure		105,300,000
Piceance Energy [Member] | Reorganized Delta Petroleum [Member]
Reorganization [Line Items]
Debtor In Possession Financing Amount Arranged		72,600,000
Equity Method investment ownership percentage		33.34%
Piceance Energy [Member] | Laramie [Member]
Reorganization [Line Items]
Debtor In Possession Financing Amount Arranged		$ 24,900,000
Equity Method investment ownership percentage		66.66%

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2013

Fair Value Measurements, Nonrecurring

The estimates of fair value of the net assets were reflected in the Successor’s consolidated balance sheet as of August 31, 2012.

	Fair Value at August 31, 2012		Fair Value Technique
	(in thousands)
Oil and gas properties
Proved	$	4,587		(a)(b)
Other assets
Frac tanks		1,400		(c)
Compressors		2,800		(c)
Miscellaneous		39		(d)
Investment in Piceance Energy		105,344		(e)

(a) Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.

(b) The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.

(c) The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.

(d) Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.

(e) The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves’ future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions

Significant inputs used in the Monte Carlo Simulation Analysis include:

	December 31,
	2013			2012
Stock price	$	22.30		$	12.00
Initial exercise price	$	0.1		$	0.1
Term (years)		8.67			9.67
Risk-free rate		2.78	%		1.68	%
Expected volatility		52.9	%		75.0	%

Fair Value, Assets Measured on Recurring Basis

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their placement with our consolidated balance sheet consist of the following (in thousands):

	Location on Consolidated Balance Sheet	Fair Value at December 31, 2013			Fair Value at December 31, 2012
Commodities - physical forward contracts	Prepaid and other current assets	$	—		$	(307	)
Commodities - exchange traded futures	Prepaid and other current assets		—			542
Warrant derivatives	Derivative liabilities		(17,336	)		(10,900	)
Contingent consideration liability	Contingent consideration liability		(11,980	)		—
Debt repayment derivative	Derivative liabilities		—			(45	)

Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location

The following table summarizes the pre-tax effect resulting from changes in fair value of derivative instruments charged directly to earnings (in thousands):

		December 31, 2013			September 1 through December 31, 2012
	Income Statement Classification	Gain (loss) recognized in income			Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Change in value of warrants	$	(10,114	)	$	(4,280	)
Debt repayment derivative	Interest expense and financing costs, net		45			—
Commodities - exchange traded futures	Gain on derivative instruments, net		104			—
Commodities - physical forward contracts	Gain on derivative instruments, net		306			—

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their level within the fair value hierarchy is as follows (in thousands):

	December 31, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Warrants derivative	$	(17,336	)	$	—	$	—	$	(17,336	)
Contingent consideration liability		(11,980	)		—		—		(11,980	)
	$	(29,316	)	$	—	$	—	$	(29,316	)

	December 31, 2012
	Fair Value			Level 1		Level 2			Level 3
Assets
Commodities - exchange traded futures	$	542		$	542	$	—		$	—
Liabilities
Warrants derivative	$	(10,900	)	$	—	$	—		$	(10,900	)
Debt prepayment derivative		(45	)		—		—			(45	)
Commodities - physical forward contracts		(307	)		—		(307	)		—
	$	(11,252	)	$	—	$	(307	)	$	(10,945	)

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

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

Description	2013			2012
Balance, at beginning of period	$	(10,945	)	$	(6,665	)
Settlements		3,723			—
Acquired		(11,980	)		—
Total unrealized losses included in earnings		(10,114	)		(4,280	)
Transfers		—			—
Balance, at end of period	$	(29,316	)	$	(10,945	)

Fair Value and Carrying Value Liabilities Measured On Recurring Basis

The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2013 and 2012 is as follows (in thousands):

	December 31, 2013
	Carrying Value		Fair Value(1)
Tranche B	$	19,480	$	18,800
ABL Facility		51,800		51,800
HIE Retail Credit Agreement		26,000		26,000
Warrants		17,336		17,336
Contingent consideration liability		11,980		11,980

	December 31, 2012
	Carrying Value		Fair Value(1)
Long-term debt	$	7,391	$	10,900
Warrants		10,900		10,900
Debt repayment derivative		45		45

⁽¹⁾ The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.

Texadian Energy Inc [Member]

Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques

The fair values of the assets acquired and liabilities assumed as a result of the Texadian acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (f) described below.

	Fair Value at December 31, 2012			Fair Value Technique
	(in thousands)
Net non-cash working capital	$	3,631			(a)
Supplier relationship		3,360			(b)
Historical shipper status		2,200			(c)
Railcar leases		3,249			(d)
Goodwill		7,756			(e)
Deferred tax liabilities		(2,757	)		(f)
	$	17,439

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

Hie Retail Llc [Member]

Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques

The preliminary fair values of the assets acquired and liabilities assumed as a result of the HIE acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (g) described below.

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,059			(a)
Property, plant and equipment		58,782			(b)
Land		39,800			(c)
Trade names and trade marks		4,689			(d)
Goodwill		13,613			(e)
Contingent consideration liability		(11,980	)		(f)
Other noncurrent liabilities		(6,384	)		(g)
	$	560,579

(a) Current assets acquired and liabilities assumed were recorded at their net realizable value.

(b) The estimated fair value of the property, plant and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and external obsolescence. We consider this to be a Level 3 fair value measurement.

(c) The estimated fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement.

(d) The estimated fair value of the trade names and trademarks was estimated using a form of the income approach, the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.

(e) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.

(f) The estimated fair value of the liability for contingent consideration was estimated using Monte Carlo Simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.

(g) Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.

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Subsequent Events (Details Textual) (Detail) (USD $)			1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Jan. 23, 2014 Subsequent Event [Member]
Subsequent Event [Line Items]
Common Stock Shares Authorized	500,000,000	300,000,000
Common stock, shares issued	30,151,000	15,008,092	301,141,520
Common Stock Par Or Stated Value Per Share	$ 0.01	$ 0.01
Stockholders Equity, Reverse Stock Split			1:10 reverse stock split

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CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (USD $) In Thousands, except Share data	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Predecessor [Member]	Predecessor [Member] Common Stock [Member]	Predecessor [Member] Additional Paid-in Capital [Member]	Predecessor [Member] Retained Earnings [Member]
Balance at Dec. 31, 2011					$ 50,225	$ 288	$ 1,641,390	$ (1,591,453)
Balance (in shares) at Dec. 31, 2011						28,841,000
Cancellation of predecessor common stock	0	(288)	288	0
Cancellation of predecessor common stock (in shares)		(28,783,000)
Stock issued to settle bankruptcy claims					0
Elimination of predecessor accumulated deficit	0	0	(1,636,890)	1,636,890
Issuance of common stock and fresh start accounting upon emergence from Chapter 11	102,879	148	102,731	0
Issuance of common stock and fresh start accounting upon emergence from Chapter 11 (in shares)		14,766,000
Net loss					(45,437)	0	0	(45,437)
Forfeitures					0	0	0	0
Forfeitures (in shares)						(58,000)
Stock-based compensation					1,895	0	1,895	0
Balance at Aug. 31, 2012	109,562	148	109,414	0	6,683	288	1,643,285	(1,636,890)
Balance (in shares) at Aug. 31, 2012		14,766,000				28,783,000
Stock issued to settle bankruptcy claims	0	0	0	0
Stock issued to settle bankruptcy claims (in shares)		20,000
Stock-based compensation	34	2	32	0
Stock-based compensation (in shares)		222,000
Net loss	(8,839)	0	0	(8,839)
Balance at Dec. 31, 2012	100,757	150	109,446	(8,839)
Balance (in shares) at Dec. 31, 2012		15,008,000
Stock issued in a private transaction, net of offering cost of $830 (in shares)		14,388,000
Stock issued in a private transaction, net of offering cost of $830	199,170	144	199,026	0
Stock issued to settle bankruptcy claims	2,605	2	2,603	0
Stock issued to settle bankruptcy claims (in shares)		209,000
Stock issued through exercise of warrants	3,741	2	3,739	0
Stock issued through exercise of warrants (in shares)		184,000
Stock-based compensation	1,164	3	1,161	0
Stock-based compensation (in shares)		362,000
Net loss	(79,173)	0	0	(79,173)
Balance at Dec. 31, 2013	$ 228,264	$ 301	$ 315,975	$ (88,012)
Balance (in shares) at Dec. 31, 2013		30,151,000

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Commitments and Contingencies (Details) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended		8 Months Ended		12 Months Ended
	Dec. 31, 2012 Count		Aug. 31, 2012 Count		Dec. 31, 2013 Count
Commitment And Contingencies [Line Items]
Number of claims filed			112
Amount of claims filed			$ 73,730
Number of claim settled	25				59
Amount of claim settled	6,600				26,906
Amount of claim settled in cash	259				5,383
Amount of claim settled stock	20				209
Number of remaining claim to be resolved	87				28
Amount of remaining claim to be resolved	67,130				40,224
U S Government [Member]
Commitment And Contingencies [Line Items]
Number of claims filed			3
Amount of claims filed			22,364
Number of claim settled	0				1
Amount of claim settled	0				0
Amount of claim settled in cash	0				0
Amount of claim settled stock	0				0
Number of remaining claim to be resolved	3				2
Amount of remaining claim to be resolved	22,364				22,364
Former Employee Claims [Member]
Commitment And Contingencies [Line Items]
Number of claims filed			32
Amount of claims filed			16,380
Number of claim settled	13				19
Amount of claim settled	3,685				12,695
Amount of claim settled in cash	230				340
Amount of claim settled stock	20				162
Number of remaining claim to be resolved	19				0
Amount of remaining claim to be resolved	12,695				0
Macquarie Capital Incorporated [Member]
Commitment And Contingencies [Line Items]
Number of claims filed			1
Amount of claims filed			8,672
Number of claim settled	0				1
Amount of claim settled	0				8,672
Amount of claim settled in cash	0				2,500
Amount of claim settled stock	0				0
Number of remaining claim to be resolved	1				0
Amount of remaining claim to be resolved	8,672				0
Swann And BuzzardCreek RoyaltyTrust [Member]
Commitment And Contingencies [Line Items]
Number of claims filed			1
Amount of claims filed			3,200
Number of claim settled	0				1
Amount of claim settled	0				3,200
Amount of claim settled in cash	0				2,000
Amount of claim settled stock	0				0
Number of remaining claim to be resolved	1				0
Amount of remaining claim to be resolved	3,200				0
Other Various Claims [Member]
Commitment And Contingencies [Line Items]
Number of claims filed			75	[1]
Amount of claims filed			23,114	[1]
Number of claim settled	12	[1]			37	[1]
Amount of claim settled	2,915	[1]			2,339	[1]
Amount of claim settled in cash	29	[1]			543	[1]
Amount of claim settled stock	0	[1]			47	[1]
Number of remaining claim to be resolved	63	[1]			26	[1]
Amount of remaining claim to be resolved	$ 20,199	[1]			$ 17,860	[1]

[1] Includes reserve for contingent/unliquidated claims in the amount of $10 million.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2013

Summary of Significant Accounting Policies

Note 2 - Summary of Significant Accounting Policies

Principles of Consolidation and Basis of Presentation

The consolidated financial statements include the accounts of Par Petroleum Corporation and its consolidated subsidiaries. All inter-company balances and transactions have been eliminated in consolidation. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.

Our wholly-owned subsidiaries include Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”) which acquired all of the outstanding membership interests of HIE on September 25, 2013 (see Note 4 - Acquisitions and Dispositions), Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3 - Investment in Piceance Energy) and Texadian, which we acquired on December 31, 2012 (see Note 4 - Acquisitions and Dispositions). Certain amounts from prior periods have been reclassified to conform to the current presentation.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include fair value of assets and liabilities recorded in connection with the application of fresh-start reporting or acquisitions, natural gas and oil reserves, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, bad debts, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

Fresh-Start Reporting and the Effects of the Plan

Certain companies qualify for fresh-start reporting in connection with their emergence from bankruptcy. Fresh-start reporting is appropriate on the emergence from bankruptcy if the reorganization value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims, and if the holders of existing voting shares immediately before confirmation receive less than 50 percent of the voting shares of the emerging entity. We met these requirements on August 31, 2012 and adopted fresh-start reporting resulting in the creation of a new reporting entity.

The bankruptcy court issued a confirmation order approving our plan of reorganization (the “Plan”) on August 15, 2012 and we met the requirements of the Plan on August 31, 2012. Under the requirements of fresh-start reporting, we have adjusted our assets and liabilities to their estimated fair values as of August 31, 2012 in conformity with the guidance for the acquisition method of accounting for business combinations. The net effect of all fresh-start adjustments, including the effects of implementing the plan, resulted in a gain of approximately $154 million, which is reflected in the 2012 Predecessor Period. The application of the fresh-start reporting provisions created a new reporting entity having no retained earnings nor accumulated deficit.

Our fresh-start adjustments consisted primarily of (i) estimates of the fair value of our minority interest in Piceance Energy and (ii) of the fair value of our remaining existing fixed assets and liabilities. A description of the adjustments and amounts is provided in Note 19 - Reorganization under Chapter 11, Fresh-Start Reporting and the Effects of the Plan.

Cash and Cash Equivalents

Cash and cash equivalents consist of demand deposits and funds invested in highly liquid short-term investments with original maturities of three months or less.

Restricted Cash

Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to bankruptcy matters and cash held at commercial banks to support letter of credit facilities.

Allowance for Doubtful Accounts

We establish provisions for losses on trade receivables if it becomes probable we will not collect all or part of the outstanding balances. We review collectability and establish or adjust our allowance as necessary using the specific identification method. As of December 31, 2013 and 2012, we had no significant allowance for doubtful accounts.

Refined Product Exchanges

We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.

Inventories

Commodity inventories are stated at the lower of cost or market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 9 - Supply and Exchange Agreements. The crude oil remains in the legal title of Barclays and is stored in HIE’s storage tanks governed by a storage agreement. Legal title to the crude oil passes to HIE at the tank outlet. After processing, Barclays takes title to the refined products when the refined products enter the tanks which are then stored in HIE’s storage tanks until sold to HIE’s retail locations or to third parties. We record the inventory owned by Barclays on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties.

Investment in Unconsolidated Affiliate

We account for our investment in unconsolidated affiliate using the equity method as we have the ability to exert significant influence, but do not control the operating and financial policies. Our proportionate share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations. Investment in unconsolidated affiliate is reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

At December 31, 2013 and 2012, our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3 - Investment in Piceance Energy.)

Property, Plant and Equipment (Other than Natural Gas and Oil Properties)

We capitalize the cost of additions, major improvements and modifications to property, plant and equipment. The cost of repairs and normal maintenance of property, plant and equipment is expensed as incurred. Major improvements and modifications of property, plant and equipment are those expenditures that either extend the useful life, increase the capacity or improve the operating efficiency of the asset, or improve the safety of our operations. We compute depreciation of property, plant and equipment using the straight-line method, based on the estimated useful life of each asset as follows:

Assets	Lives in Years
Refining	8 to 47
Logistic	3 to 30
Retail	14 to 18
Corporate	3 to 7
Software	3

We record property under capital leases at the lower of the present value of minimum lease payments using our incremental borrowing rate or the fair value of the leased property at the date of lease inception. We depreciate leasehold improvements and property acquired under capital leases over the shorter of the lease term or the economic life of the asset.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include: a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset and a significant change in the asset’s physical condition or use.

Natural Gas and Oil Properties

We account for our natural gas and oil exploration and development activities using the successful efforts method of accounting. Under such method, costs of productive exploratory wells, development dry holes and productive wells and undeveloped leases are capitalized. Natural gas and oil lease acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological or geophysical expenses and delay rentals for natural gas and oil leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, then evaluated quarterly and charged to expense if and when the well is determined not to have found reserves in commercial quantities. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of producing properties.

Unproved properties with significant acquisition costs are assessed quarterly on a property-by-property basis and any impairment in value is charged to expense. If the unproved properties are determined to be productive, the related costs are transferred to proved oil and natural gas properties and are depleted. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain or loss until all costs have been recovered.

Depreciation, depletion and amortization of capitalized acquisition, exploration and development costs is computed using the units-of-production method by individual fields (common reservoirs) using proved producing natural gas and oil reserves as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based on total proved natural gas and oil reserves as the related reserves are produced.

Our natural gas and oil assets are reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.

Goodwill and Other Intangible Assets

Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a two-step quantitative test is required. If required, we will review the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment indicator exists and an estimate of the impairment loss is calculated.

Our intangible assets include relationships with suppliers and shippers, favorable railcar leases, trade names and trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist. When we believe impairment indicators may exist, projections of the undiscounted future cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values.

Asset Retirement Obligations

We record asset retirement obligations (“AROs”) in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the liability. Our AROs arise from our refining, distribution and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and oil operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in depreciation, depletion and amortization expense on our consolidated statement of operations and the related capitalized cost is depreciated over the asset’s useful life. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments in our statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, management’s intent and estimated economic lives.

We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos), and removal or dismantlement requirements associated with the closure of our refining facility, terminal facilities or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines or other equipment.

Environmental Matters

We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and environmental expenses are recorded in operating expenses in our consolidated statements of operations.

Derivatives and Other Financial instruments

We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange traded futures contracts, collar agreements, swaps or options. The purpose of the transactions is to provide a measure of stability to our cash flows in an environment of volatile commodity prices.

Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle. Should we not designate a contract as a normal purchase or normal sale then the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. As of December 31, 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.

In addition, from time to time we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.

As a part of the Plan of Reorganization, we issued warrants (see Note 10 - Debt) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in change in value of common stock warrants and loss on derivative instruments, net respectively, on our consolidated statement of operations.

Accrued Settlement Claims

We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy (See Note 13 - Commitments and Contingencies). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.

Income Taxes

We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard, and to the extent this threshold is not met, a valuation allowance is recorded.

We recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2010, 2011, and 2012. However, since we have net operating loss carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.

Stock Based Compensation

We recognize the cost of share-based payments over the period the employee provides service, generally the vesting period, and include such costs in general and administrative expense in the consolidated statements of operations. The fair value of equity instruments issued to employees is measured on the grant date and recognized over the service period on a straight-line basis.

Revenue Recognition

We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met. These transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.

Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2013 and 2012, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of rail cars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the purchaser, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.

Refining, Distribution and Marketing. We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title and risk of loss is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We include transportation fees charged to customers in revenues in our statements of consolidated operations, while the related transportation costs are included in cost of sales. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.

Loss Per Share

Basic loss per share (“EPS”) is computed by dividing net loss by the sum of the weighted average number of common shares outstanding, and the weighted average number of shares issuable under the Warrants (see Note 16 - Loss Per Share). The Warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation of basic EPS as these shares are not considered earned until vesting occurs.

Foreign Currency Transactions

We may, on occasion, enter into transactions denominated in currencies other than our functional currency (“U.S. $”). Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in other income (expense) in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.

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Acquisitions and Dispositions (Details Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended		8 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013 Assets Held-for-sale [Member]	Aug. 31, 2012 Piceance Energy [Member]	Dec. 31, 2012 Texadian Energy Inc [Member]	Dec. 31, 2013 Hawaii Independent Energy LLC [Member]
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross					$ 14,000,000	$ 75,000,000
Business acquisition purchase price allocation working capital					3,000,000
Business Combination, Separately Recognized Transactions, Additional Disclosures, Acquisition Costs					17,000,000
Business Combination, Consideration Transferred, funds received from subsidiary		1,300,000
Business Combination, Acquisition Related Costs					556,000	7,000,000
Payments To Acquire Businesses Net Of Cash Acquired	17,439,000	559,279,000				40,000,000
Significant Acquisitions and Disposals, Terms						The earnout payments, if any, are to be paid annually following each of the three calendar years beginning January 1, 2014 through the year ending December 31, 2016, in an amount equal to 20% of the consolidated annual gross margin of HIE in excess of $165 million during such calendar years, with an annual cap of $20 million
Business Combination, funded for overhaul of co-generation turbine						24,300,000
Funding Of Acquisition From Supply And Exchange Agreements	0	378,238,000				378,200,000
Debtor Reorganization Items, Impairment Loss				151,300,000
Proceeds from Sale of Productive Assets, Total			2,900,000
Gain (Loss) on Disposition of Property Plant Equipment, Total			$ 50,000

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Fair Value Measurements (Details 5) (Detail) (USD $) In Thousands, unless otherwise specified	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Gain on derivative instruments, net [Member] | Exchange Traded Futures [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	$ 0	$ 104
Gain on derivative instruments, net [Member] | Physical Forward Contracts [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	0	306
Change In Value Of Warrants [Member] | Warrant [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	(4,280)	(10,114)
Interest expense and financing costs, net [Member] | Debt Repayment Derivative [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	$ 0	$ 45

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Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Details) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012
Preconfirmation, Current assets
Cash and cash equivalents			$ 1,954
Trust assets			0
Restricted cash			0
Trade accounts receivable, net			3,708
Prepaid assets			4,777
Prepaid reorganization costs			1,326
Total current assets			11,765
Preconfirmation, Oil and gas properties
Unproved			84
Proved			759,755
Land			4,000
Other			73,021
Total property and equipment			836,860
Less accumulated depreciation and depletion			(642,172)
Property and equipment, net			194,688
Preconfirmation, Long-term assets:
Investments in unconsolidated affiliates			3,629
Other long-term assets			307
Total long-term assets			3,936
Total assets			210,389
Preconfirmation, Liabilities not subject to compromise
Debtor in possession financing			56,535
Accounts payable and other accrued liabilities			4,897
Other accrued liabilities			9,224
Accrued reorganization and trustee expense			70,656
Preconfirmation, Liabilities subject to compromise
3 3/4% Senior notes			115,000
7% Senior convertible notes			150,000
Accounts payable and other accrued liabilities			17,203
Total current liabilities			352,859
Preconfirmation, Liabilities not subject to compromise
Long - term debt			0
Derivative liabilities			0
Total liabilities			357,273
Asset retirement obligations	3,172	512	476
Preconfirmation, Stockholders' equity
Common stock			288
Additional paid-in capital			1,643,285
Retained earnings (accumulated deficit)			(1,790,457)
Total stockholders' equity (deficit)			(146,884)
Total liabilities and equity (deficit)			210,389
Fresh Start Reporting Adjustments, Current assets
Trade accounts receivable, net			(1,981)	[1]
Prepaid assets			(4,777)	[1]
Prepaid reorganization costs			(1,326)	[1]
Fresh Start Reporting Adjustments, Oil and gas properties
Unproved			(84)	[1]
Proved			(14,776)	[1]
Other			(21,289)	[1]
Less accumulated depreciation and depletion			34,569
Fresh Start Reporting Adjustments, Long-term assets:
Investments in unconsolidated affiliates			(3,629)	[1]
Other long-term assets			(253)	[1]
Fresh Start Reporting Adjustments, Liabilities subject to compromise
Accounts payable and other accrued liabilities			(1,981)	[1]
Fresh Start Reporting Adjustments, Stockholders' equity
Common stock			(288)	[2]
Additional paid-in capital			288	[2]
Retained earnings (accumulated deficit)			(14,765)	[1]
Postconfirmation, Current assets
Cash and cash equivalents			4,882
Trust assets			3,446
Restricted cash			20,359
Trade accounts receivable, net			0
Prepaid assets			0
Prepaid reorganization costs			0
Total current assets			28,687
Postconfirmation, Oil and gas properties
Unproved			0
Proved			4,587
Land			0
Other			4,239
Total property and equipment			8,826
Less accumulated depreciation and depletion			0
Property and equipment, net			8,826
Postconfirmation, Long-term assets:
Investments in unconsolidated affiliates			105,344
Other long-term assets			54
Total long-term assets			105,398
Total assets			142,911
Postconfirmation, Liabilities not subject to compromise
Debtor in possession financing			0
Accounts payable and other accrued liabilities			4,897
Other accrued liabilities			2,640
Accrued reorganization and trustee expense			7,537
Postconfirmation, Liabilities subject to compromise
3 3/4% Senior notes			0
7% Senior convertible notes			0
Accounts payable and other accrued liabilities			12,336
Total current liabilities			19,873
Postconfirmation, Liabilities not subject to compromise
Long - term debt			6,335
Derivative liabilities			6,665
Asset retirement obligations			476
Total liabilities			33,349
Postconfirmation, Stockholders' equity
Common stock			1,477
Additional paid-in capital			108,085
Retained earnings (accumulated deficit)			0
Total stockholders' equity (deficit)			109,562
Total liabilities and equity (deficit)			142,911
Adjustments [Member]
Preconfirmation, Liabilities not subject to compromise
Asset retirement obligations			4,414
Reflects Adjustments To Remaining Assets [Member]
Fresh Start Reporting Adjustments, Liabilities subject to compromise
Accounts payable and other accrued liabilities			3,200	[1]
Reflects Elimination Of Predecessor Accumulated Deficit [Member]
Fresh Start Reporting Adjustments, Stockholders' equity
Additional paid-in capital			(1,636,890)	[3]
Retained earnings (accumulated deficit)			1,636,890	[3]
Plan Of Reorganization Adjustments [Member]
Preconfirmation, Current assets
Cash and cash equivalents			74,167	[4]
Trust assets			3,446	[5]
Restricted cash			20,359	[6]
Trade accounts receivable, net			(1,727)	[4]
Preconfirmation, Oil and gas properties
Proved			(740,392)	[4]
Land			(4,000)	[4]
Other			(47,493)	[4]
Less accumulated depreciation and depletion			607,603	[4]
Preconfirmation, Long-term assets:
Investments in unconsolidated affiliates			105,344
Preconfirmation, Liabilities not subject to compromise
Debtor in possession financing			(56,535)	[7]
Other accrued liabilities			(2,685)	[8]
Preconfirmation, Liabilities subject to compromise
3 3/4% Senior notes			(115,000)	[8]
7% Senior convertible notes			(150,000)	[8]
Accounts payable and other accrued liabilities			(2,560)	[4]
Preconfirmation, Liabilities not subject to compromise
Long - term debt			6,335	[7]
Derivative liabilities			6,665	[7]
Asset retirement obligations			(3,938)	[4]
Preconfirmation, Stockholders' equity
Common stock			1,457	[8]
Additional paid-in capital			100,084	[8]
Retained earnings (accumulated deficit)			166,144	[8]
Plan Of Reorganization Adjustments [Member] | Reflects Successor Drawing [Member]
Preconfirmation, Current assets
Cash and cash equivalents			(45,035)	[7]
Preconfirmation, Liabilities not subject to compromise
Other accrued liabilities			(1,500)	[7]
Plan Of Reorganization Adjustments [Member] | Reflects Settlement Of Other Claims [Member]
Preconfirmation, Current assets
Cash and cash equivalents			(24,204)	[6]
Preconfirmation, Liabilities not subject to compromise
Other accrued liabilities			(3,845)	[6]
Preconfirmation, Liabilities subject to compromise
Accounts payable and other accrued liabilities			(3,526)	[6]
Preconfirmation, Stockholders' equity
Common stock			20	[6]
Additional paid-in capital			1,318	[6]
Retained earnings (accumulated deficit)			2,188	[6]
Plan Of Reorganization Adjustments [Member] | Reflects Funding Of Recovery Trusts [Member]
Preconfirmation, Current assets
Cash and cash equivalents			(2,000)	[5]
Preconfirmation, Liabilities not subject to compromise
Other accrued liabilities			$ 1,446	[5]

[1] Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor's consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

[2] Reflects the cancellation of Predecessor common stock.

[3] Reflects the elimination of Predecessor's accumulated deficit.

[4] Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.

[5] Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).

[6] Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor's consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

[7] Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.

[8] Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor's consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

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Supply and Exchange Agreements (Textual) (Detail) (USD $)	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Shipping, Handling and Transportation Costs, Total		$ 3,700,000
Interest Expense, Total	1,056,000	19,471,000
Supply and Exchange Agreements [Member]
Interest Expense, Total		$ 1,400,000

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Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan

12 Months Ended

Dec. 31, 2013

Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan

Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan

In December 2011 and January 2012, Delta and its subsidiaries filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”). Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In March 2012, the Bankruptcy Court approved the procedures relating to plans of reorganization as well as asset sales. Following completion of the asset sales, the Debtors obtained approval from the Bankruptcy Court to proceed with Laramie Energy II, LLC (“Laramie”) as the sponsor of a plan of reorganization (the “Plan”). In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with a new joint venture formed by Delta and Laramie, Piceance Energy LLC (“Piceance Energy”), and Laramie to effect the transactions contemplated by Plan.

The Plan was declared effective on August 31, 2012 (the “Emergence Date”). On the Emergence Date, Delta consummated the transaction contemplated by the Contribution Agreement and each of Delta and Laramie contributed to Piceance Energy their respective assets in the Piceance Basin. Piceance Energy is owned 66.66% by Laramie and 33.34% by Delta. At the closing, Piceance Energy entered into a new credit agreement, borrowed $100 million under that agreement, and distributed approximately $72.6 million net of settlements to the company and approximately $24.9 million to Laramie. The company used its distribution to pay bankruptcy expenses and to repay its secured debt. The company also entered into a new credit facility and borrowed $13 million under that facility at closing, and used those funds primarily to pay bankruptcy claims and expenses.

Following the reorganization, Par retained its interest in the Point Arguello Unit offshore California and other miscellaneous assets and certain tax attributes, including significant net operating loss carryforwards. Based upon the Plan as confirmed by the Bankruptcy Court, Delta’s creditors were issued approximately 14.8 million shares of common stock, and Delta’s former stockholders received no consideration under the Plan.

Contemporaneously with the consummation of the Contribution Agreement, the company, through a wholly-owned subsidiary, entered into a Limited Liability company Agreement with Laramie that will govern the operations of Piceance Energy.

On the Emergence Date, Par adopted fresh-start reporting resulting in us becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to August 31, 2012 reflect the operations of Delta prior to reorganization (hereinafter also referred to as the “Predecessor”) and are not comparable to the consolidated financial statements presented on or after August 31, 2012. Fresh-start reporting was required upon emergence from Chapter 11 because (i) holders of voting shares immediately before confirmation of the Plan received less than 50% of the emerging entity and (ii) the reorganization value of our assets immediately before confirmation of the Plan was less than our post-petition liabilities and allowed claims. Fresh-start reporting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities. The effects of the implementation of the Plan and fresh-start adjustments are reflected in the results of operations of the Predecessor in the eight month period ended August 31, 2012. Our estimates of fair value are inherently subject to significant uncertainties and contingencies beyond our reasonable control. Accordingly, there can be no assurance that the estimates, assumptions, valuations, appraisals and financial projections will be realized, and actual results could vary materially. Moreover, the market value of our common stock may differ materially from the equity valuation for accounting purposes.

In the application of fresh-start reporting, a successor entity must determine a value to be assigned to the equity of the emerging company as of the date of adoption of fresh-start reporting, which for us is August 31, 2012, the date the Debtors emerged from Chapter 11. To facilitate this calculation, we first determined the enterprise value of the Successor and the individual components of the opening balance sheet. The most significant item is our 33.34% interest in Piceance Energy, the value of which was estimated to be approximately $105.3 million as of the Emergence Date. We also considered the fair value of the other remaining assets. See Note 11 - Fair Value Measurements for a detailed discussion of fair value and the valuation techniques.

The estimated enterprise value and the equity value are highly dependent on the achievement of the future financial results contemplated in the projections that were set forth in the Plan. The estimates and assumptions made in the valuation are inherently subject to significant uncertainties. The primary assumptions for which there is a reasonable possibility of the occurrence of a variation that would have significantly affected the reorganization value include the assumptions regarding our direct ownership of estimated proved reserves, our indirect ownership of estimated proved reserves through our equity ownership in Piceance Energy, operating expenses, the amount and timing of capital expenditures and the discount rate utilized.

Fresh-start reporting reflects the value of the Successor as determined in the confirmed Plan. Under fresh-start reporting, our asset values are remeasured and allocated based on their respective fair values in conformity with the acquisition method of accounting for business combinations. The reorganization values approximated the fair values of the identifiable net assets. Liabilities existing as of the Effective Date, other than deferred taxes and derivatives, were recorded at the present value of amounts expected to be paid using appropriate risk adjusted interest rates. Deferred taxes and derivatives were determined in conformity with applicable accounting standards. Predecessor accumulated depreciation, accumulated amortization and retained deficit were eliminated. Under the Plan, our priority non-tax claims and secured claims are unimpaired in accordance with the Bankruptcy Code. Each general unsecured claim and noteholder claims received its pro rata share of new common stock of Par in full satisfaction of its claims.

The following condensed consolidated balance sheet presents the implementation of the Plan and the adoption of fresh-start reporting as of the Effective Date. Reorganization adjustments have been recorded within the condensed consolidated balance sheet to reflect the effects of the Plan, including discharge of liabilities subject to compromise and the adoption of fresh-start reporting.

	August 31, 2012
	Predecessor			Plan of Reorganization Adjustments			Fresh Start Reporting Adjustments			Successor
	(in thousands)
ASSETS
Current assets
Cash and cash equivalents	$	1,954		$	74,167	(a)	$			$	4,882
					(45,035	)(c)
					(24,204	)(d)
					(2,000	)(e)
Trust assets		—			3,446	(e)					3,446
Restricted cash		—			20,359	(d)					20,359
Trade accounts receivable, net		3,708			(1,727	)(a)		(1,981	)(g)		—
Prepaid assets		4,777						(4,777	)(g)		—
Prepaid reorganization costs		1,326						(1,326	)(g)		—
Total current assets		11,765									28,687
Property and equipment
Oil and gas properties
Unproved		84						(84	)(g)		—
Proved		759,755			(740,392	)(a)		(14,776	)(g)		4,587
Land		4,000			(4,000	)(a)					—
Other		73,021			(47,493	)(a)		(21,289	)(g)		4,239
Total property and equipment		836,860									8,826
Less accumulated depreciation and depletion		(642,172	)		607,603	(a)		34,569	(g)		—
Property and equipment, net		194,688									8,826
Long-term assets:
Investments in unconsolidated affiliates		3,629			105,344	(a)		(3,629	)(g)		105,344
Other long-term assets		307						(253	)(g)		54
Total long-term assets		3,936									105,398
Total assets	$	210,389								$	142,911
LIABILITIES AND EQUITY
Current liabilities
Liabilities not subject to compromise
Debtor in possession financing	$	56,535			(56,535	)(c)				$	—
Accounts payable and other accrued liabilities		4,897									4,897
Other accrued liabilities		9,224			(2,685	)(b)					2,640
					(1,500	)(c)
					(3,845	)(d)
					1,446	(e)
Accrued reorganization and trustee expense		70,656									7,537
Liabilities subject to compromise
3 3⁄4% Senior notes		115,000			(115,000	)(b)					—
7% Senior convertible notes		150,000			(150,000	)(b)					—
Accounts payable and other accrued liabilities		17,203			(2,560	)(a)		(1,981	)(g)		12,336
					(3,526	)(d)		3,200	(g)
Total current liabilities		352,859									19,873
Long-term liabilities
Liabilities not subject to compromise
Long - term debt		—			6,335	(c)					6,335
Derivative liabilities		—			6,665	(c)					6,665
Asset retirement obligations		4,414			(3,938	)(a)					476
Total liabilities		357,273									33,349
Stockholders’ equity
Common stock		288			1,457	(b)		(288	)(f)		1,477
					20	(d)
Additional paid-in capital		1,643,285			100,084	(b)		288	(f)		108,085
					1,318	(d)		(1,636,890	)(h)
Retained earnings (accumulated deficit)		(1,790,457	)		166,144	(b)		(14,765	)(g)		—
					2,188	(d)		1,636,890	(h)
Total stockholders’ equity (deficit)		(146,884	)								109,562
Total liabilities and equity (deficit)	$	210,389								$	142,911

Notes to Plan of Reorganization and Fresh Start Accounting Adjustments

(a) Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.

(b) Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(c) Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.

(d) Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(e) Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).

(f) Reflects the cancellation of Predecessor common stock.

(g) Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

(h) Reflects the elimination of Predecessor’s accumulated deficit.

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Debt (Details 3) (Detail)	12 Months Ended
	Dec. 31, 2013
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	2.00%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	0.00%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	2.25%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	0.25%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	2.50%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Debt Instrument Margin Rate	0.50%

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Inventories (Tables)

12 Months Ended

Dec. 31, 2013

Schedule of Inventory, Current

The following is a summary of our inventory (in thousands):

	December 31, 2013						December 31, 2012
	Titled Inventory		Supply and Exchange Agreements		Total		Titled Inventory
Crude oil and feedstocks	$	—	$	137,706	$	137,706	$	10,466
Refined products and blend stock		67,532		161,554		229,086		—
Spare parts, materials and supplies, and merchandise		13,831		—		13,831		—
	$	81,363	$	299,260	$	380,623	$	10,466

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Defined Contribution Plans

12 Months Ended

Dec. 31, 2013

Defined Contribution Plans

Note 12 - Defined Contribution Plans

We maintain several defined contribution plans for our employees. Eligible employees can enter the plans either immediately or after one year of service, depending on the plan. The plans permit employee contributions up to the IRS limits per year. For some plans, we contribute 3% of the employee’s eligible compensation to the plan regardless of the employee’s contribution. On all plans, we match a portion of all the employee’s contributions up to 6% depending on the plan. In addition, we have a money purchase pension plan for certain eligible employees. Under this plan, we make contributions to employee directed investment accounts ranging from 5.5% to 8.5% of eligible compensation depending on the employee’s age. For the year ended December 31, 2013, we made contributions to the plans totaling approximately $502 thousand. There were no such plans in place for the period from September 1, 2012 through December 31, 2012.

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Segment Information (Textual) (Detail)	4 Months Ended	12 Months Ended
	Dec. 31, 2012 Segment	Dec. 31, 2013 Segment
Number of businsess segment	2	3