10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 2013

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

For the transition period from              to             

Commission file number 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)

(713) 969-3293

(Registrant’s telephone number, including area code)

 (Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No   ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T 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 whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller

reporting company. See the 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	¨	Smaller reporting company	x

Indicate by a check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange 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  ¨

299,075,145 shares of common stock, $0.01 par value per share, were outstanding as of November 14, 2013.

INDEX

Forward Looking Statements		Page No.
PART I FINANCIAL INFORMATION		1
Item 1.	Consolidated Financial Statements	1
	Consolidated Balance Sheets	1
	Consolidated Statements of Operations	2
	Consolidated Statement of Changes in Equity	4
	Consolidated Statements of Cash Flows	5
	Notes to Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	62
Item 4.	Controls and Procedures	62
PART II OTHER INFORMATION		63
Item 1.	Legal Proceedings	63
Item 1A.	Risk Factors	63
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	67
Item 3.	Defaults Upon Senior Securities	67
Item 4.	Mine Safety Disclosures	67
Item 5.	Other Information	67
Item 6.	Exhibits	67

The terms “Par,” “Company,” “we,” “our,” and “us” refer to Par Petroleum Corporation (and for periods prior to the reorganization described herein, Delta Petroleum Corporation) and its consolidated subsidiaries unless the context suggests otherwise.

Forward Looking Statements

This Quarterly Report on Form 10-Q contains forward-looking statements, within the meaning of Section 27A of the Securities Act of 1933, as amended (“Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (“Exchange Act”).

We are including the following discussion to inform our existing and potential security holders generally of some of the risks and uncertainties that can affect us and to take advantage of the “safe harbor” protection for forward-looking statements afforded under federal securities laws. From time to time, our management or persons acting on our behalf make forward-looking statements to inform existing and potential security holders about us. Forward-looking statements are generally accompanied by words such as “estimate,” “project,” “propose,” “potential,” “predict,” “forecast,” “believe,” “expect,” “anticipate,” “plan,” “goal” or other words that convey the uncertainty of future events or outcomes. Except for statements of historical or present facts, all other statements contained in this report are forward-looking statements. The forward-looking statements may appear in a number of places and include statements with respect to, among other things: business objectives and strategies, operating strategies; future refining margins; anticipated levels of crude oil and refined product inventories; anticipated trends in the supply of and demand for crude oil and other feedstocks and refined products; the effect of general economic and other conditions on refining industry fundamentals; natural gas and oil reserve estimates (including estimates of future net revenues associated with such reserves and the present value of such future net revenues); estimates of future production of natural gas and oil; marketing of natural gas and oil; expected future revenues and earnings, and results of operations; future capital, development and exploration expenditures (including the amount and nature thereof); anticipated compliance with and impact of laws and regulations; and the outcome of the claims allowance proceedings and other affirmative recoveries sought.

These statements by their nature are subject to certain risks, uncertainties and assumptions and will be influenced by various factors. Should any of the assumptions underlying a forward-looking statement prove incorrect, actual results could vary materially. In some cases, information regarding certain important factors that could cause actual results to differ materially from any forward-looking statement appears together with such statement. In addition, the factors described under Critical Accounting Policies and Risk Factors, as well as other possible factors not listed, could cause actual results to differ materially from those expressed in forward-looking statements, including, without limitation, the following: 

· our ability to maintain adequate liquidity;

· identifying future acquisitions and our diligence of any acquired businesses;

· our ability to realize the intended benefits of the acquisition of Hawaii Independent Energy, LLC and successfully integrate the business acquired;

· our level of indebtedness;

· our ability to generate cash flow;

· the continued availability of our net operating loss tax carryforwards;

· instability in the global financial system;

· the strength and financial resources of our competitors;

· credit risk of our contract counterparties;

· legal and/or regulatory compliance requirements;

· effectiveness of our disclosure controls and procedures and our internal controls over financial reporting;

· the volatility of crude oil prices, refined product prices and electrical power prices;

· the demand for transportation fuels resulting from the recent global economic downturn;

· the potential for spills, discharges or other releases of petroleum products or hazardous substances;

· our inventory risk management activities;

· interruptions of supply and increased cost resulting from third-party transportation of crude oil and refined products;

· the failure of our critical information systems;

· our ability to control activities on properties we do not operate;

· the volatility of natural gas and oil prices, including the effect of local or regional factors;

· uncertainties in the estimation of proved reserves and in the projection of future rates of production;

· our ability to replace production;

· declines in the values of our natural gas and oil properties resulting in writedowns;

· timing, amount, and marketability of production;

· third party curtailment, or processing plant or pipeline capacity constraints beyond our control;

· seasonal weather conditions;

· operating hazards that result in losses;

· uninsured or underinsured operating activities;

· our ability to develop and grow our marketing, transportation, distribution and logistics business;

· the success of the risk management strategies of Texadian Energy, Inc. (“Texadian”);

· compliance with laws and regulations relating to Texadian’s business;

· commodity price risk for the business of Texadian;

· the illiquidity and price volatility of our common stock; and

· the concentrated ownership of our common stock.

Many of these factors are beyond our ability to control or predict. These factors are not intended to represent a complete list of the general or specific factors that may affect us.

All forward-looking statements speak only as of the date made. All subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements above and other cautionary statements included in this report. We undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which it is made or to reflect the occurrence of anticipated or unanticipated events or circumstances.

We caution you not to place undue reliance on these forward-looking statements. We urge you to carefully review and consider the disclosures made in this Quarterly Report on Form 10-Q and our other reports filed with the SEC that attempt to advise interested parties of the risks and factors that may affect our business.

PART I FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

	September 30,  2013			December 31,  2012
ASSETS	(Unaudited)
Current assets:
Cash and cash equivalents	$	69,044		$	6,185
Restricted cash		1,750			23,970
Trade accounts receivable, net of allowance for doubtful accounts of $0 at September 30, 2013 and December 31, 2012		93,625			17,730
Inventories		395,798			10,466
Prepaid and other current assets		7,415			1,575
Total current assets		567,632			59,926
Property and equipment:
Land		39,800			—
Property, plant and equipment		66,144			—
Furniture and fixtures		1,853			—
Software		2,646			—
Other		1,400			1,415
Natural gas and oil properties, at cost, successful efforts method of accounting:
Proved		4,909			4,804
Total property and equipment		116,752			6,219
Less accumulated depreciation, depletion, and amortization		(1,728	)		(373	)
Property and equipment, net		115,024			5,846
Long-term assets:
Investment in unconsolidated affiliate		102,923			104,434
Intangible assets, net		12,085			8,809
Goodwill		13,309			7,756
Assets held for sale		—			2,800
Other long-term assets		17,141			11
Total long-term assets		145,458			123,810
Total assets	$	828,114		$	189,582
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current maturities of debt	$	—		$	35,000
Obligations under supply and exchange agreements		333,599			—
Accounts payable		65,795			25,329
Other accrued liabilities		25,499			981
Accrued settlement claims		6,475			8,667
Total current liabilities		431,368			69,977
Long-term liabilities:
Long – term debt, net of current maturities and unamortized discount		67,448			7,391
Derivative liabilities		17,590			10,945
Obligations under supply and exchange agreements		17,132			—
Other liabilities		19,408			512
Total liabilities		552,946			88,825
Commitments and contingencies
Stockholders’ Equity:
Preferred stock, $0.01 par value: authorized 3,000,000 shares, none issued		—			—
Common stock, $0.01 par value; authorized 500,000,000 shares at September 30, 2013 and December 31, 2012, issued 299,053,989 shares and 150,080,927 shares at September 30, 2013 and December 31, 2012, respectively		2,991			1,501
Additional paid-in capital		309,666			108,095
Accumulated deficit		(37,489	)		(8,839	)
Total stockholders’ equity		275,168			100,757
Total liabilities and stockholders’ equity	$	828,114		$	189,582

See accompanying notes to consolidated financial statements.

1

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share amounts)

	Successor			Successor			Predecessor
	Three Months Ended September 30, 2013			One Month Ended September 30, 2012			Two Months Ended August 31, 2012
Revenue:
Operating revenues	$	33,203		$	—		$	—
Natural gas and oil sales		2,182			584			5,466
Total revenues		35,385			584			5,466
Operating expenses:
Cost of revenues		30,656			—			—
Lease operating expense		1,000			332			2,223
Transportation expense		—			—			1,677
Production taxes		15			3			180
Exploration expense		—			—			1
Dry hole costs and impairment		—			—			151,346
Depreciation, depletion, amortization and accretion		1,218			124			5,815
Trust litigation and settlements		549			—			—
General and administrative expense		10,363			356			1,641
Total operating expenses		43,801			815			162,883
Loss from unconsolidated affiliates		(907	)		(1,525	)		—
Operating loss		(9,323	)		(1,756	)		(157,417	)
Other income and (expense):
Interest expense and financing costs, net		(3,935	)		(246	)		(1,990	)
Other income (expense), net		28			—			526
Unrealized loss on derivative instruments		(1,390	)		—			—
Loss from unconsolidated affiliates		—			—			(29	)
Total other expense, net		(5,297	)		(246	)		(1,493	)
Loss before income taxes and reorganization items		(14,620	)		(2,002	)		(158,910	)
Income tax expense		—			—			—
Loss before reorganization items		(14,620	)		(2,002	)		(158,910	)
Reorganization items
Professional fees and administrative costs		—			—			10,719
Gain on settlement of liabilities		—			—			(168,332	)
Fresh start adjustments		—			—			14,765
Net loss	$	(14,620	)	$	(2,002	)	$	(16,062	)
Basic and diluted loss per common share	$	(0.09	)	$	(0.01	)	$	(0.56	)

See accompanying notes to consolidated financial statements. 

2

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share amounts)

	Successor			Successor			Predecessor
	Nine Months Ended September 30, 2013			One Month Ended September 30, 2012			Eight Months Ended August 31, 2 012
Revenue:
Operating revenues	$	128,960		$	—		$	—
Natural gas and oil sales		5,988			584			23,079
Total revenues		134,948			584			23,079
Operating expenses:
Cost of revenues		113,561			—			—
Lease operating expense		4,175			332			9,038
Transportation expense		—			—			6,963
Production taxes		39			3			979
Exploration expense		—			—			2
Dry hole costs and impairments		—			—			151,347
Depreciation, depletion, amortization and accretion		3,022			124			16,041
Trust litigation and settlements		5,713			—			—
General and administrative expense		19,422			356			9,386
Total operating expenses		145,932			815			193,756
Loss from unconsolidated affiliates		(1,772	)		(1,525	)		—
Operating loss		(12,756	)		(1,756	)		(170,677	)
Other income and (expense):
Interest expense and financing costs, net		(9,806	)		(246	)		(6,852	)
Other income (expense), net		797			—			516
Realized gain on derivative instruments, net		410			—			—
Unrealized loss on derivative instruments		(6,645	)		—			—
Loss from unconsolidated affiliates		—			—			(20	)
Total other expense, net		(15,244	)		(246	)		(6,356	)
Loss before income taxes and reorganization items		(28,000	)		(2,002	)		(177,033	)
Income tax expense		(650)			—			—
Loss before reorganization items		(28,650	)		(2,002	)		(177,033	)
Reorganization items
Professional fees and administrative costs		—			—			22,354
Gain on settlement of liabilities		—			—			(168,715	)
Fresh start adjustments		—			—			14,765
Net loss	$	(28,650	)	$	(2,002	)	$	(45,437	)
Basic and diluted loss per common share	$	(0.18	)	$	(0.01	)	$	(1.57	)

See accompanying notes to consolidated financial statements.

3

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

For the nine months ended September 30, 2013

(Unaudited)

	Common stock				Additional paid-in		Accumulated			Total Stockholders’
	Shares		Amount		capital		deficit			equity
	(in thousands)
Balance, December 31, 2012		150,081	$	1,501	$	108,095	$	(8,839	)	$	100,757
Stock issued in a private transaction, net offering cost of $830		143,885		1,439		197,731		—			199,170
Stock issued to settle bankruptcy claims		2,014		20		2,448		—			2,468
Stock issued in exchange for liability		565		6		926		—			932
Stock based compensation		2,509		25		466		—			491
Net loss		—		—		—		(28,650	)		(28,650	)
Balance, September 30, 2013		299,054	$	2,991	$	309,666	$	(37,489	)	$	275,168

See accompanying notes to consolidated financial statements.

4

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)

	Successor			Successor			Predecessor
	Nine Months Ended September 30, 2013			One Month Ended September 30, 2012			Eight Months Ended August 31, 2012
Cash flows from operating activities:
Net loss	$	(28,650)		$	(2,002	)	$	(45,437	)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation, depletion, amortization and accretion		3,022			124			16,041
Interest, prepayments premiums and exit penalty capitalized into note balance		8,036			—			2,989
Amortization of deferred financing costs and bond discount		1,619			132			—
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 on sale of assets held for sale		(50)			—			—
Loss on disposal of other assets		33			—			126
Dry hole costs and impairment		—			—			151,347
Stock-based compensation		491			—			1,895
Unrealized loss on derivative contracts		6,645			—			—
Loss from unconsolidated affiliates		1,772			1,525			20
Other		—			—			(699	)
Net changes in operating assets and liabilities:
Trade accounts receivable		(16,161)			(581	)		3,472
Deposits and prepaid assets		54			(190	)		(1,378	)
Inventories		34,778			—			—
Supply and exchange agreement		(51,349	)		—			—
Other assets		2			—			—
Accounts payable and other current accrued liabilities		43,230			645			(4,187	)
Other accrued liabilities		1,034			—			—
Settlement claim liability		4,526			—			—
Accrued reorganization costs		—			—			9,116
Net cash provided by (used in) operating activities		9,032			(347	)		(20,262	)
Cash flows from investing activities:
Purchase of HIE, net of cash acquired		(559,607)			—			—
Additions to property and equipment		(4,627)			—			(1,613	)
Cash restricted for letter of credit		(1,030)			—			—
Capitalized drilling costs owed to operator		(261)			—			—
Proceeds from sale of oil and gas properties		—			—			74,209
Proceeds from sale of other fixed assets		—			—			26
Proceeds from sale of assets held for sale		2,850			—			—
Net cash used in investing activities		(562,675)			—			72,622
Cash flows from financing activities:
Funding of purchase of HIE from supply and exchange agreements		384,948			—			—
Proceeds from sale of common stock, net of offering costs		199,170			—			—
Proceeds from borrowings		67,655			—			23,000
Repayments of borrowing		(52,007)			—			(59,535	)
Payment of deferred loan costs		(2,264)			—			—
Fund distribution agent account		—			—			(21,805	)
Release of restricted cash held to secure letters of credit		19,000			—			—
Proceeds from (funding of) Wapiti and General Recovery Trust		—			2,000			(2,000)
Net cash provided by (used in) financing activities		616,502			2,000			(60,340	)
Net increase (decrease) in cash and cash equivalents		62,859			1,653			(7,980	)
Cash at beginning of period		6,185			4,882			12,862
Cash at end of period	$	69,044		$	6,535		$	4,882
Non cash investing and financing activities and supplemental disclosure of cash paid:
Stock issued to settle bankruptcy claims	$	2,468		$	—		$	—
Stock issued in exchange of liability	$	932		$	—		$	—
Cash paid for interest and financing costs	$	93		$	—		$	3,745
Restricted cash used to settle bankruptcy claims	$	4,250		$	—		$	—
Interest capitalized into note balances	$	7,839		$	114		$	—
Net settlement of supply and exchange agreements	$	21,639		$	—		$	—

See Note 4 for additional non cash disclosures from the acquisition of HIE including the assumptions of liabilities.

 See accompanying notes to consolidated financial statements.

5

PAR PETROLEUM CORPORATION AND SUBSIDIARIES

Notes to Consolidated Financial Statements

(Unaudited)

(1) Reorganization under Chapter 11

In December 2011, Delta Petroleum Corporation (“Delta”) and its subsidiaries Amber Resources Company of Colorado, DPCA, LLC, Delta Exploration Company, Inc., Delta Pipeline, LLC, DLC, Inc., CEC, Inc. and Castle Texas Production Limited Partnership 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”). In January 2012, Castle Exploration Company, Inc., a subsidiary of Delta Pipeline, LLC, also filed a voluntary petition under Chapter 11 in the Bankruptcy Court. Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In December 2011, the Debtors filed a motion requesting an order to approve matters relating to a proposed sale of Delta’s assets, including bidding procedures, establishment of a sale auction date and establishment of a sale hearing date. In January 2012, the Bankruptcy Court issued an order approving these matters. In March 2012, Delta announced that it was seeking court approval to amend the bidding procedures for its upcoming auction to allow bids relating to potential plans of reorganization as well as asset sales. On March 22, 2012, the Bankruptcy Court approved the revised procedures.

Following the auction, 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 of Reorganization” or the “Plan”) by which Laramie and Delta intended to form a new joint venture called Piceance Energy, LLC (“Piceance Energy”). In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with Piceance Energy and Laramie to effect the transactions contemplated by the Plan.

On June 4, 2012, the Debtors filed a disclosure statement relating to the Plan of Reorganization. The Plan was confirmed on August 15, 2012 and 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 (referred to after the closing of the transaction as “Successor”). 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.

On the Emergence Date, Delta also amended and restated its certificate of incorporation and bylaws and changed its name to Par Petroleum Corporation (“Par”). The amended and restated certificate of incorporation contains restrictions that render void certain transfers of the Company stock that involve a holder of five percent or more of its shares. The purpose of this provision is to preserve certain of the Company’s tax attributes including net operating loss carryforwards that the Company believes may have value. Under the amended and restated bylaws, the Company’s board of directors has five members, each of whom was appointed by its stockholders pursuant to a Stockholders’ Agreement entered into on the Emergence Date.

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 147.7 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 governs the operations of Piceance Energy (the “LLC Agreement”).

In addition, Laramie and Piceance Energy entered into a Management Services Agreement pursuant to which Laramie provides certain services to Piceance Energy for a fee of $650,000 per month.

(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

6

inter-company balances and transactions have been eliminated in consolidation. At September 30, 2013, the majority of our natural gas and oil activities were conducted through partnerships and joint ventures. We will include our proportionate share of assets, liabilities, revenues and expenses from these entities in our consolidated financial statements. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.

Our wholly owned primary subsidiaries include Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3), Texadian Energy, Inc. (formerly known as SEACOR Energy Inc. (“Texadian”)), which we acquired on December 31, 2012 (see Note 4) and Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”)  which acquired all of the outstanding membership interests of Hawaii Independent Energy, LLC (formerly known as Tesoro Hawaii, LLC (“HIE”)), on September 25, 2013 (see Note 4).

The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to Form 10-Q. Some information and footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”), have been condensed or omitted pursuant to the Securities and Exchange Commission’s (“SEC”) rules and regulations. In our opinion, all adjustments, consisting only of normal recurring accruals, considered necessary to state fairly the information in our unaudited condensed consolidated financial statements have been included. Operating results for interim periods are not necessarily indicative of the results that may be expected for the complete fiscal year. As a result, these unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto previously filed with our Annual Report on Form 10-K for the year ended December 31, 2012.

Fresh Start Accounting and the Effects of the Plan

As required by U.S. GAAP, effective as of August 31, 2012, Par adopted fresh start accounting following the guidance of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 852 “Reorganizations” (“ASC 852”). Fresh start accounting 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 “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 two and eight months ended August 31, 2012 have been omitted. Fresh start accounting 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 accounting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities.

Cash Equivalents

We consider all highly liquid investments with maturities at date of acquisition of three months or less to be cash equivalents.

Restricted Cash

As of September 30, 2013, restricted cash totaled approximately $1.7 million and consisted of approximately $720,000 designated to settle bankruptcy matters that is not available for operating activities (see Note 8) and approximately $1.0 million held at a commercial bank to support a letter of credit facility related to our acquisition of HIE. At December 31, 2012, restricted cash totaled approximately $24.0 million, including amounts held at a commercial bank to support a letter of credit facility totaling approximately $19.0 million (see Note 6) and approximately $4.8 million designated to settle bankruptcy matters. During the nine months ended September 30, 2013, the $19.0 million of restricted cash supporting a letter of credit facility was released to us and was made available for general corporate purposes.

Trade Receivables

Texadian’s customers primarily included major independent refining and marketing companies. HIE’s receivables include receivables from the sale of refined products and proprietary credit card receivables from sales at its retail locations. Customers are required to pay in advance or are granted credit on a short-term basis when credit risks are considered acceptable. We routinely review our trade receivables and make provisions for doubtful accounts based on existing customer and economic conditions; however, those provisions are estimates and actual results could differ from those estimates and those differences may be material. Trade receivables that are deemed uncollectible are removed from accounts receivable and from the allowance for doubtful accounts when collection efforts have been unsuccessful. As of September 30, 2013, we had no significant allowance for doubtful accounts. Several of Texadian’s physical purchases and sales are with the same counterparty and are settled on a net basis and therefore Texadian’s receivables are recorded net of any corresponding payables. Additionally, we provide an accrual for natural gas and oil sales using the sales method by

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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.

Refined Product Exchanges

As further described in Note 4, HIE has entered into supply and exchange contracts whereby it agrees 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 that are settled in kind on a volumetric basis, 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

Texadian’s inventories, which consist of in-transit oil, are stated at the lower of cost or market. We record impairments, as needed, to adjust the carrying amount of inventories to the lower of cost or market.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 4. Legal title to the crude oil is held by Barclays and the crude oil is stored in HIE’s storage tanks for the benefit of Barclays pursuant to a storage agreement until it is needed for further use in the refining process. At that time, certain nominated volumes are drawn out of the storage tanks and purchased by us. After processing and subject to the supply and exchange agreements described in Note 4, Barclays takes title to the refined products when the refined products enters the tanks which are then stored in HIE’s storage tanks until sold at 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. Inventories are stated at the lower of cost or market. We use last-in, first-out as the primary method to determine the cost of crude oil and refined product inventories in our refining and retail segments. We value merchandise along with spare parts, materials and supplies at average cost.

 Investment in Unconsolidated Affiliate

Investments in operating entities where we have the ability to exert significant influence, but do not control the operating and financial policies, are accounted for using the equity method. Our share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations.

Our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3).

Assets Held for Sale

As of December 31, 2012, we classified our 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 $50,000.

Property and Equipment

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 amortized as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based

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on total proved natural gas and oil reserves amortized as the related reserves are produced.

HIE’s operations, especially those of the refining segment, are highly capital intensive. The refinery consists of a series of interconnected, highly integrated and interdependent crude oil processing facilities and supporting logistical infrastructure, and these units are regularly improved. We plan for these improvements by developing a multi-year capital program that is updated and revised based on changing internal and external factors.

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. The useful lives range from 8 to 47 years for refining assets, 3 to 30 years for logistics assets, 14 to 18 years for retail assets, 3 to 7 years for corporate assets and 3 for software. 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.

Goodwill and Other Intangible Assets

We recorded goodwill as a result of our acquisitions of Texadian and have preliminarily recognized goodwill with the acquisition of HIE. Goodwill was attributable to opportunities expected to arise from combining our operations with Texadian’s and HIE’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, as a result of our acquisitions of Texadian and HIE, we recorded certain other identifiable intangible assets. These 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.

Impairment of Goodwill and Long-Lived Assets

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. Qualitative factors assessed for the reporting unit would include the competitive environments and financial performance of the reporting unit. 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, based upon a multiple of estimated earnings. 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. The fair value calculation uses Level 3 (see Note 7) inputs and includes multiple assumptions and estimates, including the projected cash flows and discount rates applied. Changes in these assumptions and estimates could result in a goodwill impairment that could materially adversely impact our financial position or results of operations.

We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist under authoritative guidance. 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 fair value. These impairment tests are heavily influenced by assumptions and estimates that are subject to change as additional information becomes available.

Our natural gas and oil assets, including our investment in our unconsolidated affiliate, are reviewed for impairment quarterly or when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Estimates of expected future cash flows represent our best estimate based on reasonable and supportable assumptions and projections.

For proved properties, if the expected future cash flows exceed the carrying value of the asset, no impairment is recognized. If the carrying value of the asset exceeds the expected future cash flows, an impairment exists and is measured by the excess of the carrying value over the estimated fair value of the asset. Any impairment provisions recognized are permanent and may not be restored in the future.

We assess proved properties on an individual field basis for impairment each quarter when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For proved properties, the review consists of a comparison of the carrying value of the asset with the asset’s expected future undiscounted cash flows without interest costs.

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For unproved properties, the need for an impairment charge is based on our plans for future development and other activities impacting the life of the property and our ability to recover our investment. When we believe the costs of the unproved property are no longer recoverable, an impairment charge is recorded based on the estimated fair value of the property.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the net book values 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’ net book value. If this occurs, an impairment loss is recognized for the difference between the fair value and net book 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.

Asset Retirement Obligations

An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. Our AROs arise from plugging and abandonment liabilities for our natural gas and oil wells, as well as AROs arising from HIE’s refinery and retail operations. We record 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. 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. 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 associated with HIE 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 primarily in operating expenses in our statements of consolidated operations.

Derivatives and Other Financial Instruments

We may 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.

Texadian 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.  Texadian’s policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle.  Should Texadian not designate a contract as a normal purchase or normal sale or should a scheduled delivery under the terms of contract not occur, then these exceptions may require the recording of the contract as a derivative.  If derivative accounting treatment is required then these

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contracts would be recorded at fair value as either an asset or a liability and marked to market each reporting period with changes in fair value being charged to earnings. As of September 30, 2013, we have elected the normal purchase normal sale exemption for these contracts. As such, 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 Texadian’s open contracts that 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 6) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our delayed draw term loan facility contains certain puts that are 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.

The carrying value of trade accounts receivable and accounts payable approximates fair value due to their short term nature. Our long-term debt is recorded on the amortized cost basis. We estimate our long term debt’s fair value to be approximately $61.3 million at September 30, 2013 using a discounted cash flow analysis and an estimate of the current yield 5.7% by reference to market interest rates for term debt of comparable companies which is considered to be a Level 3 fair value measurement (see Note 7).

Accrued Settlement Claims

As of September 30, 2013, we have accrued approximately $6.4 million relating to claims resulting from our bankruptcy (see Note 8). 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 in the financial statements 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 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 HIE’s and Texadian’s operations.  They operate in states where we have no net operating loss carryovers available to offset taxable income generated within those states.  Accordingly, we have accrued state income tax expense of approximately $0 and $650,000 for the three and nine months ended September 30, 2013, respectively.

Stock Based Compensation

We recognize the cost of share based payments over the period the employee provides service, generally the vesting period, and includes such costs in general and administrative expense in the 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.

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Revenue Recognition

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 September 30, 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Marketing and Transportation

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.

Texadian earns 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 and Retail

HIE recognizes 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

Other Income

For the nine months ended September 30, 2013, other income totaled approximately $797,000 and consists primarily of a state tax refund totaling approximately $483,000 and a legal settlement of approximately $200,000.

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 foreign currency gains or losses, net in the accompanying consolidated statements of operations in the period in which the currency exchange rates change.

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 under fresh start accounting, fair value of assets and liabilities recorded under purchase accounting, natural gas and oil reserves, bad debts, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

(3) Investments 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, and as a result, we do not meet the accounting

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criteria which require us to consolidate the joint venture. The 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 $140 million.  As of September 30, 2013, the balance outstanding on the revolving credit facility was approximately $90.0 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.

Piceance Energy holds various commodity hedging instruments to mitigate a portion of the effect of natural gas and oil price fluctuations. The contracts are in the form of costless collars of 15,000 MMBtu/day with floors of an average of $3.37 and ceilings of an average of $4.28 with 5,000 MMBtu/day through March 2014 and 10,000 MMBtu/day  through September 2014, and as well as swaps of 10,000 MMBtu/day for an average price of $3.46 through September 2014. Piceance Energy also holds natural gas gathering and processing contracts for a fixed rate expiring on various dates beginning in 2017 through 2032. Some of our contracts require a minimum throughput commitment.

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

	Three Months Ended September 30,  2013			Nine Months Ended September 30,  2013
	(in thousands)
Beginning balance	$	103,815			$	104,434
Income (loss) from unconsolidated affiliates		(907	)			(1,772	)
Capitalized drilling costs obligation paid		15				261
Ending balance	$	102,923			$	102,923

Summarized balance sheet information and our share of the equity investment are as follows:

	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Assets
Cash and equivalents	$	23		$	8
Accounts receivable		3,486			1,162
Prepaids and other assets		1,323			441
Total current assets		4,832			1,611
Natural gas and oil property, successful efforts method of accounting		549,327			183,146
Other real estate and land		14,314			4,772
Office furniture and equipment		3,110			1,037
Total		566,751			188,955
Less: accumulated depletion, depreciation and amortization		(107,216	)		(35,746	)
Total property and equipment, net		459,535			153,209
Deferred issue costs and other assets, net		953			318
Total assets	$	465,320		$	155,138

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	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Accounts payable and accrued liabilities	$	5,023		$	1,675
Natural gas and oil sales payable		11,041			3,681
Derivative liabilities		542			181
Total current liabilities		16,606			5,537
Note payable		90,000			30,006
Asset retirement obligations		2,959			987
Total non-current liabilities		92,959			30,993
Total liabilities		109,565			36,530
Members equity
Members’ equity		365,046			121,706
Accumulated deficit		(9,291	)		(3,098	)
Total members’ equity		355,755			118,608
Total liabilities and members’ equity	$	465,320		$	155,138

At September 30, 2013, our members’ equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment recorded on our consolidated balance sheet by approximately $15.7 million. We attribute this difference, which is expected to be permanent, to lack of control and marketability discounts.

Summarized income statement information and our share for the period for which our investment was accounted for under the equity method is as follows:

	Three Months Ended September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	14,622		$	4,875
Natural gas and oil operating expenses		7,416			2,473
Depletion, depreciation and amortization		6,897			2,299
Management fee		1,950			650
General and administrative		447			149
Total operating expenses		16,710			5,571
Loss from operations		(2,088	)		(696	)
Other income (expense)
Income from derivatives		106			35
Interest expense and debt issue costs		(718	)		(239	)
Other expense		(20	)		(7	)
Total other expense, net		(632	)		(211	)
Net loss	$	(2,720	)	$	(907	)

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	Nine Months Ended  September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	44,076		$	14,695
Natural gas and oil operating expenses		22,160			7,388
Depletion, depreciation and amortization		17,557			5,854
Management fee		5,850			1,950
General and administrative		2,420			807
Total operating expenses		47,987			15,999
Loss from operations		(3,911	)		(1,304	)
Other income (expense)
Income from derivatives		825			275
Interest expense and debt issue costs		(2,139	)		(713	)
Other expense		(91	)		(30	)
Total other expense, net		(1,405	)		(468	)
Net loss	$	(5,316	)	$	(1,772	)

(4) Acquisitions

Texadian Energy, Inc. (formerly known as SEACOR Energy Inc.)

On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for $14.0 million plus estimated net working capital of approximately $4.0 million at closing resulting in approximately $18.0 million of cash paid at closing. Texadian operates an oil transportation, distribution and marketing business with significant logistics capabilities. We acquired Texadian in furtherance of our growth strategy that focuses on the acquisition of income producing businesses. The purchase price for the acquisition was funded with a combination of cash and additional borrowings under the Tranche B Loan (see Note 6).

The purchase was accounted for as a business combination in accordance with ASC 805 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 is defined in ASC 805 as the future economic benefit of other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is 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		8,290
Net non cash working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	17,439

None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes.

The results of operations of Texadian are included in our consolidated statement of operations beginning January 1, 2013. We have not presented pro forma results for Predecessor periods as the entities are not comparable.

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Hawaii Independent Energy, LLC (formerly known as Tesoro Hawaii, LLC)

On June 17 , 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, entered into a membership interest purchase agreement (the “Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the Purchase Agreement, Tesoro Hawaii, LLC (“Tesoro Hawaii”). Pursuant to the 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 purchased the Purchased Units for $75.0 million plus or minus adjustments for net working capital, plus adjustments for inventories at closing and plus certain contingent earnout payments of up to $40.0 million. 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 $165.0 million during such calendar years, with an annual cap of $20.0 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 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, amounts received pursuant to the Supply and Exchange Agreements as described below and the ABL Facility (see Note 6).

Prior to the Execution Date, the Seller had commenced activities to shutdown the Refinery and to convert it into an import terminal. The Purchase Agreement contains certain pre-closing covenants, including covenants related to the startup of operations at the Refinery (the “Refinery Startup Activities”). The expenses associated with the Refinery Startup Activities were approximately $28.0 million (the “Startup Expenses”). Pursuant to the terms of the Purchase Agreement, Hawaii Pacific Energy made an initial deposit of $15.0 million for the Startup Expenses on the Execution Date. The next $5.0 million of Startup Expenses were borne by the Seller, with all Startup Expenses in excess of $20.0 million borne by Hawaii Pacific Energy. Due to the Startup Expenses exceeding $20.0 million, Hawaii Pacific Energy made an additional deposit of $7.0 million for the Startup Expenses on August 5, 2013.  In addition, Hawaii Pacific Energy funded $2.3 million on July 23, 2013 for a major overhaul of a gas turbine engine used in the operations of the refinery's steam cogeneration. These amounts are considered as additional consideration for the Purchased Units.

 Supply and Exchange Agreements

On September 25, 2013 and in connection with the acquisition by Hawaii Pacific Energy of the Purchased Units, HIE entered into the following agreements with Barclays Bank PLC, a public limited company organized under the laws of England and Wales (“Barclays”): (i) a framework agreement (the “Framework Agreement”) to which Hawaii Pacific Energy is also a party; (ii) a 2002 ISDA Master Agreement, including the Schedule thereto, the Oil Annex incorporated therein, the 1994 Credit Support Annex (New York law), the Initial Crude Purchase Confirmation, the Initial Product Purchase Confirmation, the Crude Oil Supply Master Confirmation, the Oil Products Exchange Master Confirmation, the Products Offtake Master Confirmation and the Confirmation of Forward Purchase Agreement for Refined Products (collectively, the “ISDA Agreement”); (iii) a storage and services agreement (the “Storage and Services Agreement”); and (iv) an agency and advisory agreement (the “Advisory Agreement” and, collectively with the Framework Agreement, ISDA Agreement and Storage and Services Agreement, the “Supply and Exchange Agreements”).

Pursuant to the Supply and Exchange Agreements, Barclays purchased the crude oil and refined product inventory owned by HIE on the Effective Date, and following the Effective Date, will (A) provide crude oil supply and intermediation arrangements to meet the processing needs of HIE’s petroleum refinery located at the Campbell Industrial Park in Kapolei, Hawaii (the “Refinery”), (B) provide a refined product exchange mechanism to HIE permitting it to flow volumes of refined product through Barclay’s inventory, and (C) store its crude oil and refined product inventory at the terminals and related facilities owned and operated by HIE.

Set forth below are certain of the additional material terms of the Supply and Exchange Agreements:

Term: The Supply and Exchange Agreements will remain in effect for three years following the Effective Date, subject to HIE’s right to extend the term for two additional one-year terms.

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Covenants: The Supply and Exchange Agreements require HIE and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting their respective businesses and operations, including compliance by HIE with a minimum liquidity requirement.

Exclusivity: During the term of the Supply and Exchange Agreements, HIE agrees not to purchase crude oil from any party other than Barclays, except for purchases of an amount and grade of crude oil roughly equivalent to that set forth in a transaction supplement pursuant to the ISDA Agreement that has been rejected by Barclays three consecutive times.

Collateral: All obligations arising under the Supply and Exchange Agreements are secured by a lien in favor of Wells Fargo Bank, N.A., as collateral agent for Barclays (in such capacity, the “Inventory Agent”), on substantially all of HIE’s assets, including, but not limited to, the Refinery and all of its accounts receivable, facilities, real property and improvements, pursuant to an inventory first lien security agreement (the “Inventory Security Agreement”), an inventory second lien security agreement (the “Inventory Second Lien Security Agreement”) and a first lien mortgage (the “Inventory Mortgage”). The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the collateral, are subject to an intercreditor agreement dated as of the Effective Date (the “HIE Intercreditor Agreement”), among Barclays, the Inventory Agent, Deutsche Bank AG New York Branch, acting as collateral agent under the ABL Facility (as defined below) and as administrative agent under the ABL Facility, and Hawaii Pacific Energy and HIE, as grantors. In addition, pursuant to the ISDA Agreement, HIE may be required to provide additional credit support to Barclays in the form of cash, letters of credit and/or negotiable debt obligations of the U.S. Treasury Department.

Guaranty and Pledge by Hawaii Pacific Energy: Hawaii Pacific Energy has granted a security interest in favor of the Inventory Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “Inventory Pledged Collateral”) pursuant to a Membership Interests First Lien Pledge Agreement in favor of the Inventory Agent (the “Inventory Pledge Agreement”). The obligations of HIE under the Supply and Exchange Agreements are guaranteed by Hawaii Pacific Energy, however, the recourse of the Inventory Agent under Hawaii Pacific Energy’s guaranty is limited to the Inventory Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the Inventory Pledged Collateral, are subject to the HIE Intercreditor Agreement.

The purchase of the purchased units was accounted for as a business combination in accordance with ASC 805 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 is defined in ASC 805 as the future economic benefit of other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is attributable to opportunities expected to arise from combining our operations with HIE’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 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.

The purchase price allocation is tentative and preliminary. We may have material changes to working capital, goodwill and various other assets and liabilities as better information becomes available in the fourth quarter.

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

Property, plant and equipment	$	66,144
Land		39,800
Goodwill		5,203
Intangible assets		4,782
Net working capital		462,427
Contingent consideration liability		(10,500	)
Other noncurrent liabilities		(8,249	)
Total, net of cash acquired	$	559,607

The acquisition was partially funded from net proceeds totaling approximately $384.9 million from the Supply and Exchange Agreements described above. We incurred approximately $1.0 million of expense associated with the acquisition. The results of operations of HIE are included in our consolidated statement of operations beginning September 25, 2013. We have not presented pro forma results for Predecessor periods as those Predecessor periods are not comparable to the current periods.

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(5) Inventories

Inventories at September 30, 2013 consist of the following:

	Titled Inventory		Supply and Exchange Agreements		Total
Crude oil and feedstocks	$	—	$	128,871	$	128,871
Refined products and blend stock		49,841		199,094		248,935
Warehouse stock and other		17,992		—		17,992
	$	67,833	$	327,965	$	395,798

(6) Debt

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 $30.0 million. We borrowed $13.0 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 the nine months ended September 30, 2013, we borrowed an additional $17.0 million for general corporate use.  As of September 30, 2013, we have no capacity for future borrowings under this Loan Agreement.

Below are certain of the material terms of the Loan Agreement:

Interest. At our election, any Loans will bear interest at a rate equal to 9.75% per annum payable either (i) in cash, quarterly, in arrears at the end of each calendar quarter or (ii) in-kind, accruing quarterly. In addition, all repayments made under the Loan Agreement will be charged a minimum of a 3% repayment premium. Accordingly, we will accrue amounts due for the minimum repayment premium over the term of loan using the effective interest method.

At any time after an event of default under the Loan Agreement has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 11.75% and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. We may prepay Loans at any time, in any amount. Such prepayment is to include all accrued and unpaid interest on the portion of the obligations being prepaid through the prepayment date. If at any time within the twelve months following the Emergence Date, we prepay the obligations due, in whole, but not in part, then in addition to the repayment of 100% of the principal amount of the obligations being prepaid plus accrued and unpaid interest thereon, we are required to pay the interest that would have accrued on the prepaid amount through the first anniversary of the Emergence Date plus a 6% prepayment premium.

In addition to the above described prepayment premium, we will pay an additional repayment premium equal to the percentage of the principal repaid during the following periods: 

Period	Repayment  Premium
From the Emergence Date through the first anniversary of the Emergence Date		3	%
From the day after the first anniversary of the Emergence Date through the second anniversary of the Emergence Date		2	%

We are also required to make certain mandatory repayments after certain dispositions of property, debt issuances, and joint venture distributions from Piceance Energy, casualty events and equity issuances, in each case subject to customary reinvestment provisions. These mandatory repayments are subject to the prepayment premiums described above.

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The contingent repayments described above are required to be accounted for as an embedded derivative. The estimated fair value of the embedded derivative at issuance was approximately $65,000 and was recorded as a derivative liability with the offset to debt discount. Subsequent changes in fair value are reflected in earnings (see Note 7).

Collateral. The Loans and all obligations arising under the Loan Agreement are secured by (i) a perfected, first-priority security interest in all of our assets other than our equity interest in Piceance Energy held by Par Piceance Energy Equity, LLC, one of our wholly owned subsidiaries (“Par Piceance Energy Equity”) , pursuant to a pledge and security agreement made by us and certain of our subsidiaries in favor of the Agent, and (ii) a perfected, second-lien security interest in our equity interest in Piceance Energy held by Par Piceance Energy Equity, pursuant to a pledge agreement by Par Piceance Energy Equity in favor of the Agent. The priority of the Lenders’ security interest in our assets is specified in that certain intercreditor agreement (the “Intercreditor Agreement”), among JPMorgan Chase Bank, N.A., as administrative agent for the First Priority Secured Parties (as defined in the Intercreditor Agreement), the Agent, as administrative agent for the Second Priority Secured Parties (as defined in the Intercreditor Agreement), the Company and Par Piceance Energy Equity.

Guaranty. All of our obligations under the Loan Agreement are unconditionally guaranteed by the Guarantors.

Fees and Commissions. We agreed to pay the Agent an annual nonrefundable administrative fee that was earned in full on the Emergence Date. In addition, we agreed to pay the Lenders a nonrefundable closing fee that was earned in full on the Emergence Date.

Warrants. As consideration for granting the Loans, we have also issued warrants to the Lenders to purchase shares of our common stock as described under “– Warrant Issuance Agreement” below.

Term. All loans and all other obligations outstanding under the Loan Agreement are payable in full on August 31, 2016.

Covenants. The Loan Agreement has no financial covenants that we are required to comply with; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations with which we were in compliance at September 30, 2013.

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 $35.0 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 a Letter of Credit Facility with Compass Bank (as described below). The Tranche B Loan was refinanced and replaced on July 24, 2013 by the New Tranche B Loan (as described below).

On April 19, 2013, we entered into a Fourth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Fourth Amendment:

Lender Consent to Compressor Disposition. The Lenders agreed that, in connection with the previous sale of our natural gas compressor assets held for sale (see Note 2) (a) 50% of the net cash proceeds are to be applied to pay (i) first, an amendment fee and (ii) second, to repay the Tranche B Loan in accordance with each Tranche B Lender’s pro rata share, and (ii) 50% of the net cash proceeds are to be retained by us and used for general corporate purposes.

Collateral. The Lenders agreed to the release of their liens and security interests on the assets of Texadian, including a release of any lien on the equity interests of Texadian pledged by us, and a release of Texadian from its guarantee under the Loan Agreement, if necessary. Such releases will only be made in connection with the closing of a definitive trade finance credit facility by Texadian and is subject in all respects to the satisfaction of the conditions to release described in the Fourth Amendment.

Mandatory Prepayment. Net cash proceeds of asset dispositions (other than as a result of a casualty), debt issuances and equity issuances can no longer be invested by us, and must be used to prepay the Loan Agreement, other than net cash proceeds from asset sales for fair market value resulting in no more than $150,000 in net cash proceeds per disposition (or series of related dispositions) and less than $300,000 in aggregate net cash proceeds before the Maturity Date.

Maturity Date. The Lenders agreed to extend the maturity date of the Tranche B Loan to December 31, 2013.

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With the execution of the Fourth Amendment, we repaid approximately $1.3 million of the Tranche B Loan.

On June 4, 2013, we entered into a Fifth Amendment to our Loan Agreement allowing us to form a subsidiary, Hawaii Pacific Energy, in furtherance of our acquisition of HIE.

On June 12, 2013, we entered into a Sixth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Sixth Amendment:

Pledge of Equity Interests. We are expressly permitted to pledge our equity interests in Texadian to secure the loans and other obligations of Texadian and Texadian Canada under the Uncommitted Credit Agreement (as described below).

Capital Contributions. We are permitted to make up to an aggregate amount of $5 million of capital contributions and/or loans to Texadian per year.

In connection with Hawaii Pacific Energy's entry into the Purchase Agreement, on June 17, 2013, we entered into a Seventh Amendment to the Loan Agreement.

Set forth below are certain of the material terms of the Seventh Amendment:

Lender Consent to Purchase Agreement. The Lenders consented to the execution of the Purchase Agreement by Hawaii Pacific Energy, and the performance of Hawaii Pacific Energy's obligations thereunder.

Lender Consent to Refinery Startup Reimbursement. The Lenders consented to the payment by Hawaii Pacific Energy of a cash deposit of up to $25 million, in addition to the reimbursement obligations specified in the Purchase Agreement in connection with the Refinery Startup Activities.

Lender Consent to the Consummation of the Acquisition of HIE. The Lenders consented to our use of any advance under the Loan Agreement to consummate the acquisition of HIE pursuant to the Purchase Agreement.

Lender Consent to Purchase Agreement Guaranty. The Lenders consented to the execution of our guaranty of certain obligations under the Purchase Agreement.

On June 24, 2013, we entered into an Eighth Amendment to our Loan Agreement, pursuant to which the Lenders agreed to refinance and replace the Tranche B Loan outstanding immediately prior to the Eighth Amendment with new Tranche B Loans in the aggregate principal amount of $65.0 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Existing Tranche B Loans, to make payments due under the Purchase Agreement, to consummate acquisitions permitted under the Loan Agreement and for working capital and general corporate purposes.

Set forth below are certain of the material terms of the New Tranche B Loans:

Interest. The New Tranche B Loans will bear interest (a) through September 29, 2013 at a rate equal to 9.75% per annum payable, at our election, either (i) in cash or (ii) in-kind, and (b) from and after September 29, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in-kind.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. 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.

Collateral. 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.

Guaranty. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

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Fees and Commissions. 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. Accordingly, we will accrete amounts due for the nonrefundable exit fee over the term of loan using the effective interest method.

Maturity Date. The New Tranche B Loans mature and are payable in full on August 31, 2016.

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to our Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the Purchase Agreement and the use of a portion of the proceeds from the sale of our common stock in a private transaction to fund a portion of the consideration in connection with the transactions contemplated by the Purchase Agreement and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the 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 Purchase Agreement and the sale of our common stock.

The consent provided by the Lenders was conditioned on, among other things, (A) 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 the proceeds from the sale of our common stock and (B) the proceeds from the sale of our common stock being used to consummate the transactions contemplated by the Purchase Agreement.

Set forth below are certain of the additional material terms of the Tenth Amendment:

Interest: The term loans (other than the New Tranche B Loans that remain outstanding following the repayment described above) under the Loan Agreement will bear 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.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

The New Tranche B Loans will 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.

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 ABL credit agreement (the “ABL Facility”) with Deutsche Bank AG New York Branch, as administrative agent and ABL loan collateral agent (in such capacities, the “ABL Agent”) for the lenders party thereto from time to time, including Deutsche Bank AG New York Branch (collectively, the “ABL Lenders”), pursuant to which the ABL Lenders agreed 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.

Set forth below are certain of the material terms of the ABL Facility:

Interest: 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). Notwithstanding the foregoing, for the remainder of the current fiscal year of the ABL Borrowers, the margin will be 1.25% for Base Rate loans and 2.25% for LIBO Rate loans. 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 LIBO Rate for a particular interest period is equal to the rate determined by the ABL Agent at approximately 11:00 a.m. (London time) on the date that is two business days prior to the commencement of the particular interest period by reference to the Reuters Screen LIBOR01 for deposits in dollars for a particular interest period.

 

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Collateral: 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, including, but not limited to, accounts receivable, inventory that we own, the Refinery and all of its facilities, real property and improvements, pursuant to an ABL loan second lien security agreement, an ABL loan first lien security agreement and a second lien mortgage. The rights and remedies of the ABL Agent and ABL Lenders and the priority of the ABL Agent’s security interest in the collateral are subject to the HIE Intercreditor Agreement.

Guaranty and Pledge by HPE: Hawaii Pacific Energy has granted a security interest in favor of the ABL Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “ABL Pledged Collateral”) pursuant to a Membership Interests Second Lien Pledge Agreement in favor of ABL Agent. The obligations of the ABL Borrowers under the ABL Facility are guaranteed by Hawaii Pacific Energy, however, the recourse of the ABL Agent under Hawaii Pacific Energy’s guaranty is limited to the ABL Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the ABL Agent, and the priority of the ABL Agent’s security interest in the ABL Pledged Collateral, are subject to the HIE Intercreditor Agreement.

Fees and Commissions: 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.

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

Covenants: 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.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly owned subsidiary Texadian Canada entered into an uncommitted credit agreement with BNP Paribas, as the initial lender party thereto, and BNP Paribas, as the administrative agent and collateral agent for the lenders and as an issuing bank (the “Uncommitted Credit Agreement”). The Uncommitted Credit Agreement 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 $50.0 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 September 30, 2013, Texadian was in compliance with these covenants.

Letter of Credit Facility

On December 27, 2012, we entered into a letter of credit facility agreement with Compass Bank, as the lender (the “Compass Letter of Credit Facility”). The Compass Letter of Credit Facility, which matures on December 26, 2013, provides for a letter of credit facility in an aggregate principal amount of $30.0 million that is available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries’ account. Letters of credit issued under the Compass Letter of Credit Facility are secured by an amount of cash pledged and delivered by us to Compass equal to one hundred five percent (105%) of the undrawn amount of all outstanding letters of credit. We agreed to pay a letter of credit fee equal to one and one half percent (1.5%) per annum of the stated face amount of each letter of credit for the number of days such letter of credit is to remain outstanding plus standard and customary administrative fees. The Compass Letter of Credit Facility does not contain any financial covenants; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations. The Compass Letter of Credit Facility was terminated on June 7, 2013.

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In connection with the acquisition of Texadian, Compass Bank issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.71 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that either of the following letters of credit is drawn: (i) the letter of credit issued by DNB Bank, ASA in favor of Suncor Energy Marketing Inc., with an original maturity date of February 5, 2013; or (ii) the letter of credit issued by DNB Bank, ASA in favor of Cenovus Energy Marketing Services Limited, with an original maturity date of February 5, 2013. Those letters of credit have been terminated and released.

Cross Default Provisions

Included within each of the Company’s 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.

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 9,592,125 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 $0.01 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 Warrant Shares issued on the Emergence Date was determined based on the number of shares of our common stock issued as allowed claims on or about the Emergence Date by the Bankruptcy Court pursuant to the Plan of Reorganization. The Warrant Issuance Agreement provides that the number of Warrant Shares and the Exercise Price shall be adjusted in the event that any additional shares of common stock or securities convertible into common stock (the “Unresolved Bankruptcy Shares”) are authorized to be issued under the Plan by the Bankruptcy Court after the Emergence Date as a result of any unresolved bankruptcy claims under the Plan. Upon each issuance of any Unresolved Bankruptcy Shares, the Exercise Price shall be reduced to an amount equal to the product obtained by multiplying (A) the Exercise Price in effect immediately prior to such issuance or sale, by (B) a fraction, the numerator of which shall be (x) 147,655,815 and (y) the denominator of which shall be the sum of (1) 147,655,815 and (2) and the number of additional Unresolved Bankruptcy Shares authorized for issuance under the Plan. Upon each such adjustment of the Exercise Price, the number of Warrant Shares shall be increased to the number of shares determined by multiplying (A) the number of Warrant Shares which could be obtained upon exercise of such Warrant immediately prior to such adjustment by (B) a fraction, the numerator of which shall be the Exercise Price in effect immediately prior to such adjustment and the denominator of which shall be the Exercise Price in effect immediately after such adjustment. In the event that any Lender or its affiliates fails to fund its pro rata portion of any Loans required to be made under the Loan Agreement, then the number of Warrant Shares exercisable under the Warrants held by such Lender will be reduced to an amount equal to the product of (i) the number of Warrant Shares initially exercisable under the Warrant held by the Lender and (ii) a fraction equal to one minus the quotient obtained by dividing (x) the amount of Loans previously made under the Loan Agreement by such Lender by (y) such Lender’s full commitment for Loans.

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 September 30, 2013, we issued an additional 2,232,934 Unresolved Bankruptcy Shares. This entitles the Lenders to receive an additional 145,057 Warrant Shares based on the formula described above increasing the total Warrant Shares to 9,737,182 at September 30, 2013.

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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 will be amortized over the life of the Loan Agreement, using the effective interest method. Subsequent changes in the fair value of the Warrants are reflected in earnings (see Note 7).

Summary

Our debt at September 30, 2013 is as follows (in thousands):

Delayed Draw Term Loan Agreement, including interest in-kind	$	32,389
New Tranche B Loan, including interest in-kind		18,760
ABL Facility		21,000
Less: unamortized debt discount – warrants and embedded derivative		(4,701	)
Total debt, net of unamortized debt discount		67,448
Less: current maturities		—
Long term debt, net of current maturities and unamortized discount	$	67,448

 Interest and financing costs consists of the following:

	Three Months Ended September 30, 2013		Nine Months Ended September 30,  2013
	(in thousands)
Interest accrued in kind	$	2,395	$	5,196
Amortization of debt discount relating to the warrants and embedded derivative		493		1,372
Accretion of 3% repayment premium on the Delayed Draw Term Loan Agreement		24		72
Accretion of 5% exit fee on the Tranche B Loan		—		1,750
Accretion of 2.5% exit fee on the New Tranche B Loan		909		1,078
Amortization of deferred loan costs		35		247
Miscellaneous		79		91
Interest and financing costs, net	$	3,935	$	9,806

(7) Fair Value Measurements

We follow accounting guidance which defines fair value, establishes a framework for measuring fair value in U.S. GAAP, and requires additional disclosures about fair value measurements. As required, we applied the following fair value hierarchy:

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 transfer 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. These valuation policies are determined by our Chief Financial Officer, with the assistance of third party experts as needed, and approved by our Chief Executive Officer. They are discussed with our Audit Committee as

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deemed appropriate. Each quarter, our Chief Financial Officer and Chief Executive Officer update the inputs used in the fair value measurement and internally review the changes from period to period for reasonableness. 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 Measure at Fair Value on a Nonrecurring Basis

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 the Level 3 valuation techniques described in notes (a) through (g) described below.

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,427		(a)
Property, plant and equipment		66,144		(b)
Land		39,800		(c)
Trade names and trade marks		4,782		(d)
Goodwill		5,203		(e)
Contingent consideration liability		(10,500	)	(f)
Other noncurrent liabilities		(8,249	)	(g)
	$	559,607

(a) Current assets acquired and liabilities assumed were recorded at their estimated fair 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.

(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

Derivative liabilities associated with our debt agreement – Derivative liabilities include the Warrants and fair value is estimated using an income valuation technique 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 the stock price of $1.81 per share, initial exercise price $0.01, term of 8.92 years, risk free rate of 2.42%, and expected volatility of 72.5%. 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 $1.79 per share, or approximately $17.4 million, as of September 30, 2013. 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.

In addition, our Loan Agreement contains 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 consider the contingent prepayment feature to be an embedded derivative

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which was bifurcated from the loan and accounted for as a derivative. The fair value of the embedded derivative is 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 September 30, 2013, we estimate the fair value of the embedded derivative to be $153,000 based on the probability of us repaying the loan prior to maturity.

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 September 30, 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 September 30, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts except for contracts treated as normal purchase or normal sale contracts as discussed in our Summary of Significant Accounting Policies.

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 $10.5 million as described in (f) above. The liability will be 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 September 30, 2013.

Our liabilities measured at fair value on a recurring basis as of September 30, 2013 consist of the following (in thousands):

	September 30, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Derivatives:
Warrants	$	(17,437	)	$	—	$	—	$	(17,437	)
Contingent consideration liability		(10,500	)	$	—		—		(10,500	)
Embedded derivatives		(153)			—		—		(153	)
	$	(28,090	)	$	—	$	—	$	(28,090	)

	Location on Consolidated Balance Sheet	Fair Value at September 30, 2013
		(in thousands)
Warrant derivatives	Noncurrent liabilities	$	(17,437	)
Contingent consideration liability	Noncurrent liabilities	$	(10,500	)
Embedded derivative	Noncurrent liabilities	$	(153	)

A rollforward of Level 3 derivative warrants and the embedded derivative measured at fair value using Level 3 on a reoccurring basis for the nine months ended September 30, 2013 is as follows (in thousands):

Description
Balance, at December 31, 2012	$	(10,945	)
Purchases, issuances, and settlements		(10,500	)
Total unrealized losses included in earnings		(6,645	)
Transfers		—
Balance, at September 30, 2013	$	(28,090	)

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

	For the three months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(1,390	)
Embedded derivatives	Other income (expense)		285
Commodities - exchange traded futures	Other income (expense)		—
Commodities - physical forward contracts	Other income (expense)		—

	For the nine months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(6,645	)
Embedded derivatives	Other income (expense)		45
Commodities - exchange traded futures	Other income (expense)		104
Commodities - physical forward contracts	Other income (expense)		306

(8) Commitments and Contingencies

Environmental Matters

Like other petroleum refiners, 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.

Hawaii Consent Decree On September 25, 2013, Hawaii Pacific Energy, Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities relating to the acquisition of HIE, including the Consent Decree as described below.

Tesoro is currently negotiating a consent decree with the United States Environmental Protection Agency (“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 by Tesoro and its affiliates (the “Consent Decree”), including the Refinery.  It is anticipated that the Consent Decree will be finalized sometime during the first quarter of 2014 and will require certain capital improvements to the 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 of the Purchase Agreement (the “Closing Date”). Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, this obligation terminates on the third anniversary of the Closing Date.

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Regulation of Greenhouse Gases The EPA began regulating greenhouse gases in January 2011 under the Clean Air Act Amendment of 1990 (the “Clean Air Act”).  Any new construction or material expansions will require that, among other things, a greenhouse gas permit be issued at either or both the state or federal level in accordance with the Clean Air Act regulations, and we will be required to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce greenhouse gas emissions.  The determination would be on a case by case basis, and the EPA has provided only general guidance on which controls will be required or delegated to the states through State Implementation Plans.

Furthermore, the 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 but have not yet been delineated.  Any such controls, however, 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 34, which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed by two years, the Hawaii Department of Health (“DOH”) is on schedule to finalize and issue regulations by the end of 2013 that would require each major facility to reduce CO2 emission by 16% by 2020 relative to calendar year 2010 baseline (the first year in which greenhouse gas was reported to the EPA under 40 CFR Part 98). 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 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 16.55 billion gallons of renewable fuel usage in 2013, increasing 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 productions and logistic challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase credits from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.

In October 2010, the EPA issued a partial waiver decision under the 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 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 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 May 2013, the EPA published a proposed Tier 3 gasoline standard that would lower the allowable sulfur level in gasoline to 10 ppm, lower the standards for Reid vapor pressure, and also lower the allowable benzene, aromatics and olefins content of gasoline, while possibly increasing octane requirements. The proposed 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 have already filed extensive comments and intend to challenge the proposed 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.

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, including preference actions, fraudulent transfer and conveyance actions, rights of setoff and other claims, or causes of action under the U.S.

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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.

On September 19, 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. Further distributions are not anticipated from the Wapiti Trust and the Wapiti Trust is anticipated to be 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 former Chief Executive Officer is the 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 for each of the Recovery Trusts, subject to the terms of the respective trust agreements 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 September 30, 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, 106 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 202,753 shares of common stock.  Pursuant to the Plan, during the nine months ended September 30, 2013, the Recovery Trustee settled an additional 47 claims with an aggregate face amount of $17.5 million for approximately $2.7 million in cash and 2,013,773 shares of common stock.

As of September 30, 2013, it is estimated that a total of 34 claims totaling approximately $49.6 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. In addition, litigation and/or settlement efforts are ongoing with other claim holders.

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 544 shares per $1,000 of claim. At September 30, 2013, we have reserved approximately $6.4 million 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:

	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	$	22,364,000		—	$	—	$	—		—		3	$	22,364,000
Former Employee Claims		32		16,379,849		13		3,685,253		229,478		202,231		19		12,694,596
Macquarie Capital (USA) Inc.		1		8,671,865		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		—		—		—		—		1		3,200,000
Other Various Claims*		69		23,113,659		12		2,914,859		29,427		522		57		20,198,800
Total		106	$	73,729,373		25	$	6,600,112	$	258,905		202,753		81	$	67,129,261

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	For the Nine Months Ended September 30, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364,000
Former Employee Claims		19		12,694,596		339,588		1,614,988		—		—
Macquarie Capital (USA) Inc.		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		2,000,000		—		—		—
Other Various Claims*		26		1,620,177		397,754		398,785		31		18,578,623
Total		47	$	17,514,773	$	2,737,342		2,013,773		34	$	49,614,488

* Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Subsequent to September 30, 2013, the Recovery Trustee settled the Macquarie Capital (USA) Inc. claim for $2.5 million in cash. In addition, two claims with an aggregate face amount of approximately $678,000 were settled for $145,000 in cash and 46,935 shares of common stock.

HIE

Operating Leases

HIE has 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. In general, these leases have remaining primary terms of up to 32 years and typically contain multiple renewal options.

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. HIE has 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.

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

2013	$	12,105
2014		11,312
2015		10,384
2016		9,432
2017		8,712
Thereafter		32,172
Total minimum rental payments	$	84,117

Capital Leases

HIE’s capital lease obligations relate 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		968
Total minimum rental payments	$	1,782

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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 purchase commitment during the initial term is approximately $28.0 million.

As of September 30, 2013, Texadian had various agreements to lease 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. Leases generally range in duration of five years or less and contain lease renewal options at fair value.

 (9) Stockholders’ Equity

Common Stock

On September 13, 2013, we entered into the Common Stock Purchase Agreement pursuant to which we agreed to sell, contemporaneously with the consummation of the acquisition of HIE, shares of our common stock at a price of $1.39 per share (the “Shares”) in a private transaction (the “Stock Sale”). 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 Stock Sale and issued 143,884,892 Shares. The Stock Sale resulted in aggregate gross proceeds to us of approximately $200.0 million. We did not engage any investment advisors with respect to the Stock Sale, and no finders’ fees or commissions will be paid to any party in connection therewith. The Shares have been issued and sold by us in a private placement transaction in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933, as amended.

During the nine months ended September 30, 2013, we issued approximately 2,014,000 shares of our common stock for settlement of bankruptcy claims and approximately 3,129,000 shares of restricted and unrestricted common stock to certain key employees and directors.

Registration Rights Agreement

In connection with the closing of the sale of the Shares, we entered into a registration rights agreement (the “Registration Rights Agreement”), with the purchasers of the Shares. Under the Registration Rights Agreement, we agreed to file a registration statement relating to the Shares 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.

The 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, the Registration Rights Agreement contains customary indemnification rights and obligations for both us and the holders of registrable securities.

If the 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 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

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purchaser’s allocated purchase price per calendar month, not to exceed 0.75% of the allocated purchase price. We will accrue an obligation for the 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 16 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.

On December 31, 2012, a total of 2,191,834 shares of our restricted common stock were granted to members of the Board of Directors and certain key employees. During the nine months ended September 30, 2013, an additional 3,094,168 shares of our restricted stock were granted to certain key 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 nine months ended September 30, 2013, the following activity occurred under our Incentive Plan:

	Shares		Weighted- Average Grant Date Fair Value
Stock Awards:
Non vested balance, beginning of period		2,191,834	$	1.09
Granted		3,094,168		1.77
Vested		—		—
Forfeited		—		—
Non vested balance, end of period		5,286,002	$	1.49

For the three and nine months ended September 30, 2013, we recognized compensation costs of approximately $210,000 and $491,000, respectively, related to the restricted stock awards. As of September 30, 2013, there are approximately $6.3 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 4.6 years. The grant date fair value was estimated using the previous 20 days average trading price of our common stock.

(10) 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 $230 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

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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 continues to conclude 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 September 30, 2013.

During the three and nine month periods ended September 30, 2013, 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.  State income tax expense of approximately $0 and $650,000 was recognized for the three and nine months ending September 30, 2013, respectively.

During 2013 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.

(11) Earnings Per Share

Basic earnings per share (“EPS”) are 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, representing 9,737,182 shares (see Note 5 and 6). U.S. GAAP requires the inclusion of these Warrants in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation as these shares are not considered earned until vesting. The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share amounts):

	Successor			Successor			Predecessor
	Three Months Ended September 30,  2013			One Month  Ended September 30,  2012			Two Months Ended August 31,  2012
Net loss attributable to common stockholders	$	(14,620	)	$	(2,002	)	$	(16,062	)
Basic weighted-average common stock outstanding		167,523			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		167,523			157,248			28,841
Basic loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)
Diluted loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)

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

	Successor		Successor		Predecessor
	Three Months  Ended September 30, 2013		One Month  Ended September 30, 2012		Two Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

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	Successor			Successor			Predecessor
	Nine Months Ended  September 30,  2013			One Month  Ended  September 30,  2012			Eight Months  Ended August 31, 2012
Net loss attributable to common stockholders	$	(28,650	)	$	(2,002	)	$	(45,437	)
Basic weighted-average common stock outstanding		161,633			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		161,633			157,248			28,841
Basic loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)
Diluted loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)

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

	Successor		Successor		Predecessor
	Nine Months  Ended September 30,  2013		One Month  Ended September 30,  2012		Eight Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

(12) Segment Information

Following our acquisitions of HIE and Texadian, we have four business segments, (i) natural gas and oil exploration and production, (ii) commodity transportation and marketing (iii) refining and (iv) retail. The retail segment is comprised of 31 retail locations that sell various refined products and merchandise to customers located across Oahu, Maui and Hawaii. Summarized financial information concerning reportable segments consists of the following (in thousands):

For the three months ended September 30, 2013:	Natural Gas and Oil Exploration and Production			Commodity Transportation  and Marketing		Refining		Retail		Trust Litigation and Settlements		Total
Sales and operating revenues	$	2,182		$	4,598	$	26,133	$	2,472	$	—	$	35,385
Operating income		648			1,952		405		494		(549)		2,950
Loss from unconsolidated affiliate		(907	)		—		—		—		—		(907	)
Capital expenditures		37			—		—		—		—		37
Capital additions from acquisitions*		—			—		101,103		4,670		—		105,773
Depreciation, depletion, amortization and accretion		519			599		96		—		—		1,214

For the nine months ended September 30, 2013:	Natural Gas  and Oil Exploration and Production			Commodity Transportation and Marketing		Refining		Retail		Trust Litigation and Settlements			Total
Sales and operating revenues	$	5,988		$	100,355	$	26,133	$	2,472	$	—		$	134,948
Operating income (loss)		483			13,773		405		494		(5,713	)		9,442
Loss from unconsolidated affiliate		(1,773	)		—		—		—		—			(1,773	)
Capital expenditures		128			—		—		—		—			128
Capital additions from acquisitions*		—			—		101,103		4,670		—			105,773
Depreciation, depletion, amortization and accretion		1,291			1,631		96		—		—			3,018

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* Includes only amounts capitalized as property, plant and equipment from the acquisition of HIE.

At September 30, 2013, our reportable segment assets consisted of the following (in thousands):

	Natural Gas  and Oil Exploration and Production		Commodity Transportation  and Marketing		Refining		Retail		Trust Litigation and Settlements		Total
Current assets	$	3,273	$	33,847	$	489,056	$	6,441	$	720	$	533,337
Property and equipment, net		4,697		47		103,715		2,120		—		110,579
Investments in unconsolidated affiliates		102,923		—		—		—		—		102,923
Goodwill and other intangible assets, net		—		15,593		9,801		—		—		25,394
Other long term assets		9		—		17,132		—		—		17,141
Totals	$	110,902	$	49,487	$	619,704	$	8,561	$	720	$	789,374

Reconciliation of reportable segment assets to our consolidated totals is as follows (in thousands):

	September 30,  2013
Total assets for reportable segments	$	789,374
Cash and restricted cash not allocated to segments		33,064
Property and equipment		4,446
Prepaid expenses and other assets		1,230
Total assets	$	828,114

For the comparable periods in 2012, 100% of our activities were natural gas and oil exploration and production so no comparable segment information has been provided.

(13) 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 6).

On September 17, 2013 (but effective January 1, 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 $50,000 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 unless 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.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Overview

Based in Houston, Texas, we are a diversified energy holding company created through the successful reorganization of Delta Petroleum (NYSE: DPTR) in August 2012. The reorganization converted $265.0 million of unsecured debt to equity and allowed us to preserve significant tax attributes. Currently, we maintain interests in a variety of energy-related assets including assets located in the Piceance Basin, a crude oil logistics business focused on moving Canadian crude oil to the Gulf Coast and an integrated refinery, distribution and marketing business in Hawaii.

Our natural gas weighted holdings consist of a 33.34% interest in a joint venture entity called Piceance Energy, LLC (“Piceance Energy”). The remaining ownership interest in Piceance Energy is held by Laramie Energy II, LLC (“Laramie”), which manages the day to day operations of the joint venture. 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.

In December 2012, we acquired Texadian Energy, Inc. (“Texadian”) (formerly known as SEACOR Energy, Inc.) for $14.0 million in cash, plus $4.0 million in working capital. Texadian’s focus is the sourcing, marketing, transportation and distribution of crude oil and refined products. Texadian’s 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 United States.

On September 25, 2013, we acquired Hawaii Independent Energy, LLC (“HIE”) (formerly known as Tesoro Hawaii, LLC (“Tesoro Hawaii”)) for $75.0 million in cash, plus or minus adjustments for net working capital, plus adjustments for inventories at closing, plus certain contingent earn out payments of up to $40.0 million.  We also contributed approximately $22.0 million for renovation and improvements at the refinery and funded $2.3 million for a major overhaul of a gas turbine used at the refinery.  HIE is an integrated refined products business serving Hawaii and owns a refinery in Kapolei, Hawaii (the “Refinery”) that has approximately 94,000 barrels per day of throughput capacity, 2.4 million barrels of crude oil and feedstock storage and 2.5 million barrels of refined products storage. The Refinery processes ultra-low sulfur diesel, gasoline, jet fuel, marine fuel and other associated refined products. HIE’s logistics assets include five refined products terminals, 27 miles of pipelines, a single point mooring and other associated logistics assets. In addition, HIE owns 31 retail outlets located across the islands of Oahu, Maui and Hawaii.

As a result of these transactions, our results of operations for any period after September 30, 2013 will not be comparable to any period before September 30, 2013.  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 at Texadian, which will be dependent primarily on marketing and transportation revenues.  But we anticipate our 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 operations.  The difference, or spread, between crude oil prices and the prices we receive for finished products (also known as the “crack spread”) will be the primary driver of the refinery’s results of operations and therefore, of our own profitability.

Reorganization under Chapter 11

In December  2011, Delta Petroleum Corporation (“Delta”) and its subsidiaries Amber Resources Company of Colorado, DPCA, LLC, Delta Exploration Company, Inc., Delta Pipeline, LLC, DLC, Inc., CEC, Inc. and Castle Texas Production Limited Partnership 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”). In January 2012, Castle Exploration Company, Inc., a subsidiary of Delta Pipeline, LLC, also filed a voluntary petition under Chapter 11 in the Bankruptcy Court. Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In December 2011, the Debtors filed a motion requesting an order to approve matters relating to a proposed sale of Delta’s assets, including bidding procedures, establishment of a sale auction date and establishment of a sale hearing date. In January 2012, the Bankruptcy Court issued an order approving these matters. In March 2012, Delta announced that it was seeking court approval to amend the bidding procedures for its upcoming auction to allow bids relating to potential plans of reorganization as well as asset sales. In March 2012, the Bankruptcy Court approved the revised procedures.

Following the auction, the Debtors obtained approval from the Bankruptcy Court to proceed with Laramie as the sponsor of the Plan of Reorganization by which Laramie and Delta intended to form Piceance Energy as a new joint venture. In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with Piceance Energy and Laramie to effect the transactions contemplated by Plan.

On June 4, 2012, the Debtors filed a disclosure statement relating to the Plan of Reorganization. The Plan was confirmed on August 16, 2012 and was declared effective on August 31, 2012 (the “Emergence Date”). On the Emergence Date, Delta consummated the transactions contemplated by the Contribution Agreement and each of Delta and Laramie contributed to

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Piceance Energy their respective assets in the Piceance Basin. Piceance Energy is owned 66.66% by Laramie and 33.34% by Delta (referred to after the closing of the transaction as “Successor”). 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 repaid 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 147.7 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 governs the operations of Piceance Energy (the “LLC Agreement”). For a description of this agreement, see “– Piceance Energy – Piceance Energy LLC Agreement” below.

In addition, Laramie and Piceance Energy entered into a Management Services Agreement pursuant to which Laramie provides certain services to Piceance Energy for a fee of $650,000 per month.

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. Under the amended and restated bylaws, the Company’s board of directors has five members, each of whom was appointed by our stockholders pursuant to a Stockholders’ Agreement entered into on the Emergence Date.

Fresh Start Accounting and the Effects of the Plan

As required by U.S. generally accepted accounting principles (“U.S. GAAP”), effective as of August 31, 2012, we adopted fresh start accounting following the guidance of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 852 “Reorganizations” (“ASC 852”). Fresh start accounting 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 “Predecessor”) and are not comparable to consolidated financial statements presented on or after August 31, 2012. Accordingly, certain disclosures relating to the Predecessor’s financial statements for the two and eight months ended August 31, 2012 have been omitted. Fresh start accounting 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 accounting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities.

Piceance Energy

Laramie is a Denver-based company primarily focused on finding and developing natural gas reserves from unconventional gas reservoirs within the Rocky Mountain Region. Laramie is backed by equity capital commitments funded by Laramie’s management team, EnCap Investments, Avista Capital, and DLJ Merchant Banking Partners (an affiliate of Credit Suisse Securities).

All of the assets contributed to Piceance Energy are located within Garfield and Mesa Counties, Colorado and are within a 10-mile radius in the Piceance Basin geologic formation. All of the natural gas and oil reserves contributed to Piceance Energy produce from the same geologic formations, the Mesaverde and Mancos Formations, and some of the contributed acreage is contiguous.

Piceance Energy, LLC Agreement

In connection with the consummation of the Contribution Agreement, as discussed under “- Reorganization under Chapter 11”, Laramie and Par Piceance Energy Equity LLC, one of our wholly owned subsidiaries (“Par Piceance Energy Equity”), entered into the LLC Agreement. The business of Piceance Energy is to own the natural gas and oil, surface real estate, and related assets formerly owned by Laramie and us in Garfield and Mesa Counties, Colorado, or other assets subsequently acquired by Piceance Energy, and to operate such assets. Pursuant to the LLC Agreement, Piceance is managed by Laramie, which controls its day-to-day operations, subject to the supervision of a six-person board, four (4) of which were appointed by Laramie and two

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(2) of which were appointed by Par Piceance Energy Equity. Certain major decisions require the unanimous consent of the board. The LLC Agreement provides that the sole manager, which is initially Laramie, 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 the 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. The LLC Agreement also contains certain restrictions on transfers by the members of their units. One such restriction provides that in the event one member elects to sell or transfer a majority of its units, the other member may elect to participate in such sale. The LLC Agreement also provides that under certain circumstances, a member desiring to transfer all, but not less than all, of its units may require the other member to participate in such transfer.

Piceance Energy Credit Facility

On June 4, 2012, Piceance Energy entered into a credit facility, (as amended, the “Piceance Energy Credit Facility”), with J.P. Morgan Securities LLC and Wells Fargo Securities LLC, each as an arranger, JPMorgan Chase Bank, N.A., as the administrative agent (the “Administrative Agent”), and the lenders party thereto. The Piceance Energy Credit Facility is a $400 million secured revolving credit facility secured by a lien on Piceance Energy’s natural gas and oil properties and related assets. Par Piceance Energy Equity and Laramie are each guarantors of the Piceance Energy Credit Facility, with recourse limited to the pledge of the equity interests of Par Piceance Energy Equity and Laramie in Piceance Energy.

Availability under the Piceance Energy Credit Facility is limited to the lesser of (i) $400 million or (ii) the borrowing base in effect from time to time. The initial borrowing base at the Emergence Date was set at $140 million. The borrowing base is determined by the Administrative Agent and the lenders, in their sole discretion, based on customary lending practices, review of the natural gas and oil properties included in the borrowing base, financial review of Piceance Energy, and such other factors as may be deemed relevant. The borrowing base is redetermined (i) on or about March 15 of each year based on the previous December 31 reserve report prepared by an independent engineering firm acceptable to the Administrative Agent, and (ii) on or about September 15 of each year based on the previous June 30 reserve report prepared by Piceance Energy’s internal engineers. The borrowing base was redetermined on March 12, 2013 and set at $140 million. In connection with the consummation of the Contribution Agreement, Piceance Energy borrowed $100 million under the Piceance Energy Credit Facility and distributed approximately $72.6 million of that amount to us and approximately $24.9 million to Laramie. The total amount outstanding under the Piceance Energy Credit Facility of September 30, 2013 is approximately $90.0 million.

The Piceance Energy Credit Facility will mature on June 4, 2016. Amounts borrowed bear interest at rates ranging from LIBOR plus 1.75% to LIBOR plus 2.75% per annum for Eurodollar loans and the prime rate plus 0.75% to prime rate plus 1.75% per annum for Base Rate loans, depending upon the ratio of outstanding credit to the borrowing base. The agreement contains customary operational and financial covenants, including a current ratio covenant, a total debt to consolidated EBITDAX covenant and a borrowing base covenant. At September 30, 2013, Piceance Energy was in compliance with all such covenants. Under the terms of the Piceance Energy Credit Facility, Piceance Energy is generally prohibited from making future cash distributions to its owners, including Par Piceance Energy Equity.

HIE

On September 25, 2013, we acquired Tesoro Hawaii. Tesoro Hawaii’s assets include the Kapolei refinery, 31 retail stations and the associated logistical assets. Following the acquisition, Tesoro Hawaii was renamed “Hawaii Independent Energy, LLC.”

Refining.  Our 94,000 barrel per day Hawaii refinery is located in Kapolei on approximately 130 acres about 20 miles west of Honolulu. Barclays Bank PLC supplies the refinery with crude oil from South America, Southeast Asia, the Middle East, Russia and other foreign sources. The Refinery's major processing units include crude distillation, vacuum distillation, visbreaking, hydrocracking, hydrotreating, and naphtha reforming units, which produce gasoline and gasoline blendstocks, jet fuel, diesel fuel, heavy fuel oils, liquefied petroleum gas and asphalt.

Transportation. Crude oil is transported to Hawaii in tankers, which discharge through our single-point mooring, approximately two miles offshore from the refinery. Our three underwater pipelines from the single-point mooring allow crude oil and refined products to be transferred to and from the refinery. We own and operate a refined products pipeline from our Hawaii refinery to the Sand Island terminal, which we operate, and to third-party terminals on the island of Oahu. Furthermore, our four refined products pipelines connect the Hawaii refinery to Barbers Point Harbor, approximately three miles away, where refined products are loaded on ships and barges to transport to the neighboring islands. The Barbers Point Harbor pipelines are also connected to other third-party origination and destination points. We operate a proprietary trucking business at our Hawaii refinery to transport refined products to other customers.

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Terminals.  We operate refined products terminals on Maui and on the Island of Hawaii and operate a diesel terminal on Oahu. We also operate an aviation fuel terminal on Kauai, and distribute refined products from our refinery to customers through third-party terminals in our market areas.

Wholesale Marketing and Refined Product Distribution. We sell refined products including gasoline and gasoline blendstocks, jet fuel, diesel fuel, heavy fuel oils and residual products in both the bulk and wholesale markets. We currently sell in the wholesale market primarily through independent unbranded distributors that sell refined products purchased from us through our terminal. Our bulk sales are primarily to independent unbranded distributors, utilities, airlines, the military and marine and industrial end-users. These products are primarily distributed by pipelines, ships, barges, and trucks. Our sales include refined products that we manufacture or purchase.

Jet Fuel. We supply jet fuel to passenger and cargo airlines at airports in Hawaii. We also supply military grade jet fuel to locations in Hawaii. The demand for jet fuel is seasonal.

Gasoline and Gasoline Blendstocks.  We sell gasoline and gasoline blendstocks in both the bulk and wholesale markets in Hawaii. We sell, at wholesale, to unbranded distributors and high-volume retailers, and we distribute refined product through owned terminals.

Diesel Fuel.  We sell diesel fuel primarily on a wholesale basis for marine, transportation, industrial and agricultural use. We sell lesser amounts to end-users through marine terminals and for power generation in Hawaii.

Heavy Fuel Oils and Residual Products.  We sell heavy fuel oils to other refiners, third-party resellers, electric power producers and marine and industrial end-users through our refinery and terminals in Hawaii. We are also a supplier of liquid asphalt.

Texadian Energy, Inc.

We acquired Texadian in December 2012. Texadian currently focuses on the trading of crude oil, transportation, and storage for third parties of hydrocarbon fluids used in the manufacturing or development of energy products in North America. Our business strategy is to transport oil from low cost production areas in Canada to Woodriver, Illinois or the Gulf Coast of the United States. We recently finalized a contract for a terminal in Harford, Illinois. The contract is a terminal agreement for crude oil storage and blending facilities. As a part of this contract, we will have access to two tanks currently under construction with a total capacity of 340,000 barrels along with 300,000 barrels of dock space. The facility began operation on September 1, 2013 and construction of the tanks is expected to be completed in the fourth quarter of 2013. In addition, we provide tow and barge services and lease railcars.

Operations Overview

During the first eight months of 2012, we focused on our restructuring while operating as a debtor in possession under Chapter 11 of the U.S. Bankruptcy Code. Our operations consisted of maintaining and operating existing natural gas and oil properties with no significant exploration or drilling activities. Effective August 31, 2012, we emerged from Chapter 11 of the U.S. Bankruptcy Code. Since then, our operations primarily consisted of activities related to our minority ownership interest in Piceance Energy, Texadian which we acquired effective December 31, 2012, and HIE which we acquired effective September 25, 2013. A discussion of operations follows.

Results of Operations

For this discussion, we will sometimes refer to Par post bankruptcy as the “Successor” and to Delta pre-bankruptcy as the “Predecessor”. The following discussion and analysis relates to items that have affected the Successor’s results of operations for three months ended September 30, 2013, and the results of operations of the Successor for the month ended September 30, 2012 and the Predecessor for the two months ended August 31, 2012.

Successor three months ended September 30, 2013 compared to Successor month ended September 30, 2012 and Predecessor two 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 acquisitions of HIE effective September 25, 2013.

Net Loss. Net loss was approximately $14.6 million, or a loss of $0.09 per basic and diluted common share, for the three months

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ended September 30, 2013, compared to a net loss of approximately $2.0 million, or a loss of $0.01 per basic and diluted common share, for the month ended September 30, 2012 and a net loss of approximately $16.1 million, or a loss of $0.56 per basic and diluted common share, for the two months ended August 31, 2012.

Operating Revenues.For the three months ended September 30, 2013, our operating revenues was approximately $33.2 million, consisting of refining revenues totaling approximately $26.1 million, retail revenues of approximately $2.5 million and marketing and transportation revenues of approximately $4.6 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. For the three months ended September 30, 2013, tow and barge revenues was approximately $1.3 million. Pipeline transportation and rail car lease revenues totaled approximately $2.9 million.

Natural Gas and Oil Sales. For the three months ended September 30, 2013, natural gas and oil sales was approximately $2.2 million. For the one and two months ended September 30, 2012 and August 31, 2012, respectively, natural gas and oil sales were approximately $584,000 and $5.5 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Cost of Revenues.For the three months ended September 30, 2013, our cost of revenues was approximately $30.7 million consisting of refining costs totaling approximately $26.6 million, retail costs of approximately $2.0 million, and marketing and transportation costs of approximately $2.1 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.  Barge transportation costs and dock space fees were approximately $600,000. Pipeline and rail car lease expense tariff expense was approximately $1.3 million.

Lease Operating Expense.For the three months ended September 30, 2013, lease operating expense was approximately $1.0 million. For the one and two months ended September 30, 2012 and August 31, 2012, respectively, lease operating expense were approximately $332,000 and $2.2 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Transportation Expense.For the three months ended September 30, 2013 and the one month ended September 30, 2012, we incurred no transportation expense.   For two months ended August 31, 2012, transportation expense was approximately $1.7 million. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Production Taxes. For the three months ended September 30, 2013, production taxes was approximately $15,000. For the one and two months ended September 30, 2012 and August 31, 2012, production taxes were approximately $3,000 and $180,000, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Depreciation, Depletion, Amortization and Accretion.For the three months ended September 30, 2013, depreciation, depletion, amortization and accretion expense was approximately $1.2 million. For the one and two months ended September 30, 2012 and August 31, 2012, depreciation, depletion, amortization and accretion expense were approximately $124,000 and $5.8 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Dry Hole Costs and Impairments. Dry hole costs and impairments for the two month period ended August 31, 2012 were approximately $151.3 million. On August 31, 2012, concurrent with the approval of the Plan, our oil and natural gas properties were reclassified to assets held for sale resulting in a fair value impairment of approximately $151.3 million.

Trust Litigation and Settlements. For the three months ended September 30, 2013, trust litigation and settlement expense was approximately $549,000.

General and Administrative Expense.For the three months ended September 30, 2013, the general and administrative expense was approximately $10.4 million. For the one and two months ended September 30, 2012 and August 31, 2012, general and administrative expense were approximately $356,000 and $1.7 million, respectively. Significant components of general and administrative expense for the three months ended September 30, 2013, include general and administrative expense related to HIE and Texadian totaling approximately $0.2 million and $1.0 million, respectively, professional fees of approximately $4.9 million including legal costs associated with our acquisition of HIE of $1.2 million, compensation and benefit expense of approximately $1.0 million, information technology expense of approximately $2.2 million and miscellaneous expense of approximately $1.1 million.

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Loss From Unconsolidated Affiliates. For the three months ended September 30, 2013, our allocated loss from Piceance Energy totaled approximately $907,000, which includes an operating loss of approximately $696,000 and financing costs of approximately $239,000 less a gain of approximately $35,000 from derivative obligations. For the month ended September 30, 2012, our allocated loss from our investment in Piceance Energy was approximately $1,525,000, which includes a $3.4 million loss from derivative activities and a loss of $921,000 from operating activities. 

Interest Expense and Financing Costs. For the three months ended September 30, 2013, our interest expense and financing costs was approximately $3.9 million consisting of interest accrued in kind totaling approximately $2.4 million, amortization of debt discount related to our Loan Agreement totaling approximately $493,000, accretion of the 2.5% exit penalty on our Tranche B Loans of approximately $909,000 and amortization of deferred loan costs of approximately $35,000. For the one and two months ended September 30, 2012 and August 31, 2012, interest expense and financing costs were approximately $246,000 and $2.0 million, respectively. The consummation of the Plan of Reorganization on August 31, 2012 resulted in a new capital structure for us.

Unrealized Loss of Derivative Instruments. For the three months ended September 30, 2013, we recognized an unrealized loss on our embedded derivative and warrant derivative liabilities of approximately $1.4 million due to mark to market adjustments resulting from an increase in the price of our common stock.

Income Taxes. For the three months ended September 30, 2013, we recorded no state tax expense. We recorded no Federal income tax expense or benefit in any period presented as 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 two months ended August 31, 2012, we recognized approximately $10.7 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 accounting adjustments, and a gain on the extinguishment of debt of approximately $168.3 million related to the settlement of our senior debt. There are no reorganization items in periods subsequent to August 31, 2012.

The following discussion and analysis relates to items that have affected the Successor’s results of operations for nine months ended September 30, 2013, the one month ended September 30, 2012 and the results of operations of the Predecessor for the eight months ended August 31, 2012.

Successor nine months ended September 30, 2013 compared to Successor one month ended September 30, 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 acquisitions of HIE effective September 25, 2013.

Net Loss. Net loss was approximately $28.7 million, or a loss of $0.18 per basic and diluted common share, for the nine months ended September 30, 2013, compared to a net loss of approximately $2.0 million, or a loss of $0.01 per basic and diluted common share, for the one month ended September 30, 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 nine months ended September 30, 2013, our operating revenues was approximately $129.0 million, consisting of refining revenues totaling approximately $26.1 million, retail revenues of approximately $2.5 million and marketing and transportation revenues of approximately $100.4 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. For the nine months ended September 30, 2013, tow and barge revenues was approximately $90.4 million. In addition, pipeline transportation and rail car leases totaled approximately $9.9 million.

Natural Gas and Oil Sales. For the nine months ended September 30, 2013, natural gas and oil sales was approximately $6.0 million. For the one month ended September 30, 2012 and eight months ended August 31, 2012, natural gas and oil sales were approximately $584,000 and $23.1 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Cost of Revenues. For the nine months ended September 30, 2013, our cost of revenues was approximately $113.6 million consisting of refining costs totaling approximately $26.6 million, retail costs of approximately $2.0 million, and marketing and transportation costs of approximately $85.0 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.  Cost of goods sold associated with tow and barge charters was approximately $73.5 million.  Related barge transportation costs and dock space fees were approximately $7.2 million. Pipeline and railcar lease expense was approximately $4.2 million.

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Lease Operating Expense. For the nine months ended September 30, 2013, lease operating expense was approximately $4.2 million. For the one month ended September 30, 2012 and eight months ended August 31, 2012, lease operating expenses were approximately $332,000 and $9.0 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Transportation Expense.For the nine months ended September 30, 2013 and the one month ended September 30, 2012, we incurred no transportation expense.   For the eight months ended August 31, 2012, transportation expense were 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.

Production Taxes. For the nine months ended September 30, 2013, production taxes was approximately $39,000. For the one month ended September 30, 2012 and eight months ended August 31, 2012, production taxes were approximately $3,000 and $979,000, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Dry Hole Costs and Impairments. 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 oil and natural gas properties were reclassified to assets held for sale resulting in a fair value impairment of approximately $151.3 million.

Depreciation, Depletion, Amortization and Accretion.For the nine months ended September 30, 2013, depreciation, depletion, amortization and accretion expense was approximately $3.0 million. For the one month ended September 30, 2012 and eight months ended August 31, 2012, depreciation, depletion, amortization and accretion expense were approximately $124,000 and $16.0 million, respectively. The decrease is primarily related to the contribution of the majority of our natural gas and oil assets to Piceance Energy.

Trust Litigation and Settlements.For the nine months ended September 30, 2013, trust litigation and settlement expense was approximately $5.7 million and consisted of professional fees relating to Recovery Trust activities paid through restricted cash of approximately $2.3 million and an increase in the settlement claim liability of approximately $3.9 million, offset by recoveries of approximately $500,000.

General and Administrative Expense.For the nine months ended September 30, 2013, general and administrative expense was approximately $19.4 million. For the one month ended September 30, 2012 and eight months ended August 31, 2012, general and administrative expense were approximately $356,000 and $9.4 million, respectively. Significant components of general and administrative expense for the nine months ended September 30, 2013, include general and administrative expense related to HIE and Texadian totaling approximately $0.2 million and $5.0 million, respectively, professional fees of approximately $8.6 million including legal costs associated with our acquisition of HIE of approximately $1.2 million, compensation and benefit expense of approximately $1.0 million, information technology expense of approximately $2.2 million and miscellaneous expense of approximately $2.4 million.

Loss From Unconsolidated Affiliates.For the nine months ended September 30, 2013, our allocated loss from Piceance Energy totaled approximately $1.8 million, which includes an operating loss of approximately $1.3 million and financing costs of approximately $713,000 less a gain of approximately $275,000 from derivative obligations. For the month ended September 30, 2012, our allocated loss from our investment in Piceance Energy was approximately $1,525,000, which includes a $3.4 million loss from derivative activities and a loss of $921,000 from operating activities. 

Interest Expense and Financing Costs.For the nine months ended September 30, 2013, our interest expense and financing costs was approximately $9.8 million consisting of interest accrued in kind totaling approximately $5.2 million, amortization of debt discount related to our Loan Agreement totaling approximately $1.4 million, accretion of the 5% and 2.5% exit penalties on our Tranche B Loans of approximately $1.8 million and $1.1 million, respectively, and amortization of deferred loan costs of approximately $245,000. For the one month ended September 30, 2012 and eight months ended August 31, 2012, interest expense and financing costs were approximately $246,000 and $6.9 million, respectively. The consummation of the Plan of Reorganization on August 31, 2012 resulted in a new capital structure for us.

Unrealized Loss of Derivative Instruments. For the nine months ended September 30, 2013, we recognized an unrealized loss on our embedded derivative and warrant derivative liabilities of approximately $6.6 million due to mark to market adjustments resulting from an increase in the price of our common stock.

Other Income.For the nine months ended September 30, 2013, other income totaled approximately $786,000 and consists

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primarily of a state tax refund totaling approximately $483,000 and a legal settlement of approximately $200,000. Other income for the one month ended September 30, 2012 was not significant. For the eight months ended August 31, 2012, other income was approximately $526,000.

Income Taxes. For the nine months ended September 30, 2013, we recorded a state tax expense of approximately $650,000 due to the operating results of Texadian. We recorded no Federal income tax expense or benefit in any period presented as 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 accounting adjustments, and a gain on the extinguishment of debt of approximately $168.7 million related to the settlement of our senior debt. There are no reorganization items in periods subsequent to August 31, 2012.

Liquidity and Capital Resources

As of September 30, 2013, we have access to the Texadian Uncommitted Credit Agreement and the ABL Facility, as described below, and unrestricted cash of $69.0 million. In addition, in conjunction with our acquisition of HIE, and to finance the acquisition and the operations of the business of HIE after the acquisition, we sold an aggregate of $200.0 million of our common stock in a private placement and entered into a crude oil supply and intermediation arrangement. Since the Emergence Date, the primary uses of our capital resources have been in the operations of Texadian and HIE, payment of operating expenses related to our natural gas and oil assets, acquisitions, professional fees, and bankruptcy expenses. Prior to our bankruptcy filing, our sources of liquidity and capital resources were cash provided through the issuance of debt and equity securities when market conditions permitted, operating activities, sales of natural gas and oil properties, and borrowings under our credit facilities. During bankruptcy proceedings, our principal sources of liquidity and capital resources were borrowings under the Predecessor’s secured debtor-in-possession credit facility and cash flows from operating activities.

Prior to our acquisitions of Texadian and HIE, our principal asset since the consummation of the Plan and our emergence from bankruptcy was a minority interest in Piceance Energy. Piceance Energy’s primary sources of liquidity are cash from operations and borrowings under the Piceance Energy Credit Facility. Piceance Energy’s ability to distribute cash to us under the Piceance Energy Credit Facility is subject to various covenants, by our need to satisfy our obligations under the Loan Agreement, and by potential capital contributions required to be made by us to Piceance Energy. We expect that the operations of HIE and Texadian will provide us with additional liquidity. We also expect to have minimal cash flows from certain assets not contributed to Piceance Energy pursuant to the Contribution Agreement on the Emergence Date.

We may be required to fund capital contributions of up to $20.0 million to Piceance Energy under the LLC Agreement. We expect that our capital contributions will be funded from available cash on hand, advances under the Loan Agreement, 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 the Common Stock Purchase Agreement pursuant to which we agreed to sell, shares of our common stock at a price of $1.39 per share (the “Shares”) in a private transaction (the “Stock Sale”). 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 Stock Sale and issued 143,884,892 Shares. The Stock Sale resulted in aggregate gross proceeds to us of approximately $200.0 million. We did not engage any investment advisors with respect to the Stock Sale, and no finders’ fees or commissions will be paid to any party in connection therewith however we did incur approximately $830,000 of other offering related expenses which have been netted with the proceeds we received as presented within Stockholders Equity. The Shares have been issued and sold by us in a private placement transaction in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933, as amended.

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

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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 $30.0 million. We borrowed $13.0 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 the nine months ended September 30, 2013, we borrowed an additional $17.0 million. As of September 30, 2013, we have no capacity for future borrowings under this Loan Agreement.

Below are certain of the material terms of the Loan Agreement:

Interest. At our election, any Loans will bear interest at a rate equal to 9.75% per annum payable either (i) in cash, quarterly, in arrears at the end of each calendar quarter or (ii) in-kind, accruing quarterly. In addition, all repayments made under the Loan Agreement will be charged a minimum of a 3% repayment premium. Accordingly, we will accrue amounts due for the minimum repayment premium over the term of loan using the effective interest method.

At any time after an event of default under the Loan Agreement has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 11.75% and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. We may prepay Loans at any time, in any amount. Such prepayment is to include all accrued and unpaid interest on the portion of the obligations being prepaid through the prepayment date. If at any time within the twelve months following the Emergence Date, we prepay the obligations due, in whole, but not in part, then in addition to the repayment of 100% of the principal amount of the obligations being prepaid plus accrued and unpaid interest thereon, we are required to pay the interest that would have accrued on the prepaid amount through the first anniversary of the Emergence Date plus a 6% prepayment premium.

In addition to the above described prepayment premium, we will pay an additional repayment premium equal to the percentage of the principal repaid during the following periods:

Period	Repayment  Premium
From the Emergence Date through the first anniversary of the Emergence Date		3	%
From the day after the first anniversary of the Emergence Date through the second anniversary of the Emergence Date		2	%

We are also required to make certain mandatory repayments after certain dispositions of property, debt issuances, and joint venture distributions from Piceance Energy, casualty events and equity issuances, in each case subject to customary reinvestment provisions. These mandatory repayments are subject to the prepayment premiums described above.

The contingent repayments described above are required to be accounted for as an embedded derivative. The estimated fair value of the embedded derivative at issuance was approximately $65,000 and was recorded as a derivative liability with the offset to debt discount. Subsequent changes in fair value are reflected in earnings.

Collateral. The Loans and all obligations arising under the Loan Agreement are secured by (i) a perfected, first-priority security interest in all of our assets other than our equity interest in Piceance Energy held by Par Piceance Energy Equity, pursuant to a pledge and security agreement made by us and certain of our subsidiaries in favor of the Agent, and (ii) a perfected, second-lien security interest in our equity interest in Piceance Energy held by Par Piceance Energy Equity, pursuant to a pledge agreement by Par Piceance Energy Equity in favor of the Agent. The priority of the Lenders’ security interest in our assets is specified in that certain intercreditor agreement (the “Intercreditor Agreement”), among JPMorgan Chase Bank, N.A., as administrative agent for the First Priority Secured Parties (as defined in the Intercreditor Agreement), the Agent, as administrative agent for the Second Priority Secured Parties (as defined in the Intercreditor Agreement), the Company and Par Piceance Energy Equity.

Guaranty. All of our obligations under the Loan Agreement are unconditionally guaranteed by the Guarantors.

Fees and Commissions. We agreed to pay the Agent an annual nonrefundable administrative fee that was earned in full on the Emergence Date. In addition, we agreed to pay the Lenders a nonrefundable closing fee that was earned in full on the Emergence Date.

Warrants. As consideration for granting the Loans, we have also issued warrants to the Lenders to purchase shares of our common stock as described under “– Warrant Issuance Agreement” below.

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Term. All loans and all other obligations outstanding under the Loan Agreement are payable in full on August 31, 2016.

Covenants. The Loan Agreement has no financial covenants that we are required to comply with; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations with which we are in compliance at September 30, 2013.

Amendment to the Loan Agreement

On December 28, 2012, in order to fund a portion of the purchase price for our acquisition of Texadian (see “–Capital and Exploration Expenditures” below), 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 Lendors”) agreed to extend additional borrowings to us (the “Tranche B Loan”). The total commitment of the Tranche B Loan of $35.0 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 the letter of credit facility with Compass Bank (as described below). The Tranche B Loan was refinanced and replaced on July 24, 2013 by the New Tranche B Loan (as described below).

On April 19, 2013, we entered into a Fourth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Fourth Amendment:

Lender Consent to Compressor Disposition. The Lenders agreed that, in connection with the previous sale of our natural gas compressor assets held for sale (a) 50% of the net cash proceeds are to be applied to pay (i) first, an amendment fee and (ii) second, to repay the Tranche B Loan in accordance with each Tranche B Lender’s pro rata share, and (ii) 50% of the net cash proceeds are to be retained by us and used for general corporate purposes.

Collateral. The Lenders agreed to the release of their liens and security interests on the assets of Texadian, including a release of any lien on the equity interests of Texadian pledged by us, and a release of Texadian from its guarantee under the Loan Agreement, if necessary. Such releases will only be made in connection with the closing of a definitive trade finance credit facility by Texadian and is subject in all respects to the satisfaction of the conditions to release described in the Fourth Amendment.

Mandatory Prepayment. Net cash proceeds of asset dispositions (other than as a result of a casualty), debt issuances and equity issuances can no longer be invested by us, and must be used to prepay the Loan Agreement, other than net cash proceeds from asset sales for fair market value resulting in no more than $150,000 in net cash proceeds per disposition (or series of related dispositions) and less than $300,000 in aggregate net cash proceeds before the Maturity Date.

Maturity Date. The Lenders agreed to extend the maturity date of the Tranche B Loan to December 31, 2013.

With the execution of the Fourth Amendment, we repaid approximately $1.3 million of the Tranche B Loan.

On June 4, 2013, we entered into a Fifth Amendment to our Loan Agreement allowing us to form a subsidiary, Hawaii Pacific Energy in furtherance of our acquisition of HIE.

On June 12, 2013, we entered into a Sixth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Sixth Amendment:

Pledge of Equity Interests. We are expressly permitted to pledge our equity interests in Texadian to secure the loans and other obligations of Texadian and Texadian Canada under the Uncommitted Credit Agreement (as described below).

Capital Contributions. We are permitted to make up to an aggregate amount of $5 million of capital contributions and/or loans to Texadian per year.

In connection with Hawaii Pacific Energy's entry into the Purchase Agreement, on June 17, 2013, we entered into a Seventh Amendment to the Loan Agreement.

Set forth below are certain of the material terms of the Seventh Amendment:

Lender Consent to Purchase Agreement. The Lenders consented to the execution of the Purchase Agreement by Hawaii

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Pacific Energy, and the performance of Hawaii Pacific Energy's obligations thereunder.

Lender Consent to Refinery Startup Reimbursement. The Lenders consented to the payment by Hawaii Pacific Energy of a cash deposit of up to $25 million, in addition to the reimbursement obligations specified in the Purchase Agreement in connection with the Refinery Startup Activities (as described below).

Lender Consent to the Consummation of the Acquisition of Tesoro Hawaii. The Lenders consented to our use of any advance under the Loan Agreement to consummate the acquisition of HIE pursuant to the Purchase Agreement.

Lender Consent to Purchase Agreement Guaranty. The Lenders consented to the execution of our guaranty of certain obligations under the Purchase Agreement.

On June 24, 2013, we entered into an Eighth Amendment to our Loan Agreement, pursuant to which the Lenders agreed to refinance and replace the Tranche B Loans outstanding immediately prior to the Eighth Amendment with new Tranche B Loans in the aggregate principal amount of $65.0 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were  applied to prepay in full the Existing Tranche B Loans, to make payments due under the Purchase Agreement (see Note 6), to consummate acquisitions permitted under the Loan Agreement and for working capital and general corporate purposes.

Set forth below are certain of the material terms of the New Tranche B Loans:

Interest. The New Tranche B Loans will bear interest (a) through September 29, 2013 at a rate equal to 9.75% per annum payable, at our election, either (i) in cash or (ii) in-kind, and (b) from and after September 29, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in-kind.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. 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.

Collateral. 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, LLC and its subsidiaries.

Guaranty. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

Fees and Commissions. We agreed to pay the Tranche B Lenders a nonrefundable exit fee equal to 2.5% of the aggregate amount of the 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 Tranche B Loans are paid in full. Accordingly, we will accrete amounts due for the nonrefundable exit fee over the term of loan using the effective interest method.

Maturity Date. The Tranche B Loans mature and are payable in full on August 31, 2016.

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to our Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the Purchase Agreement and the use of a portion of the proceeds from the sale of our common stock in a private transaction to fund a portion of the consideration in connection with the transactions contemplated by the Purchase Agreement and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the 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 Purchase Agreement and the sale of our common stock.

The consent provided by the Lenders was conditioned on, among other things, (A) 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 the proceeds from the sale of our common stock and (B) the proceeds from the sale of our common stock being used to consummate the transactions contemplated by the Purchase Agreement.

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Set forth below are certain of the additional material terms of the Tenth Amendment:

Interest: The term loans (other than the New Tranche B Loans that remain outstanding following the repayment described above) under the Loan Agreement will bear 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.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

The New Tranche B Loans will 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.

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 ABL credit agreement (the “ABL Facility”) with Deutsche Bank AG New York Branch, as administrative agent and ABL loan collateral agent (in such capacities, the “ABL Agent”) for the lenders party thereto from time to time, including Deutsche Bank AG New York Branch (collectively, the “ABL Lenders”), pursuant to which the ABL Lenders agreed 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.

Set forth below are certain of the material terms of the ABL Facility:

Interest: 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). Notwithstanding the foregoing, for the remainder of the current fiscal year of the ABL Borrowers, the margin will be 1.25% for Base Rate loans and 2.25% for LIBO Rate loans. 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 LIBO Rate for a particular interest period is equal to the rate determined by the ABL Agent at approximately 11:00 a.m. (London time) on the date that is two business days prior to the commencement of the particular interest period by reference to the Reuters Screen LIBOR01 for deposits in dollars for a particular interest period.

Collateral: 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, including, but not limited to, accounts receivable, the Refinery and all of its facilities, real property and improvements, pursuant to an ABL loan second lien security agreement, an ABL loan first lien security agreement and a second lien mortgage. The rights and remedies of the ABL Agent and ABL Lenders and the priority of the ABL Agent’s security interest in the collateral are subject to the HIE Intercreditor Agreement.

Guaranty and Pledge by HPE: Hawaii Pacific Energy has granted a security interest in favor of the ABL Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “ABL Pledged Collateral”) pursuant to a Membership Interests Second Lien Pledge Agreement in favor of ABL Agent. The obligations of the ABL Borrowers under the ABL Facility are guaranteed by Hawaii Pacific Energy, however, the recourse of the ABL Agent under Hawaii Pacific Energy’s guaranty is limited to the ABL Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the ABL Agent, and the priority of the ABL Agent’s security interest in the ABL Pledged Collateral, are subject to the HIE Intercreditor Agreement.

Fees and Commissions: 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

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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.

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

Covenants: 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.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly owned subsidiary Texadian Canada entered into an uncommitted credit agreement with BNP Paribas, as the initial lender party thereto, and BNP Paribas, as the administrative agent and collateral agent for the lenders and as an issuing bank (the “Uncommitted Credit Agreement”). The Uncommitted Credit Agreement 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 $50.0 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 September 30, 2013, Texadian was in compliance with these covenants.

Letter of Credit Facility

On December 27, 2012, we entered into a letter of credit facility agreement with Compass Bank, as the lender (the “Compass Letter of Credit Facility”). The Compass Letter of Credit Facility, which matures on December 26, 2013, provides for a letter of credit facility in an aggregate principal amount of $30.0 million that is available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries’ account. Letters of credit issued under the Compass Letter of Credit Facility are secured by an amount of cash pledged and delivered by us to Compass equal to one hundred five percent (105%) of the undrawn amount of all outstanding letters of credit. We agreed to pay a letter of credit fee equal to one and one half percent (1.5%) per annum of the stated face amount of each letter of credit for the number of days such letter of credit is to remain outstanding plus standard and customary administrative fees. The Compass Letter of Credit Facility does not contain any financial covenants; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations. The Compass Letter of Credit Facility was terminated on June 7, 2013.

In connection with the acquisition of Texadian, Compass Bank issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.71 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that either of the following letters of credit is drawn: (i) the letter of credit issued by DNB Bank, ASA in favor of Suncor Energy Marketing Inc., with an original maturity date of February 5, 2013; or (ii) the letter of credit issued by DNB Bank, ASA in favor of Cenovus Energy Marketing Services Limited, with an original maturity date of February 5, 2013. Those letters of credit have been terminated and released.

Warrant Issuance Agreement

Pursuant to the Plan, on the Emergence Date, we issued to the Lenders warrants (the “Warrants”) to purchase up to an aggregate of 9,592,125 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 $0.01 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.

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The number of Warrant Shares issued on the Emergence Date was determined based on the number of shares of our common stock issued as allowed claims on or about the Emergence Date by the Bankruptcy Court pursuant to the Plan. The Warrant Issuance Agreement provides that the number of Warrant Shares and the Exercise Price shall be adjusted in the event that any additional shares of common stock or securities convertible into common stock (the “Unresolved Bankruptcy Shares”) are authorized to be issued under the Plan by the Bankruptcy Court after the Emergence Date as a result of any unresolved bankruptcy claims under the Plan. Upon each issuance of any Unresolved Bankruptcy Shares, the Exercise Price shall be reduced to an amount equal to the product obtained by multiplying (A) the Exercise Price in effect immediately prior to such issuance or sale, by (B) a fraction, the numerator of which shall be (x) 147,655,815 and (y) the denominator of which shall be the sum of (1) 147,655,815 and (2) and the number of additional Unresolved Bankruptcy Shares authorized for issuance under the Plan. Upon each such adjustment of the Exercise Price, the number of Warrant Shares shall be increased to the number of shares determined by multiplying (A) the number of Warrant Shares which could be obtained upon exercise of such Warrant immediately prior to such adjustment by (B) a fraction, the numerator of which shall be the Exercise Price in effect immediately prior to such adjustment and the denominator of which shall be the Exercise Price in effect immediately after such adjustment. In the event that any Lender or its affiliates fails to fund its pro rata portion of any Loans required to be made under the Loan Agreement, then the number of Warrant Shares exercisable under the Warrants held by such Lender will be reduced to an amount equal to the product of (i) the number of Warrant Shares initially exercisable under the Warrant held by the Lender and (ii) a fraction equal to one minus the quotient obtained by dividing (x) the amount of Loans previously made under the Loan Agreement by such Lender by (y) such Lender’s full commitment for Loans.

From the Emergence Date through September 30, 2013, we issued an additional 2,232,934 Unresolved Bankruptcy Shares. This entitles the Lenders to receive an additional 145,057 Warrant Shares based on the formula described above increasing the total Warrant Shares to 9,737,182 at September 30, 2013.

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.

Cash Flows

	Successor			Successor		Predecessor
	Nine Months Ended September 30,  2013			One Month Ended September 30, 2012		Eight Months Ended August 31,  2012
	(In thousands)
Net cash provided by (used in) operating activities	$	9,032		$	(347)	$	(20,262	)
Net cash provided by (used in) investing activities	$	(562,675	)	$	—	$	72,622
Net cash provided by financing activities	$	616,502		$	2,000	$	(60,340)

Net cash provided by operating activities was approximately $9.0 million for the nine months ended September 30, 2013 which resulted from a net loss of approximately $28.6 million offset by non-cash charges to operations of approximately $21.6 million and net cash provided by changes in operating assets and liabilities of approximately $16.0 million. Net cash used by operating activities for the one month ended September 30, 2012 and eight months ended August 31, 2012 was approximately $347,000 and $20.2 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 effective December 31, 2012 and our acquisition of HIE on September 25, 2013.

For the nine months ended September 30, 2013, net cash used in investing activities was primarily related to the acquisition of HIE for approximately $559.6 million net of cash acquired, capitalized drilling costs and additions to property and equipment totaling approximately $4.6 million, approximately $1.0 million of cash restricted to support a letter of credit partially offset by proceeds of the sale of our assets held for sale of approximately $2.9 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 totaling approximately $74.2 million ($72.6 million net after working capital adjustments made in subsequent periods).

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Net cash provided by financing activities for the nine months ended September 30, 2013 of approximately $616.5 million resulted from advances from our supply and exchange agreements used to fund the HIE acquisition totaling approximately $384.9 million, the sale of common stock provided approximately $199.2 million, additional net borrowings under our Loan Agreement totaling approximately $66.7 million and the release of approximately $19.0 million from restricted cash held to secure letters of credit partially offset by repayment of borrowings totaling approximately $52.0 and payment of loan issue costs of approximately $2.3 million. For the one month ended September 30, 2012, net cash provided by financing activities totaled $2.0 million resulting from a recovery from the Wapati Trust. 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 debtor-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 and Exploration Expenditures

Our capital and exploration expenditures for the nine months ended September 30, 2013 totaled approximately $564.5 million and was primarily related to our acquisition of HIE as described below.

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 directors. We also continue to seek strategic investments in business opportunities, but the amount and timing of those investments are not predictable.

On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for approximately $14.0 million plus estimated net working capital of approximately $4.0 million at closing. Texadian operates an oil sourcing, marketing, transportation, distribution and marketing business with significant logistics capabilities in historical pipeline shipping status, a railcar fleet and tow and barge chartering. We acquired Texadian in furtherance of our growth strategy that focuses on the acquisition of income producing businesses.

Hawaii Independent Energy, LLC (formerly known as Tesoro Hawaii, LLC)

On June 17 , 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, LLC ("Hawaii Pacific Energy"), entered into a membership interest purchase agreement (the “Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the Purchase Agreement, Tesoro Hawaii. Pursuant to the 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)  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 HIE.

Hawaii Pacific Energy purchased the Purchased Units for $75.0 million, paid in cash at the closing of the Purchase Agreement, plus or minus adjustments for net working capital, plus adjustments for inventories at closing and plus certain contingent earnout payments of up to $40.0 million. 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 $165.0 million during such calendar years, with an annual cap of $20.0 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 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, amounts received pursuant to the Supply and Exchange Agreements as described below and the ABL Facility.

Prior to the Execution Date, the Seller had commenced activities to shutdown the Refinery and to convert it into an import terminal. The Purchase Agreement contains certain pre-closing covenants, including covenants related to the startup of operations at the Refinery (the “Refinery Startup Activities”). The expenses associated with the Refinery Startup Activities were

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approximately $28.0 million (the “Startup Expenses”). Pursuant to the terms of the Purchase Agreement, Hawaii Pacific Energy made an initial deposit of $15.0 million for the Startup Expenses on the Execution Date. The next $5.0 million of Startup Expenses were borne by the Seller, with all Startup Expenses in excess of $20.0 million borne by Hawaii Pacific Energy. Due to the Startup Expenses exceeding $20.0 million, Hawaii Pacific Energy made an additional deposit of $7.0 million for the Startup Expenses on August 5, 2013.  In addition, Hawaii Pacific Energy funded $2.3 million on July 23, 2013 for a major overhaul of a gas turbine engine used in the operations of the refinery's steam cogeneration. These amounts are considered as additional consideration for the Purchased Units.

 Supply and Exchange Agreements

On September 25, 2013 and in connection with the acquisition by Hawaii Pacific Energy of the Purchased Units, HIE entered into the following agreements with Barclays Bank PLC, a public limited company organized under the laws of England and Wales (“Barclays”): (i) a framework agreement (the “Framework Agreement”) to which Hawaii Pacific Energy is also a party; (ii) a 2002 ISDA Master Agreement, including the Schedule thereto, the Oil Annex incorporated therein, the 1994 Credit Support Annex (New York law), the Initial Crude Purchase Confirmation, the Initial Product Purchase Confirmation, the Crude Oil Supply Master Confirmation, the Oil Products Exchange Master Confirmation, the Products Offtake Master Confirmation and the Confirmation of Forward Purchase Agreement for Refined Products (collectively, the “ISDA Agreement”); (iii) a storage and services agreement (the “Storage and Services Agreement”); and (iv) an agency and advisory agreement (the “Advisory Agreement” and, collectively with the Framework Agreement, ISDA Agreement and Storage and Services Agreement, the “Supply and Exchange Agreements”).

Pursuant to the Supply and Exchange Agreements, Barclays purchased the crude oil and refined product inventory owned by HIE on the Effective Date, and, following the Effective Date, will (A) provide crude oil supply and intermediation arrangements to meet the processing needs of the Refinery, (B) provide a refined product exchange mechanism to HIE permitting it to flow volumes of refined product through Barclay’s inventory, and (C) store its crude oil and refined product inventory at the terminals and related facilities owned and operated by HIE.

Set forth below are certain of the additional material terms of the Supply and Exchange Agreements:

Term: The Supply and Exchange Agreements will remain in effect for three years following the Effective Date, subject to HIE’s right to extend the term for two additional one-year terms.

Covenants: The Supply and Exchange Agreements require HIE and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting their respective businesses and operations, including compliance by HIE with a minimum liquidity requirement.

Exclusivity: During the term of the Supply and Exchange Agreements, HIE agrees not to purchase crude oil from any party other than Barclays, except for purchases of an amount and grade of crude oil roughly equivalent to that set forth in a transaction supplement pursuant to the ISDA Agreement that has been rejected by Barclays three consecutive times.

Collateral: All obligations arising under the Supply and Exchange Agreements are secured by a lien in favor of Wells Fargo Bank, N.A., as collateral agent for Barclays (in such capacity, the “Inventory Agent”), on substantially all of HIE’s assets, including, but not limited to, the Refinery and all of its accounts receivable, facilities, real property and improvements, pursuant to an inventory first lien security agreement (the “Inventory Security Agreement”), an inventory second lien security agreement (the “Inventory Second Lien Security Agreement”) and a first lien mortgage (the “Inventory Mortgage”). The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the collateral, are subject to an intercreditor agreement dated as of the Effective Date (the “HIE Intercreditor Agreement”), among Barclays, the Inventory Agent, Deutsche Bank AG New York Branch, acting as collateral agent under the ABL Facility (as defined below) and as administrative agent under the ABL Facility, and Hawaii Pacific Energy and HIE, as grantors. In addition, pursuant to the ISDA Agreement, HIE may be required to provide additional credit support to Barclays in the form of cash, letters of credit and/or negotiable debt obligations of the U.S. Treasury Department.

Guaranty and Pledge by Hawaii Pacific Energy: Hawaii Pacific Energy has granted a security interest in favor of the Inventory Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “Inventory Pledged Collateral”) pursuant to a Membership Interests First Lien Pledge Agreement in favor of Inventory Agent (the “Inventory Pledge Agreement”). The obligations of HIE under the Supply and Exchange Agreements are guaranteed by Hawaii Pacific Energy, however, the recourse of the Inventory Agent under Hawaii Pacific Energy’s guaranty is limited to the Inventory Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the Inventory Pledged Collateral, are subject to the HIE Intercreditor Agreement.

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 Commitments and Contingencies

Environmental Matters

Like other petroleum refiners, 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.

Hawaii Consent Decree. On September 25, 2013, Hawaii Pacific Energy, Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities relating to the acquisition of HIE, including the Consent Decree described below.

Tesoro is currently negotiating a consent decree with the United States Environmental Protection Agency (“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 by Tesoro and its affiliates (the “Consent Decree”), including the Refinery. It is anticipated that the Consent Decree will be finalized sometime during the first quarter of 2014 and will require certain capital improvements to the refinery to reduce emissions of air pollutants.

It is not possible to predict 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 us arising from the Consent Decree to the extent related to acts or omission of Tesoro or HIE prior to the closing date of the Purchase Agreement (the “Closing Date”). Tesoro’s obligation to reimburse us for such fines and penalties is not subject to a monetary limitation; however, this obligation terminates on the third anniversary of the Closing Date.

Regulation of Greenhouse Gases. The EPA began regulating greenhouse gases in January 2011 under the Clean Air Act Amendment of 1990 (the “Clean Air Act”).  Any new construction or material expansions will require that, among other things, a greenhouse gas permit be issued at either or both the state or federal level in accordance with the Clean Air Act regulations, and we will be required to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce greenhouse gas emissions.  The determination would be on a case by case basis, and the EPA has provided only general guidance on which controls will be required or delegated to the states through State Implementation Plans.

Furthermore, the 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 but have not yet been delineated.  Any such controls, however, 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 34 which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed by two years, the Hawaii Department of Health (“DOH”) is on schedule to finalize and issue regulations by the end of 2013 that would require each major facility to reduce CO2 emission by 16% by 2020 relative to calendar year 2010 baseline (the first year in which greenhouse gas was reported to the EPA under 40 CFR Part 98). 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

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States by model year 2020, and contained a second Renewable Fuel Standard (the “RFS2”). In August 2012, the EPA and National Highway Traffic Safety Administration jointly adopted regulations that establish an average industry fuel economy of 54.5 miles per gallon by model year 2025. The RFS2 requires 16.55 billion gallons of renewable fuel usage in 2013, increasing 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 productions and logistic challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase credits from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.

In October 2010, the EPA issued a partial waiver decision under the 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 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 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 May 2013, the EPA published a proposed Tier 3 gasoline standard that would lower the allowable sulfur level in gasoline to 10 ppm, lower the standards for Reid vapor pressure, and also lower the allowable benzene, aromatics and olefins content of gasoline, while possible increasing octane requirements. The proposed 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 have already filed extensive comments and intend to challenge the proposed regulation.

There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in 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.

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.

On September 19, 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. Further distributions are not anticipated from the Wapiti Trust and the Wapiti Trust is anticipated to be 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 former Chief Executive Officer is the 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 for each of the Recovery Trusts, subject to the terms of the respective trust agreements 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 September 30, 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.

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The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. On the Emergence Date, 106 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 202,753 shares of common stock.  Pursuant to the Plan, during the nine months ended September 30, 2013, the Recovery Trustee settled an additional 47 claims with an aggregate face amount of $17.5 million for approximately $2.7 million in cash and 2,013,773 shares of common stock.

As of September 30, 2013, it is estimated that a total of 34 claims totaling approximately $49.6 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. In addition, litigation and/or settlement efforts are ongoing with other claim holders.

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 544 shares per $1,000 of claim. At September 30, 2013, we have reserved approximately $6.4 million 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:

	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	$	22,364,000		—	$	—	$	—		—		3	$	22,364,000
Former Employee Claims		32		16,379,849		13		3,685,253		229,478		202,231		19		12,694,596
Macquarie Capital (USA) Inc.		1		8,671,865		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		—		—		—		—		1		3,200,000
Other Various Claims*		69		23,113,659		12		2,914,859		29,427		522		57		20,198,800
Total		106	$	73,729,373		25	$	6,600,112	$	258,905		202,753		81	$	67,129,261

	For the Nine Months Ended September 30, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364,000
Former Employee Claims		19		12,694,596		339,588		1,614,988		—		—
Macquarie Capital (USA) Inc.		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		2,000,000		—		—		—
Other Various Claims*		26		1,620,177		397,754		398,785		31		18,578,623
Total		47	$	17,514,773	$	2,737,342		2,013,773		34	$	49,614,488

* Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Subsequent to September 30, 2013, the Recovery Trustee settled the Macquarie Capital (USA) Inc. claim for $2.5 million in cash. In addition, two claims with an aggregate face amount of approximately $678,000 were settled for $145,000 in cash and 46,935 shares of common stock.

HIE

Operating Leases.  HIE has 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. In general, these leases have remaining primary terms of up to 32 years and typically contain multiple renewal options.

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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. HIE has 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.

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

2013	$	12,105
2014		11,312
2015		10,384
2016		9,432
2017		8,712
Thereafter		32,172
Total minimum rental payments	$	84,117

Capital Leases. HIE’s capital lease obligations relate 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		968
Total minimum rental payments	$	1,782

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 purchase commitment during the initial term is approximately $28.0 million.

As of September 30, 2013, Texadian had various agreements to lease 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. Leases generally range in duration of five years or less and contain lease renewal options at fair value.

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 of our unaudited 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

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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.

Derivatives and Other Financial instruments

We may 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.

Texadian 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.  Texadian’s policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle.  Should Texadian not designate a contract as a normal purchase or normal sale or should a scheduled delivery under the terms of contract not occur, then these exceptions may require the recording of a derivative.  If derivative accounting treatment is required then these contracts would be recorded at fair value as either an asset or a liability and marked to market each reporting period with changes in fair value being charged to earnings.  As of September 30, 2013, we have elected the normal purchase or normal sale exemption for these derivative instruments.   As such, we did not recognize the unrealized gains or losses related to these designated derivative instruments in our consolidated financial statements. As of December 31, 2012, we did not elect this exemption for Texadian’s open contracts that 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, we issued warrants (see Note 6) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our delayed draw term loan facility contains certain puts that are 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.

Investment in unconsolidated affiliate

Investments in operating entities where we have the ability to exert significant influence, but do not control the operating and financial policies, are accounted for using the equity method. Our share of net income of these entities is recorded as income (losses) from unconsolidated affiliates in the consolidated statements of operations.

Impairment of Goodwill and Long-Lived Assets

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. Qualitative factors assessed for the reporting unit would include the competitive environments and financial performance of the reporting unit. 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, based upon a multiple of estimated earnings. 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. The fair value calculation uses Level 3 (see “Fair Value Measurements” below) inputs and includes multiple assumptions and estimates, including the projected cash flows and discount rates applied. Changes in these assumptions and estimates could result in goodwill impairment that could materially adversely impact our financial position or results of operations.

We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist under authoritative guidance. 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 fair value. These impairment

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tests are heavily influenced by assumptions and estimates that are subject to change as additional information becomes available.

Our natural gas and oil assets, including our investment in our unconsolidated affiliate, are reviewed for impairment quarterly or when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Estimates of expected future cash flows represent our best estimate based on reasonable and supportable assumptions and projections.

 For proved properties, if the expected future cash flows exceed the carrying value of the asset, no impairment is recognized. If the carrying value of the asset exceeds the expected future cash flows, an impairment exists and is measured by the excess of the carrying value over the estimated fair value of the asset. Any impairment provisions recognized are permanent and may not be restored in the future.

We assess proved properties on an individual field basis for impairment each quarter when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For proved properties, the review consists of a comparison of the carrying value of the asset with the asset’s expected future undiscounted cash flows without interest costs.

For unproved properties, the need for an impairment charge is based on our plans for future development and other activities impacting the life of the property and our ability to recover our investment. When we believe the costs of the unproved property are no longer recoverable, an impairment charge is recorded based on the estimated fair value of the property.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the net book values 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’ net book value. If this occurs, an impairment loss is recognized for the difference between the fair value and net book 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.

Asset Retirement Obligations

An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. Our AROs arise from plugging and abandonment liabilities for our natural gas and oil wells, as well as AROs arising from HIE's refinery and retail operations. We record 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. 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. 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

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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 primarily in operating expenses in our statements of consolidated operations.

Fair Value Measurements

We follow accounting guidance which defines fair value, establishes a framework for measuring fair value in U.S. GAAP, and requires additional disclosures about fair value measurements. As required, we applied the following fair value hierarchy:

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 transfer 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. These valuation policies are determined by our Chief Financial Officer, with the assistance of third party experts as needed, and approved by our Chief Executive Officer. They are discussed with our

Audit Committee as deemed appropriate. Each quarter, our Chief Financial Officer and Chief Executive Officer update the inputs used in the fair value measurement and internally review the changes from period to period for reasonableness. 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 Measure at Fair Value on a Nonrecurring Basis

Purchase Price Allocation of HIE – The preliminary fair values of the assets acquired and liabilities assumed as a result of the Tesoro Hawaii 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	$	462,427		(a)
Property, plant and equipment		66,144		(b)
Land		39,800		(c)
Trade names and trade marks		4,782		(d)
Goodwill		5,203		(e)
Contingent consideration liability		(10,500	)	(g)
Other noncurrent liabilities		(8,249	)	(g)
	$	559,607

(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.

(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.

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(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 a Monte Carlo Simulation analysis. 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 Recorded at Fair Value on a Recurring Basis

Derivative liabilities associated with our debt agreement – Derivative liabilities include the Warrants and fair value is estimated using an income valuation technique and 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 the stock price of $1.81 per share, initial exercise price $0.01, term of 8.92 years, risk free rate of 2.42%, and expected volatility of 72.5%. 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 $1.79 per share, or approximately $17.4 million, as of September 30, 2013. 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.

In addition, our Loan Agreement contains 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 consider 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 is 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 September 30, 2013, we estimate the fair value of the embedded derivative to be $153,000 based on the probability of us repaying the loan prior to maturity.

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 September 30, 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 September 30, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts except for contracts treated as normal purchase or normal sale contracts as discussed in our Summary of Significant Accounting Policies.

Contingent consideration liability – Our acquisition of HIE contains an earn out provision. The initial value was estimated to be approximately $10.5 million as described in (f) above. The liability will be 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 September 30, 2013.

Our liabilities measured at fair value on a recurring basis as of September 30, 2013 consist of the following (in thousands):

	September 30, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Derivatives:
Warrants	$	(17,437	)	$	—	$	—	$	(17,437	)
Contingent consideration liability		(10,500	)		—				(10,500	)
Embedded derivatives		(153	)		—		—		(153	)
	$	(28,090	)	$	—	$	—	$	(28,090	)

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	Location on Consolidated Balance Sheet	Fair Value at September30, 2013
		(in thousands)
Warrant derivatives	Noncurrent  liabilities	$	(17,437	)
Contingent consideration liability	Noncurrent  liabilities	$	(10,500	)
Embedded derivative	Noncurrent liabilities	$	(153	)

A rollforward of Level 3 derivative warrants and the embedded derivative measured at fair value using Level 3 on a reoccurring basis for the nine months ended September 31, 2013 is as follows (in thousands): 

Description
Balance, at December 31, 2012	$	(10,945	)
Purchases, issuances, and settlements		(10,500	)
Total unrealized losses included in earnings		(6,645	)
Transfers		—
Balance, at September 30, 2013	$	(28,090	)

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

	For the three months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(1,390	)
Embedded derivatives	Other income (expense)		285
Commodities - exchange traded futures	Other income (expense)		—
Commodities - physical forward contracts	Other income (expense)		—

	For the nine months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(6,645	)
Embedded derivatives	Other income (expense)		45
Commodities - exchange traded futures	Other income (expense)		104
Commodities - physical forward contracts	Other income (expense)		306

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Income Taxes

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 it 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 the Company. 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 continues to conclude 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 September 30, 2013.

 Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our net operating loss 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 net operating losses were incurred; therefore we expect to incur state tax liabilities on the net income of Texadian’s and HIE’s operations. State income tax expense of approximately $0 and $650,000 was recognized for the three and nine months ending September 30, 2013, respectively.

We will continue to assess the realizability of our deferred tax assets on a go forward basis taking into account 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.

During the three and nine months ended September 30, 2013, no adjustments were recognized for uncertain tax benefits.

Revenue Recognition

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, so that we 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 September 30, 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Marketing and Transportation. 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. Texadian earns 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 upon fulfillment of the contract.   Revenues from the rental of railcars are recognized ratably over the lease periods.

Refining and Retail.

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HIE recognizes 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 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

Refined Product Exchanges

HIE has entered into certain supply and exchange contracts whereby it agrees 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 that are settled in kind on a volumetric basis, 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

Texadian’s inventories, which consist of in-transit oil, are stated at the lower of cost or market. We record impairments, as needed, to adjust the carrying amount of inventories to the lower of cost or market.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 4. Legal title to the crude oil is held by Barclays and the crude oil is stored in HIE’s storage tanks for the benefit of Barclays pursuant to a storage agreement until it is needed for further use in the refining process. At that time, certain nominated volumes are drawn out of the storage tanks and purchased by us. After processing and subject to the supply and exchange agreements described in Note 4, Barclays takes title to the refined products when the refined products enters the tanks which are then stored in HIE’s storage tanks until sold at 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. Inventories are stated at the lower of cost or market. We use last-in, first-out as the primary method to determine the cost of crude oil and refined product inventories in our refining and retail segments. We value merchandise along with spare parts, materials and supplies at average cost.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Market Rate and Price Risk

Revenues from our natural gas and oil business are derived from the sale of our natural gas and oil production. Based on projected annual sales volumes for 2013, a 10% decline in the estimated average prices we expect to receive for our natural gas and oil production would have an approximate $0.7 million impact on our estimated 2013 natural gas and oil revenues, or approximately $0.2 million for the remainder of 2013.

Texadian enters and settles positions in various exchange traded commodity swap and future contracts. Texadian also enters into exchange traded positions to protect its inventory balances from market changes. As of September 30, 2013, we had no open positions relating to exchange derivative positions.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

In connection with the preparation of this Quarterly Report on Form 10-Q, as of September 30, 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 that as of September 30, 2013, these disclosure controls and procedures were not effective and not designed to ensure that the information required to be disclosed in our reports filed with the SEC is recorded, processed, summarized and reported on a timely basis, due to the existence of material weaknesses identified as of December 31, 2012 as discussed below.

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Prior to December 31, 2011, the Company filed for voluntary bankruptcy and during the duration of the proceedings, the Company’s ability to maintain effect internal control over financial reporting was weakened due to a high amount of turnover of its accounting staff. Because of the high turnover and low number of accounting personnel available, the Company was not able to timely file its Form 10-K as of December 31, 2011. Management concluded that internal control over financial reporting as of December 31, 2011 was not effective. As of August 31, 2012, the Company emerged from bankruptcy and replaced the operations and financial reporting functions with a new accounting group. During the fourth quarter of 2012, management performed a comprehensive assessment of the design and operating effectiveness of internal control over financial reporting. While performing the review of the design and operating effectiveness of internal control over final reporting, control gaps were identified in internal control and related processes that require remediation to be performed in order for management to conclude that internal control

over final reporting is effective in preventing the financial statements and related disclosures from being materially misstated. The internal control gap remediation to be performed by management was not completed as of December 31, 2012. Additionally, while completing our December 31, 2012 year end close process, adjustments were identified relating to the application of fresh start accounting that impacted the amounts, presentation of the financial statements and related disclosures previously reported at September 30, 2012 in our related Form 10-Q. Because of the items mentioned above, management concluded that material weaknesses exist in the operating effectiveness of internal control over financial reporting.

As of September 30, 2013, we believe these material weaknesses remain present and until our material weaknesses are remediated, there is a reasonable possibility that a material misstatement of our financial statements would not be prevented or detected on a timely basis. As part of our remediation efforts, we have contracted with experienced financial and accounting consultants to assist with our financial close and other accounting matters and in the preparation of the financial statements and related accounting and reporting disclosures. We are evaluating other remediation alternatives and efforts are in progress, however any contemplated changes to our internal control over financial reporting have not been implemented.

 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.

Changes in Internal Control over Financial Reporting

There have been no changes during the quarter ended September 30, 2013, in the Company’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financing reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

From time to time, we may be involved in litigation relating to claims arising out of our operations in the normal course of our business. As of the date of this report, no legal proceedings are pending against us that we believe individually or collectively could have a materially adverse effect upon our financial condition, results of operations or cash flows. Any litigation pending at the time we emerged from Chapter 11 was transferred to the Trust for resolution and settlement. See Note 8 to our unaudited consolidated financial statements included herein.

Item 1A. Risk Factors

Except as set forth below, there have been no material changes from the risk factors disclosed in the “Risk Factors” section of our Annual Report on Form 10-K for the year ended December 31, 2012.

The Tesoro Acquisition involves risks associated with acquisitions and integrating acquired businesses and the intended benefits of the Tesoro Acquisition may not be realized.

The Tesoro Acquisition involves risks associated with acquisitions and integrating acquired businesses into existing operations, including that:

· our senior management's attention, and a significant amount of our resources, may be diverted from the management of daily operations of our other businesses to the integration of HIE; 

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· we could incur significant unknown and contingent liabilities for which we have limited or no contractual remedies or insurance coverage;

· the businesses acquired in the Tesoro Acquisition may not perform as well as we anticipate; and

· unexpected costs, delays and challenges may arise in integrating HIE into our existing operations.

If we fail to integrate HIE into our existing businesses, or if we fail to realize the full benefits we anticipate from the Tesoro Acquisition, our business, results of operations and financial condition would be adversely affected.

Risks Related to our Petroleum Product Refining and Marketing Operations conducted by HIE

The volatility of crude oil prices, refined product prices andelectrical power prices may have a material adverse effect on HIE’s cash flow andresults of operations.

Earnings and cash flows from our refining and wholesale marketing operations depend on a number of factors, including to a large extent the cost of crude oil and other refinery feedstocks which has fluctuated significantly in recent years. While prices for refined products are influenced by the price of crude oil, the constantly changing margin between the price we pay for crude oil and other refinery feedstocks, and the spread between crude oil prices and the prices received for refined products, or the crack spread, also fluctuates significantly from time to time. These prices depend on numerous factors beyond our control, including the global supply and demand for crude oil, gasoline and other refined products, which are subject to, among other things:

· changes in the global economy and the level of foreign and domestic production of crude oil and refined products;

· availability of crude oil and refined products and the infrastructure to transport crude oil and refined products;

· local factors, including market conditions, the level of operations of other refineries in our markets, and the volume of refined products imported;

· threatened or actual terrorist incidents, acts of war, and other global political conditions;

· government regulations; and

· weather conditions, hurricanes or other natural disasters.

In addition, we purchase our refinery feedstocks weeks before manufacturing and selling the refined products. Price level changes during the period between purchasing feedstocks and selling the manufactured refined products from these feedstocks could have a significant impact on our financial results. We also purchase refined products manufactured by others for sale to our customers. Price level changes during the periods between purchasing and selling these refined products could also have a material adverse effect on our business, financial condition and results of operations.

Volatile prices for electrical power used by our refinery and other operations affect manufacturing and operating costs. Electricity prices have been, and will continue to be, affected by supply and demand for fuel and utility services in Hawaii.

Adverse changes in global economic conditions and the demand fortransportation fuels may impact our business and financial condition inways that we currently cannot predict.

The U.S. economic recovery from the recent recession continues to be tenuous, and the risk of further significant global economic downturn continues. Further prolonged downturns or failure to recover could result in declines in consumer and business confidence and spending as well as increased unemployment and reduced demand for transportation fuels. This continues to adversely affect the business and economic environment in which we operate. These conditions increase the risks associated with the creditworthiness of our suppliers, customers and business partners. The consequences of such adverse effects could include interruptions or delays in our suppliers’ performance of our contracts, reductions and delays in customer purchases, delays in or the inability of customers to obtain financing to purchase our products, and bankruptcy of customers. Any of these events may adversely affect our cash flow, profitability and financial condition.

Competition from integrated national and international oil companies that produce their own supply of feedstocks, larger independent refiners and from high volume retailers and large convenience store retailing operators who may have greater financial resources, could materially affect our business, financial condition and results of operations.

We compete with a number of integrated national and international oil companies who produce crude oil, some of which is used in their refining operations. Unlike these oil companies, we must purchase all of our crude oil from unaffiliated sources.

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Because these oil companies benefit from increased commodity prices, and as other larger independent refining companies have greater access to capital and have stronger capital structures, they are able to better withstand poor and volatile market conditions, such as a lower refining margin environment, shortages of crude oil and other feedstocks or extreme price fluctuations.

We also face strong competition in the fuel and convenience store retailing market for the sale of retail gasoline and convenience store merchandise. Our competitors include service stations operated by integrated major oil companies and well-recognized national high volume retailers or regional large chain convenience store operators, often selling gasoline or merchandise at aggressively competitive prices.

Some of these competitors may have access to greater financial resources, which may provide them with a better ability to bear the economic risks inherent in all phases of our industry. Fundamental changes in the supply dynamics of foreign product imports could lead to reduced margins for the refined products we market, which could have an adverse effect on the profitability of our fuel retailing business.

Meeting the requirements of evolving environmental, health and safety laws andregulations including those related to climate change could adversely affect ourperformance.

Consistent with the experience of other U.S. refiners, environmental laws and regulations have raised operating costs and require significant capital investments at our refinery. We believe that existing physical facilities at our refinery are substantially adequate to maintain compliance with existing applicable laws and regulatory requirements. However, we may be required to address conditions that may be discovered in the future and require a response. Also, potentially material expenditures could be required in the future as a result of evolving environmental, health and safety, and energy laws, regulations or requirements that may be adopted or imposed in the future. Future developments in federal and state laws and regulations governing environmental, health and safety and energy matters are especially difficult to predict.

Currently, multiple legislative and regulatory measures to address greenhouse gas emissions (including carbon dioxide, methane and nitrous oxides) are in various phases of consideration, promulgation or implementation. These include actions to develop national, statewide or regional programs, each of which could require reductions in our greenhouse gas emissions. Requiring reductions in our greenhouse gas emissions could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls at our facilities and (iii) administer and manage any greenhouse gas emissions programs, including acquiring emission credits or allotments.

Requiring reductions in our greenhouse gas emissions and increased use of renewable fuels which can be supplied by producers and marketers in other industries that supply alternative forms of energy and fuels to satisfy the requirements of our industrial, commercial and individual customers could also decrease the demand for our refined products, and could have a material adverse impact on our business, financial condition and results of operations. For example:

· The United States Environmental Protection Agency, or the USEPA, proposed regulations in 2009, that would require the reduction of emissions of greenhouse gases from light trucks and cars, and would establish permitting thresholds for stationary sources that emit greenhouse gases and require emissions controls for those sources. Promulgation of the final rule on April 1, 2010, has resulted in a cascade of related rulemakings by the USEPA pursuant to the Federal Clean Air Act, or the CAA, relative to controlling greenhouse gas emissions.

· In December 2007, the Energy Independence and Security Act was enacted into federal law, which created a second renewable fuels standard. This standard requires the total volume of renewable transportation fuels (including ethanol and advanced biofuels) sold or introduced in the U.S. to reach 16.6 billion gallons in 2013 and to increase to 36 billion gallons by 2022.

In addition, the inability of third parties to manufacture advanced biofuels may prohibit us from meeting the requirements of the Energy Independence and Security Act of 2007.

Our operations are subject to operational hazards that could expose us to potentiallysignificant losses.

Our operations are subject to potential operational hazards and risks inherent in refining operations and in transporting and storing crude oil and refined products. Any of these risks, such as fires, explosions, maritime disasters, security breaches, pipeline ruptures and spills, mechanical failure of equipment, and severe weather and natural disasters, at our or third party facilities could result in business interruptions or shutdowns and damage to our properties and the properties of others. A serious accident at our facilities could also result in serious injury or death to our employees or contractors and could expose us to significant liability for personal injury claims and reputational risk. Any such event or unplanned shutdown could have a material adverse effect on our business, financial condition and results of operations.

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We carry property, casualty and business interruption insurance but such insurance may not provide coverage against all potential losses.

We carry property, casualty and business interruption insurance but we do not maintain insurance coverage against all potential losses. Marine vessel charter agreements do not include indemnity provisions for oil spills so we also carry marine charterer’s liability insurance. We could suffer losses for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. The occurrence of an event that is not fully covered by insurance or failure by one or more insurers to honor its coverage commitments for an insured event could have a material adverse effect on our business, financial condition and results of operations.

Our business is impacted by environmental risks of spills, discharges or other releases of petroleum or hazardous substances that are inherent in refining operations.

The operation of refineries, pipelines, and refined products terminals is inherently subject to the risks of spills, discharges or other inadvertent releases of petroleum or hazardous substances. These events could occur in connection with our refinery, pipelines, or refined products terminals, or in connection with any facilities which receive our waste or by-products for treatment or disposal. If any of these events occur, or is found to have previously occurred, we could be liable for costs and penalties associated with their remediation under federal, state and local environmental laws or common law, and could be liable for property damage to third parties caused by contamination from releases and spills. The penalties and clean-up costs that we may have to pay for releases or the amounts that we may have to pay to third parties for damages to their property, could be significant and the payment of these amounts could have a material adverse effect on our business, financial condition and results of operations.

We operate in and adjacent to environmentally sensitive coastal waters where tanker, pipeline, and refined product transportation and storage operations are closely regulated by federal, state and local agencies and monitored by environmental interest groups. Transportation and storage of crude oil and refined products over and adjacent to water involves inherent risk and subjects us to the provisions of the Federal Oil Pollution Act of 1990 and state laws in Hawaii. Among other things, these laws require us and the owners of tankers that we charter to deliver crude oil to our refinery to demonstrate in some situations the capacity to respond to a spill of up to one million barrels of oil from a tanker and up to 600,000 barrelsof oil from an above ground storage tank adjacent to water, which we refer to as a Worst Case Discharge, to the maximum extent possible.

We and the owners of tankers we charter have contracted with various spill response service companies in the areas in which we transport and store crude oil and refined products to meet the requirements of the Federal Oil Pollution Act of 1990 and state and foreign laws. However, there may be accidents involving tankers, pipelines, or above ground storage tanks transporting or storing crude oil or refined products, and response services may not respond to a Worst Case Discharge in a manner that will adequately contain that discharge, or we may be subject to liability in connection with a discharge. Additionally, we cannot ensure that all resources of a contracted response service company could be available for our or a chartered tanker owner’s use at any given time. There are many factors that could inhibit the availability of these resources, including, but not limited to, weather conditions, governmental regulations or other global events. By requirement of state or federal rulings, these resources could be diverted to respond to other global events.

Our operations are also subject to general environmental risks, expenses and liabilitieswhich could affect our results of operations.

From time to time we have been, and presently are, subject to litigation and investigations with respect to environmental and related matters. We may become involved in further litigation or other proceedings, or we may be held responsible in any existing or future litigation or proceedings, the costs of which could be material.

We operate and have in the past operated retail stations with underground storage tanks in Hawaii. Federal and state regulations and legislation govern the storage tanks, and compliance with these requirements can be costly. The operation of underground storage tanks poses certain risks, including leaks. Leaks from underground storage tanks, which may occur at one or more of our retail stations, or which may have occurred at our previously operated retail stations, may impact soil or groundwater and could result in fines or civil liability for us.

Our inventory risk management activities are designed to manage the risk of volatile prices associated with our physical inventory and may result in substantial derivative gains and losses.

We enter into derivative transactions to manage the risks from changes in the prices of crude oil and refined products.  Our inventory risk management activities are designed to manage the risk stemming from the volatile prices associated with our

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physical inventories and may result in substantial derivatives gains and losses. We hedge price risk on inventories above or below our target levels to mitigate the impact these price fluctuations have on our earnings and cash flows.  Consequently, our derivatives hedging results may fluctuate significantly from one reporting period to the next depending on the terms of the derivative transactions, commodity price fluctuations and our relative physical inventory positions.  

We are subject to interruptions of supply and increased costs as a result of ourreliance on third-party transportation of crude oil and refined products.

Our Hawaii refinery currently receives its crude oil via ships and barges and transports some refined products from Oahu to Hawaii and Maui.  In addition to environmental risks discussed above, we could experience an interruption of supply or an increased cost to deliver refined products to market if the ability of the pipelines or vessels to transport crude oil or refined products is disrupted because of accidents, governmental regulation or third-party action. A prolonged disruption of the ability of a pipeline or vessels to transport crude oil or refined products could have a material adverse effect on our business, financial condition and results of operations.

We rely upon certain critical information systems for the operation of our business, and the failure of any critical information system, including a cyber-security breach, may result in harm to our business. 

We are heavily dependent on our technology infrastructure and maintain and rely upon certain critical information systems for the effective operation of our business. These information systems include data network and telecommunications, internet access and our websites, and various computer hardware equipment and software applications, including those that are critical to the safe operation of our refinery and our pipelines and terminals. These information systems are subject to damage or interruption from a number of potential sources including natural disasters, software viruses or other malware, power failures, cyber-attacks, and other events. To the extent that these information systems are under our control, we have implemented measures such as virus protection software and intrusion detection systems to address the outlined risks. However, security measures for information systems cannot be guaranteed to be failsafe. Any compromise of our data security or our inability to use or access these information systems at critical points in time could unfavorably impact the timely and efficient operation of our business and subject us to additional costs and liabilities, which could adversely affect our results of operations.  Finally, federal legislation relating to cyber-security threats could impose additional requirements on our operations.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Pursuant to the Plan, during the three months ended September 30, 2013, the Recovery Trustee settled an additional 11 claims with an aggregate face amount of $3.7 million for approximately $2.0 million in cash and 16,408 shares of stock. See Note 8 to our unaudited consolidated financial statements included herein. The Company’s common stock was issued pursuant to Section 1145 of the Bankruptcy Code, which exempts the issuance of securities from the registration requirements of the Securities Act of 1933, as amended.

As long as any obligations remain outstanding under the Loan Agreement, we are prohibited from paying any dividends.

Item 3. Defaults Upon Senior Securities

Not applicable

Item 4. Mine Safety Disclosure

Not applicable

Item 5. Other Information

None

Item 6. Exhibits.

Exhibits are as follows:

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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 of June17, 2013, by and among Tesoro Corporation, Tesoro Hawaii, LLC and Hawaii Pacific Energy, LLC Incorporated by reference to Exhibit 2.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013, filed on August 14, 2013.@
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	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.
3.3	Certificate of Amendment to the 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 27, 2013.
4.1	Form of the Company’s Common Stock Certificate. Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on September 7, 2012.
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.
4.7	Registration Rights Agreement dated as of September 25, 2013, by and among the Company and the Purchasers party thereto. Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on September 27, 2013.
10.1	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 on September 13, 2013.
10.2	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 Current Report on Form 8-K filed on September 27, 2013.

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10.13	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 in September 27, 2013.
10.14	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 in September 27, 2013.
10.15	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 in September 27, 2013.
10.16	Environmental Agreement dated as of September 25, 2013, by and among Tesoro Corporation, Hawaii Pacific Energy, LLC and Tesoro Hawaii, LLC. *
10.17	Letter Agreement, dated as of September 17, 2013, by and between Equity Group Investments and Par Petroleum Corporation. *
10.18	Letter Agreement, dated as of September 17, 2013, by and between Whitebox Advisors, LLC and Par Petroleum Corporation. *
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 350.*
32.2	Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350. *
101.INS	XBRL Instance Document.**
101.SCH	XBRL Taxonomy Extension Schema Documents.**
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.**
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.**
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.**
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.**

*           Filed herewith.

**        These interactive data files are furnished and deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

@           Schedules and similar attachments to the Membership Interest Purchase 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.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

PAR PETROLEUM CORPORATION (Registrant)
By:	/s/ William Monteleone
	William Monteleone
	Chief Executive Officer
By:	/s/ R. Seth Bullock
	R. Seth Bullock
	Chief Financial Officer

Date: November 14, 2013

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EX-10.16

Exhibit 10.16

Execution Copy

ENVIRONMENTAL AGREEMENT

THIS ENVIRONMENTAL AGREEMENT (this “Environmental Agreement”) is entered into as of September 25, 2013 (the “Execution Date”), by and among TESORO CORPORATION, a Delaware corporation (“Seller”), HAWAII PACIFIC ENERGY, LLC, a Delaware limited liability company (“Buyer”), and TESORO HAWAII, LLC, a Hawaii limited liability company (the “Company”). Seller, Buyer and the Company may be referred to herein individually as a “Party,” and collectively as the “Parties.”

W I T N E S S E T H:

WHEREAS, the Parties have entered into that certain Membership Interest Purchase Agreement dated June 17, 2013 for the sale of all of the issued and outstanding units representing membership interests in the Company (as such agreement may hereafter be amended, restated, supplemented or otherwise revised) (the “Purchase Agreement”); and,

WHEREAS, in connection with the Closing, the Parties have agreed to enter into this Environmental Agreement in relation to their respective obligations arising under Environmental Laws and certain matters relating thereto.

NOW, THEREFORE, in consideration of the mutual promises made herein and for other good and valuable consideration, the receipt and sufficiency of which is hereby expressly acknowledged, and subject to the conditions hereinafter set forth, the parties hereto agree as follows:

ARTICLE I

DEFINITIONS AND INTERPRETATIONS

1.01                 Definitions; Usage.  Unless the context shall otherwise require, capitalized terms used and not defined herein shall have the meanings assigned thereto in the Purchase Agreement and all rules as to interpretation and usage set forth therein shall apply hereto except that all references herein to Articles, Sections, Exhibits and Schedules are to Articles and Sections of and Exhibits and Schedules attached to and forming part of this Environmental Agreement, unless the contrary is specifically stated. As used in this Environmental Agreement, the following terms shall have the meanings set forth below, unless the context otherwise requires:

“Acceptable Corrective Action Method” means the minimum method using a demonstrated and acceptable technology or techniques to Remediate at the minimum required expense allowable under, and which satisfies the requirements of, all Environmental Laws in effect and as interpreted as of the Closing Date for the type of property affected consistent with its use on the Closing Date (i.e., industrial). For the avoidance of doubt, Acceptable Corrective Action Method may include (a) risk assessment or risk reduction principles or programs, (b) natural attenuation of contamination in appropriate circumstances, (c) capping in place, or (d) acceptance of perpetual land use or institutional use restrictions or engineering controls.

“Acquired Subsidiary” means Smiley’s Super Service, Inc., a Hawaii corporation.

“Asbestos” means any asbestos containing material, the management, maintenance, removal, abatement or disposal of which is regulated under Environmental Laws.

“BHP Environmental Agreement” means that certain Environmental Agreement dated as of May 29, 1998, by and among BHP Hawaii Inc., BHP Petroleum Pacific Islands Inc., and Tesoro Petroleum Corporation.

“BHP Hawaii” means BHP Hawaii Inc. and its successors and assigns.

“BHP Pacific” means BHP Petroleum Pacific Islands Inc. and its successors and assigns.

“Breach Notice” has the meaning set forth in Section 2.02.

“Buyer” has the meaning given such term in the preamble of this Environmental Agreement.

“Capital Projects” has the meaning given such term in Section 3.03(c).

“Change in Control” means, and shall be deemed to have occurred upon one or more of the following events:

(A)                 any transaction, or series of related transactions, that results or would result in the transfer of fifty percent (50%) or more of the Equity Interests in Buyer or its subsidiaries (or fifty percent (50%) or more of the Equity Interest in any business entity that owns or controls, directly or indirectly, fifty percent (50%) or more of the Equity Interests of Buyer (the “Buyer Parent”)) to a single transferee or multiple transferees under common control (other than transferred to the Buyer Parent or any of its subsidiaries but in such event the Buyer Parent or such subsidiary shall thereafter be subject to the definition of Change in Control);

(B)      any transaction that would result in the Company or its subsidiaries (or Buyer or the Buyer Parent) merging, directly or indirectly, with one or more other entities, provided, that a merger as a result of which the holders of Equity Interests of the Company, such subsidiary or Buyer or the Buyer Parent, as applicable, immediately prior to such merger possess fifty percent (50%) or more of the voting power, directly or indirectly, of the business entity surviving such merger (or other business entity which is the issuer of the Equity Interest into which the Equity Interest of the Company, such subsidiary or Buyer or the Buyer Parent, as applicable, is converted or exchanged in such merger) shall not be treated as a Change in Control but such surviving entity shall thereafter be subject to the definition of Change in Control; or

(C)       any transaction (or series of related transactions) not in the ordinary course of business of the Company, its subsidiaries, Buyer or the Buyer Parent that results in the direct or indirect sale, purchase or other transfer or exchange of assets, including manufacturing facilities and ownership interests in other business entities, representing fifty percent (50%) or more of the fair market value of the assets of Buyer and its subsidiaries, on a consolidated basis, to any Person other than the Buyer Parent or any of its subsidiaries but in such event the Buyer Parent or such subsidiary shall thereafter be subject to the definition of Change in Control.

“Claim” means any demand, claim, complaint, notice of violation or any other assertion of an Obligation, whether written or oral, for any Loss, specific performance, injunctive relief, remediation or other equitable relief whether or not ultimately determined to be valid.

“Closure” means achieving compliance with the commercial and industrial cleanup standards established by the applicable Governmental Authority such that the Refinery and the other Assets may be

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used to the same extent as Seller has operated them on a recent historical basis prior to the Closing Date. Compliance shall be established by (i) receipt of a “No Further Action Letter” or similar communication from the applicable Governmental Authority that no further action is required or that the action taken by Seller has been completed (a “Closure Letter”); (ii) except for the Refinery Groundwater Remediation, three (3) years after the date Seller has submitted written notice and supporting documentation to such applicable Governmental Authority indicating that Seller considers its action to be complete and in compliance with all applicable Environmental Laws in effect and as interpreted as of the Closing Date (provided that the Governmental Authority has failed to respond during such period and that no adverse status changes attributable solely to Seller occur during the three-year period, which changes would materially alter the conclusion that the action was complete and compliant with Environmental Laws in effect and as interpreted as of the Closing Date); or (iii) except for the Refinery Groundwater Remediation, five (5) years following the date that the applicable Government Authority directs Seller to “monitor only" at the particular location, regardless of whether Seller has submitted a written notice described in subparagraph (ii) above; provided, however the time period will terminate after three (3) years if levels of all Hazardous Materials remain constant or are showing a negative downward trend over such three (3) year time period.

“Company” has the meaning given such term in the preamble of this Environmental Agreement.

“Company Assumption” has the meaning given such term in Section 4.01(a).

“Company Environmental Liabilities” means any and all Orders, Claims, Losses or Obligations, including required capital expenditures, arising from or related to Environmental Laws or the Hawaii Consent Decree, whether known or unknown, of the Companies or the Business, whether arising before or after the Closing, including those related to Third Party Claims, actual or threatened Releases of Hazardous Materials, off-site treatment, storage, recycling, or disposal and off-site migrations of Hazardous Materials or any fine, penalty or other cost assessed in connection with any alleged or actual violation(s) of Environmental Laws.

“Companies”means the Company and the Acquired Subsidiary.

“Construction Activity” has the meaning set forth in Section 4.01(d).

“Corrective Action” means all Remediation Activities, whether undertaken pursuant to judicial or administrative Order or otherwise, reasonably necessary to comply with applicable Environmental Laws in effect and as interpreted as of the Closing Date to investigate, monitor and, if required, clean up, remove, treat, cover and protect from human or environmental exposure.

“De Minimis Amount” has the meaning given such term in Section 5.02(c).

“Environmental Authorization” means any Authorization of any applicable Governmental Authority required by Environmental Laws in effect and as interpreted as of the Closing Date for the ownership, operation or use of the Assets as they are operated by the Company as of the Closing Date.

“Environmental Cap” has the meaning given such term in Section 5.02(e).

“Environmental Claim” shall mean any administrative, regulatory or judicial action, suit, Order, demand, directive, claim, lien, governmental investigation, proceeding or written or oral notice of noncompliance or violation by or from any Person alleging liability of whatever kind or nature (including liability or responsibility for the costs of enforcement proceedings, Corrective Action, governmental response, natural resources damages, property damages, personal injuries, medical monitoring, penalties,

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contribution, indemnification and injunctive relief) arising out of, based on or resulting from (i) the presence or Release of, or exposure to, any Hazardous Materials; or (ii) the failure to comply with any Environmental Laws in effect and as interpreted as of the Closing Date.

“Environmental Condition” means any condition at, on, under, within or migrating from any tangible Assets, in each case arising out of the presence or Release of any Hazardous Materials on, at or underlying the Real Property Interests or the Pipeline ROW Interests.

“Environmental Deductible” has the meaning given such term in Section 5.02(d).

“Environmental Law” means any Law pertaining to public or employee exposure to Hazardous Materials, pollution, the environment or the protection of fish, wildlife or natural resources. For the avoidance of doubt, due to the inclusion of the word “applicable” in the definition of “Law” incorporated into this definition, any references in this Environmental Agreement to “any Environmental Law” or “any applicable Environmental Law” shall have the same meaning.

“Environmental Testing” means any environmental site assessment, test, inspection or investigation of the Assets that could reasonably be expected to lead to the discovery, investigation or assessment of an Environmental Condition.

“EPA Attestations” means the procedures applicable to the Refinery described in 40 CFR § 80.

“Hawaii Consent Decree” has the meaning given such term in Section 3.03(a).

“Hazardous Materials” means (i) any chemicals, materials or substances in any form, whether solid, liquid, gaseous, semisolid, or any combination thereof, whether waste materials, raw materials, chemicals, finished products, by-products, degradation products or any other materials or articles, which are listed, defined or otherwise designated as hazardous, toxic or dangerous and as such are regulated under any Environmental Law, including asbestos, and lead-containing paints or coatings, (ii) any petroleum (including crude oil), petroleum derivatives, petroleum products or by-products of petroleum refining or any oxygenate (including degradation products) in any fuel, and (iii) any other chemical, substance or waste that is regulated by any Environmental Law.

“Indemnified Party” has the meaning set forth in Section 5.04.

“Indemnifying Party” has the meaning set forth in Section 5.04.

“Lead-Based Paint” means any intact paint or other surface coating containing lead or lead-based materials, the application, management, maintenance, removal, abatement or disposal of which is regulated under Environmental Laws.

“NORM” has the meaning given such term in Section 3.01.

“Order” means any order, writ, ruling, decision, verdict, decree, assessment, award (including arbitration awards), judgment, stipulation, injunction, or other determination, decision or finding by, before or under the supervision of any Governmental Authority, including the Hawaii Consent Decree.

“PCBs” has the meaning given such term in Section 3.01.

“Pre-Existing Environmental Condition” means any Environmental Condition (whether known or unknown) at, on, under, or within the Real Property Interests or any Pipeline ROW Interest or any

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improvements thereon or therein existing as of the Closing Date; provided, however, that Pre-Existing Environmental Conditions shall not include Lead-Based Paint, NORM, PCB’s or non-friable Asbestos on or within the buildings or other improvements included in the Assets or migration of Hazardous Materials onto or into the Real Property Interests or any Pipeline ROW from outside sources or locations.

“Purchase Agreement” has the meaning given such term in the Recitals of this Environmental Agreement.

“Refinery Groundwater Remediation” means the Remediation of groundwater contamination currently being conducted by the Company at the Refinery.

“Release” means any spilling, leaking, seeping, pumping, pouring, emitting, emptying, injecting, discharging, escaping, leaching, dumping, disposing or releasing of a Hazardous Material into the environment (including the air, soil, surface water, groundwater, sewer, septic system, or waste treatment, storage, or disposal systems) of any kind whatsoever, including the abandonment or discarding of barrels, containers, tanks or other receptacles containing or previously containing a Hazardous Material.

“Remediate,” “Remediation” or “Remediation Activities” means testing, investigation, assessment, study, design, monitoring, cleanup, treatment, removal, response, remediation, corrective action, reporting or other similar activities in each case undertaken pursuant to Environmental Laws to address any Environmental Condition or any Release, including any such temporary, interim, emergency or permanent activities involving investigation, study, design, assessment, testing, monitoring, containment, removal, disposal, Closure, corrective action, passive remediation, natural attenuation or bioremediation, the installation and operation of remediation systems, or reporting of released Hazardous Materials to applicable Governmental Authorities.

“Seller” has the meaning given such term in the preamble of this Environmental Agreement.

“Seller Remediation Activities” has the meaning given such term in Section 4.01.

“Tank Replacements” has the meaning given such term in Section 3.04.

ARTICLE II

SELLER’S ENVIRONMENTAL REPRESENTATIONS AND WARRANTIES

2.01                 Representations and Warranties. Except as set forth in Schedule 2.01, Seller represents and warrants to Buyer to Seller’s Knowledge, as follows:

(a)           Except as would not reasonably be expected to have a Material Adverse Effect, the Companies, the Business and the Assets are, and for the five (5) years prior to the Execution Date, have been operated in compliance with all applicable Environmental Laws (in each case, as in effect and interpreted at the respective times within such five-year period);

(b)           Except as would not reasonably be expected to have a Material Adverse Effect, all Environmental Authorizations required to be obtained, filed or applied for by the Companies under any Environmental Law in connection with the Business or their respective Assets as normally operated prior to the Execution Date have been duly obtained, filed or applied for by the Companies, as applicable, and each of the Companies is and, for the five (5) years prior to the Execution Date, has been in compliance with the terms and conditions of such Environmental Authorizations, as applicable;

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(c)           Except as would not reasonably be expected to have a material  effect, (i) there are no Claims, Proceedings or Orders (including any alleging criminal violations or liability) pending or threatened by or before any Governmental Authority arising under any Environmental Law relating to the Companies, the Assets or the Business, and (ii) neither of the  Companies has received written notice of any potential violation of, or liability under, any Environmental Law;

(d)           Except as would not reasonably be expected to have a Material Adverse Effect, neither the operations of the Companies nor the operations of the Business prior to the Effective Time has resulted in a Release at concentrations in excess of those allowed for under applicable Environmental Laws or Environmental Authorizations;

(e)           Except as would not reasonably be expected to have a Material Adverse Effect, neither of the Companies has assumed by contract any liabilities arising under Environmental Laws of any other Person; and

(f)           Seller has prior to the Execution Date provided or made available to Buyer (i) in the Data Room, copies of all material non-privileged environmental site assessments, audits, investigations and studies prepared by third parties that are in the possession, custody or control of Seller or its Affiliates relating to the Companies, the Business, the Assets or properties or assets formerly owned, leased, operated or used by the Companies or the Business, or (ii) by examination of all files in the possession of the Company located at any of its company facilities, copies of material non-privileged environmental site assessments, audits, investigations and studies relating to the Companies, the Business, the Assets or properties or assets formerly owned, leased, operated or used by the Companies or the Business.

2.02                 Breach Notice.  If, prior to the Closing Date, Buyer obtains Knowledge of a breach of any of Seller’s representations, warranties or covenants contained in this Environmental Agreement, Buyer shall notify Seller in writing of such information (the “Breach Notice”) within three (3) Business Days of such discovery or on the day prior to the Closing Date, whichever is earlier. The Breach Notice shall contain reasonable details regarding the alleged breach and Buyer’s good faith estimate of the potential Losses associated with such breach.

ARTICLE III

ENVIRONMENTAL PROVISIONS

3.01                 Incidental Contamination and NORM.  Buyer acknowledges that the Assets may contain inter alia Asbestos in pipe coating, undisplaced petroleum hydrocarbon compounds in pipelines, coats of Lead-Based Paints, polychlorinated biphenyls (“PCBs”) in transformers or rectifiers, mercury in electrical switches, and Naturally Occurring Radioactive Material (“NORM”) in various potential forms. Buyer also expressly understands that special procedures may be required for the Remediation, removal, transportation and disposal of such contained, affixed or attached materials. Notwithstanding any provision to the contrary contained in this Environmental Agreement, Buyer expressly assumes liability for or in connection with the future abandonment and removal of NORM, Lead-Based Paint, undisplaced petroleum hydrocarbon compounds, mercury, Asbestos or PCBs to the extent contained, affixed or attached in or on the Assets; provided, however, that nothing in this Section 3.01 shall in any way affect Seller’s liability for NORM, Lead-Based Paint, petroleum hydrocarbon compounds, mercury, Asbestos or PCBs that have been Released into the environment prior to Closing.

3.02                 Reports and Submittals.  For any reports or submittals required by any Governmental Authority that cover periods of both Seller’s and the Company’s ownership or use of the Assets or operation of the Refinery, the Company shall prepare such reports to the extent it is able to do

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so, segregated to the extent feasible based on the Closing Date, and send Seller’s portion to Seller for its completion, review, approval and signature (if a separate report from Seller is required by the Governmental Authority or if such report or submittal could reasonably impact Seller’s Obligations under this Environmental Agreement, Seller’s liability under Environmental Laws or Seller’s Obligations to third parties). The Company’s preparation of such report shall not modify, change, alter or diminish any other provision in this Environmental Agreement as applied to the subject matter of such report and the rights, liabilities, responsibilities, obligations and indemnities for any matters contained in such reports shall be as set forth elsewhere herein.  Seller agrees to prepare reports responsive to the Hawaii Consent Decree until such time that the Parties agree this should become the Company’s responsibility.  Notwithstanding the foregoing, each of Seller and Buyer shall prepare and file the EPA Attestations relating to the ownership and operation of the Assets in 2013 for such Party’s period of ownership of the Assets during such year.

3.03                 Hawaii Consent Decree.  

(a)           Seller anticipates entering into final binding settlement(s) whether by judicial decree, judgment, agreement or otherwise, memorializing Seller’s settlement with the United States Environmental Protection Agency and the United States Department of Justice and other applicable entities or agencies, if any, regarding alleged violations of the Clean Air Act related to the ownership and operation of multiple facilities owned by Seller and its Affiliates, including the Refinery. Buyer hereby irrevocably authorizes Seller (i) to finalize the negotiations for such settlement related to the ownership and operation of the Refinery even if such negotiations extend beyond the Closing Date and (ii) to cause the Company (prior to Closing) or, if applicable, to have Buyer to cause the Company (after the Closing) to enter into such settlement (the “Hawaii Consent Decree”) provided that the terms and conditions of the Hawaii Consent Decree solely relate to air emissions originating from the Refinery and such terms and conditions, as they relate to the Company or the Refinery, are reasonably consistent with the proposed terms as described on Schedule 3.03(a). The Hawaii Consent Decree may be evidenced in a separate agreement between the Company and the applicable Governing Authorities or included in a multi-refinery consent decree between Seller and its Affiliates (including the Company) and the applicable Governing Authorities. To the extent such Hawaii settlement is included in a multi-refinery consent decree then the term “Hawaii Consent Decree” shall refer to the provisions of such multi-refinery consent decree that are applicable to the Company or the Refinery from or after the Closing Date.

(b)           The Company shall cooperate with and assist Seller as Seller shall reasonably request in finalizing and executing the Hawaii Consent Decree. Seller shall provide Buyer with monthly oral reports regarding the status of the negotiations and execution of the Hawaii Consent Decree. Seller shall provide Buyer the opportunity, with reasonable advance notice, to attend meetings with, or hearings before, any Governmental Authority regarding the Hawaii Consent Decree to the extent such meetings and hearings relate to the Refinery (Buyer shall not participate in such meetings or hearings to the extent such meetings or hearings do not involve the Company or the Refinery). Seller shall, following any such meeting or hearing with such Governmental Authority, advise Buyer of the substance of any action or position taken by such Governmental Authority during any such meeting or hearing with regards to the Company or the Refinery. Notwithstanding the preceding, Buyer’s decision to attend or not any such meeting or hearing shall not delay or postpone such meetings or hearings with a Governmental Authority. Seller shall promptly provide Buyer with copies of significant reports, plans, correspondence and other substantive communications received by or on behalf of Seller from or submitted by or on behalf of Seller to a Governmental Authority with respect to the negotiation or execution of the Hawaii Consent Decree.

(c)           Provided that the Startup Criteria have been met in all material respects as of the Execution Date, Seller shall (or shall cause its Affiliates to) reimburse the Company for reasonable third party capital expenditures incurred by the Company for the construction, installation and

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commissioning of capital projects at the Refinery as and when and to the extent required pursuant to the Hawaii Consent Decree (collectively, the “Capital Projects”).  Seller and Buyer agree to communicate, consult and reasonably cooperate with one another in the design, engineering, procurement, construction, installation and commissioning of the Capital Projects, provided such consultation and cooperation are consistent with the terms of this section.  Seller and Buyer (and their Affiliates) shall minimize the capital expenditures for the Capital Projects to the extent necessary to satisfy the obligations of the Hawaii Consent Decree. Seller and the Company agree to use Commercially Reasonable Efforts to work together during the design, engineering, procurement and construction of the Capital Projects to minimize the potential for disruption of Refinery operations during implementation of the Capital Projects. Between Seller and the Company, Seller shall have the primary responsibility, at Seller’s expense, for the design and engineering of the Capital Projects. Buyer shall cause the Company to permit Seller and its Affiliates and their respective representatives (including Seller’s engineering contractors) to have reasonable access to the Refinery (subject to appropriate safety and security standards of the Company) and applicable books and records and reasonable access to and inquiry of employees and other personnel who are employed, retained or controlled by the Company who have relevant information necessary for the designing and engineering of the Capital Projects. Seller and the Company agree to use Commercially Reasonable Efforts to work together to develop the Capital Projects in a cost effective manner while meeting the requirements of the Hawaii Consent Decree and also minimizing the anticipated impact on the Refinery’s operating expenses following implementation. NOTWITHSTANDING ANY OTHER PROVISIONS IN THIS AGREEMENT TO THE CONTRARY, NEITHER SELLER NOR ANY AFFILIATE, AGENT, OR REPRESENTATIVE OF SELLER HAS MADE, AND SELLER HEREBY EXPRESSLY DISCLAIMS AND NEGATES, ANY IMPLIED OR EXPRESS WARRANTY OF MERCHANTABILITY, FITNESS (BOTH GENERALLY AND FOR A PARTICULAR PURPOSE), OR CONFORMITY TO MODELS, DESIGNS OR SAMPLES OR ANY OTHER REPRESENTATION OR WARRANTY, EXPRESS, STATUTORY OR  IMPLIED,  RELATING TO THE CAPITAL PROJECTS.

(d)           Seller shall retain sole responsibility for the payment of any fines or penalties imposed on the Company arising from the Hawaii Consent Decree to the extent related to acts or omissions of Seller or the Company prior to the Closing Date.

(e)           The Company shall be responsible for compliance with the Hawaii Consent Decree except to the extent provided above in this Section 3.03.

3.04                 Tank Replacements.  Seller shall cause (or shall cause its Affiliates to cause), at Seller’s expense, the replacement of existing underground storage tanks at the Retail Assets listed on Schedule 3.04, including any Corrective Action relating to Pre-Existing Environmental Conditions identified at the time of such tank replacements (the “Tank Replacements”).  The Company shall provide reasonable assistance and cooperation in order for Seller (or its Affiliates) to complete the Tank Replacements in an efficient and timely manner.  The Company shall permit Seller and its Affiliates and their respective representatives (including Seller’s contractors) to have reasonable access to the Retail Assets listed on Schedule 3.04 (subject to appropriate safety and security standards of the Company) to complete the Tank Replacements.

3.05                 Company Environmental Liabilities. Except as otherwise provided herein, Buyer and the Company acknowledge and agree that after the Closing, the Company will continue to retain all Company Environmental Liabilities.

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ARTICLE IV

CORRECTIVE ACTION AND ENVIRONMENTAL TESTING

4.01                 Conduct of Corrective Action.

(a)           In the event Corrective Action is necessary after the Closing to Remediate  a Pre-Existing Environmental Condition (whether known or unknown as of the Closing Date) and for which Seller has agreed to indemnify, defend and hold Buyer harmless pursuant to Section 5.02, then Seller (or its Affiliates) shall control such Corrective Action (the “Seller Remediation Activities”) until (i) Seller’s indemnification obligation terminates pursuant to Section 5.02 or (ii) a Claim is made against Buyer or the Company by a Governmental Authority after the Closing with respect to such Pre-Existing Environmental Condition and Buyer or the Company elects, by providing written notice to Seller, to assume control of such Corrective Action (a “Company Assumption”); provided, however, that if Buyer or the Company elects to assume control of any Corrective Action, Seller shall have no further obligation to indemnify, defend or hold Buyer harmless for such Corrective Action pursuant to Section 5.02. Seller (and its Affiliates) shall take (and shall only be required to take) all actions and make all expenditures reasonably required by applicable Environmental Laws in effect and as interpreted as of the Closing Date in order to Remediate such Pre-Existing Environmental Condition consistent with the Acceptable Corrective Action Method. In determining the Acceptable Corrective Action Method, Seller shall consult with Buyer, consider in good faith any reasonable recommendations or proposals made by Buyer, and take into account the intended usage of the relevant property.

(b)           In connection with any Seller Remediation Activities:

(i)           The Company shall provide reasonable assistance and cooperation in order for Seller to complete the Seller Remediation Activities in an efficient and timely manner; provided, that any third party costs or expenses incurred by or on behalf of Buyer or the Company in connection with such assistance and cooperation shall be borne by Seller to the extent approved by Seller in writing in advance and subject to the limitations of Section 5.02;

(ii)           Seller shall provide the Company the opportunity, with reasonable advance notice, to attend meetings with, or hearings before, any Governmental Authority regarding such Seller Remediation Activities. Seller shall, following any such meeting or hearing with such Governmental Authority, advise the Company of the substance of any action or position taken by such Governmental Authority during any such meeting or hearing. Notwithstanding the preceding, the Company’s decision to attend or not any such meeting or hearing shall not delay or postpone such meetings or hearings with a Governmental Authority;

(iii)           Seller will coordinate the schedule of on-site Seller Remediation Activities with the Company so that disruptions of the Company’s operations of the Assets will be minimized;

(iv)           The Company shall permit Seller and its Affiliates and their respective representatives (including Seller’s environmental contractors) to have reasonable access to the Assets (subject to appropriate safety and security standards of the Company) and applicable books and records and reasonable access to and inquiry of employees and other personnel who are employed, retained or controlled by the Company who have relevant information regarding the Assets related to the obligations of Seller for Corrective Action. The Company shall provide Seller, without additional charge, reasonable access to utilities

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and available equipment and operations (including wastewater treatment units) used in connection with Seller Remediation Activities;

(v)           Seller shall provide the Company with copies of third party reports and studies, notices and filings received or prepared on behalf of Seller prior to the delivery of such submissions to any Governmental Authority and shall allow the Company a reasonable opportunity (which shall not be fewer than ten (10) days to review such filings in advance of any such submission and, if requested, shall consider in good faith all reasonable comments to such submissions made by the Company prior to submitting such materials to such Governmental Authority. The Company shall respond promptly to requests for information by a Governmental Authority with respect to Seller Remediation Activities. The Company shall respond promptly and without unreasonable conditions to reasonable requests by Seller for execution and delivery of any submissions or applications reasonably requested by Seller that are required to be filed by or on behalf of the Company with respect to the Seller Remediation Activities;

(vi)           Seller shall promptly provide the Company with copies of significant reports, plans, correspondence and other substantive communications received by or on behalf of Seller from or submitted by or on behalf of Seller to a Governmental Authority with respect to the Seller Remediation Activities;

(vii)           The Company shall promptly provide Seller with copies of all reports, plans, correspondence and other substantive communications received by or on behalf of the Company from or submitted by or on behalf of the Company to a Governmental Authority with respect to the Seller Remediation Activities;

(viii)           Seller shall be responsible for transportation and offsite disposition of solid wastes generated in connection with Seller Remediation Activities and required to be managed offsite; and

(ix)           To the extent that Seller Remediation Activities include land use or institutional use restrictions or engineering controls consistent with an Acceptable Corrective Action Method, the Company shall (at Seller’s cost and expense) execute such commercially reasonable agreements embodying such restrictions as may be required by a Governmental Authority in order to bind the Company and any subsequent owners of any of the Assets to such land use or institutional use restrictions or engineering controls.

(c)           In the event of a Company Assumption, Seller shall coordinate with the Company to transition responsibility for such Corrective Action to the Company.  Seller shall promptly provide the Company with copies of all reports, studies, plans, data, correspondence and notices relating to the assumed Corrective Action. For the avoidance of doubt, Seller’s indemnification obligations pursuant to Section 5.02 shall terminate with respect to any Corrective Action that is the subject of a Company Assumption, and Seller shall have no further obligation to indemnify, defend or hold Buyer harmless for such Corrective Action pursuant to Section 5.02.

(d)           In the event the Company plans after the Closing to conduct construction activity which will or may cause disturbance of soils, sediment or other media containing Hazardous Materials (“Construction Activity”) for which Seller may be obligated to conduct Seller Remediation Activities, the Company shall consult with Seller prior to such construction activity and to consider in good faith Seller’s requests and comments with respect to Remediation methods and location of construction, all to the extent reasonably practicable and consistent with an Acceptable Corrective Action

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Method and that do not unreasonably interfere with the Company’s proposed construction activity. Notwithstanding anything in this Environmental Agreement to the contrary, Seller shall not have any liability to indemnify, defend or hold Buyer Indemnified Parties harmless pursuant to Section 5.02 for Corrective Action (or other Losses related thereto) required or incurred as a result of Construction Activity to the extent such Corrective Action would not be required (or related Losses incurred) in the event the Construction Activity did not occur.

(e)           If a Release shall occur or is continuing after the Closing at a location or in an amount not readily distinguishable from an Environmental Condition existing prior to the Closing for which Seller is required to indemnify, defend and hold harmless a Buyer Indemnified Party pursuant to Section 5.02, then the Company shall be responsible for the incremental costs incurred for the Remediation of the post-Closing Release as compared to the costs that would otherwise have been incurred to Remediate such pre-Closing Environmental Condition. The Company and Seller shall negotiate in good faith to allocate all respective obligations arising out of such pre-Closing Environmental Condition and post-Closing Release in question in an equitable manner, which allocation shall take into consideration and reflect all pertinent facts, which pertinent facts may include:  (i) the quantity or volume of Hazardous Materials present immediately prior to such post-Closing Release, and present as a result of the post-Closing Release; (ii) differences, if any, in the composition of the Hazardous Materials present immediately prior to such post-Closing Release, and present as a result of the post-Closing Release; and (iii) if and to what extent the post-Closing Release has impacted geographical areas not impacted by the pre-Closing Environmental Condition prior to the post-Closing Release. Seller shall control the Remediation of such commingled Environmental Conditions until Seller’s obligation to indemnify, defend and hold harmless for the pre-Closing Environmental Condition terminates.

(f)           The Company shall not cause, suffer or permit the waiver, modification, suspension or termination of any obligation of BHP Hawaii or BHP Pacific to conduct and pay for Remediation Activities at, on, under or within the Real Property Interests or the Pipeline ROW Interests pursuant to the BHP Environmental Agreement and the Company shall use Commercially Reasonable Efforts to assist Seller to enforce BHP Hawaii’s and BHP Pacific’s obligations to conduct and pay for such Remediation Activities under the BHP Environmental Agreement to the extent that such obligations exist as of the date of this Environmental Agreement.

(g)           Simultaneously with the execution hereof, Seller will provide Buyer with a list of all third parties currently conducting any Corrective Action at any Asset.

(h)           In the event the Company is required pursuant to Environmental Laws to continue Remediation Activities beyond or subsequent to the conclusion of any Seller Remediation Activities, then Seller shall coordinate with the Company to transition responsibility for such Remediation Activities to the Company. Seller shall promptly provide the Company with copies of all reports, studies, plans, data, correspondence and notices relating to the assumed Remediation Activities.

4.02                 Closure and Anticipated Use.

(a)           With respect to any Corrective Action that Seller is responsible for under this Environmental Agreement, Seller (and its Affiliates) shall only be obligated to implement and complete such Corrective Action as is necessary to obtain Closure, subject to the limitations of Section 5.02. Unless terminated earlier, Seller’s obligations to perform such Corrective Action shall be deemed satisfied and shall terminate once Closure is obtained, and Seller shall have no obligation to perform further Corrective Action with respect to the Environmental Condition or Release to which the Corrective Action relates, provided that receipt of Closure shall not impact any other Obligations as between Buyer and Seller, even if such Obligations arise out of such Environmental Condition or Release.

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(b)           Seller shall not be required to address contamination beyond the Acceptable Corrective Action Method. The Company shall be responsible for any incremental cost associated with changes in Environmental Laws or a more restrictive ongoing use of the Refinery or the other Assets (i.e. commercial or residential use).

4.03                 Environmental Testing.

(a)           Until the expiration of Seller’s obligation to conduct Seller Remediation Activities, or until the Company provides notice of a Company Assumption pursuant to Section 4.01(a) (but only to the extent necessary to conduct the Corrective Action that is subject to the Company Assumption), the Company shall not directly or indirectly, initiate or conduct Environmental Testing of the Assets. Notwithstanding the preceding sentence, the Company may conduct Environmental Testing of the Assets in the event (i) such Environmental Testing is performed in the ordinary course of business of the Company such as geophysical studies of building foundations or in connection with construction, remodeling or demolition and rebuild work on Assets, (ii) the Company or its Affiliates are ordered or directed to conduct such Environmental Testing by any Governmental Authority having jurisdiction thereof, (iii) such Environmental Testing is conducted as a result of and reasonably necessary to respond to a Release that occurs after the Closing, (iv) there is reasonable evidence that such Environmental Testing is required by applicable Environmental Laws then in effect and interpreted, or (v) such Environmental Testing is conducted as a result of any written Claim by a Person other than a Buyer Indemnified Party. For the avoidance of doubt, the Company may at any time(s) conduct non-intrusive investigations of Environmental Conditions of the Assets, including Phase I environmental site assessments.

(b)           Prior to engaging in any Environmental Testing, the Company shall provide Seller with reasonable advance written notice so that Seller may, at its own expense, observe such activities and obtain any split samples it may desire. The Company shall provide Seller with copies of all written, non-privileged reports prepared by third parties related to Environmental Testing.  In the event that exigent circumstances (such as responding to a Release) do not allow for reasonable advance written notice of Environmental Testing, the Company will make a good faith attempt to orally advise Seller of such Environmental Testing and shall, within a reasonable time thereafter, provide written notice to Seller describing the Environmental Testing that was conducted.

ARTICLE V

INDEMNIFICATION; SURVIVAL

5.01                 Survival.  Subject to the limitations and other provisions of this Environmental Agreement, (a) Seller’s representations and warranties contained in Article II shall survive the Closing and shall remain in full force and effect for a period of eighteen (18) months after the Closing Date, and until the resolution of the indemnification Claims received by the Indemnifying Party in accordance with the provisions hereof prior to the expiration of the relevant time period, and (b) each covenant and agreement of the Parties contained in this Environmental Agreement which by its terms requires performance after the Closing Date shall survive the Closing Date and shall remain in full force and effect until such covenant or agreement is fully performed.

5.02                 Indemnification Provisions for the Benefit of Buyer.

(a)           Subject to the other provisions of this Article V, Seller shall indemnify, defend, save and hold the Buyer Indemnitees harmless from and against any Claims and Losses actually suffered or incurred by them to the extent arising out of or related to:

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(i)           the breach of any representation or warranty of Seller contained in this Environmental Agreement;

(ii)           all Corrective Action relating to Pre-Existing Environmental Conditions other than a Company Assumption (except to the extent addressed specifically in Sections 5.02(a)(v) or 5.02(a)(vi)), to the extent and pursuant to the procedures described in Section 4.01; provided that if the Company causes or permits a change in the use of Assets from industrial use after the Closing, then Seller shall not be required to incur any cost or make any expenditure with respect to Seller Remediation Activities related to such property greater than that which would have been required if such property had continued in its current use as of the Closing Date (i.e., industrial);

(iii)           Third Party Claims arising under Environmental Laws (as in effect and as interpreted as of the Closing Date) for personal injury or property damage to the extent arising out of or relating to Releases of Hazardous Materials that occur from the ownership, operation or use of the Assets by the Company prior to the Closing Date;

(iv)           except with respect to the Hawaii Consent Decree (which is addressed specifically in Section 3.03), any fine, penalty or other cost assessed by a Government Authority in connection with violations of Environmental Laws by the Company prior to the Closing Date;

(v)           the Refinery Groundwater Remediation to the extent and pursuant to the procedures described in Section 4.01;

(vi)           the replacement of underground storage tanks at the Retail Assets listed on Schedule 3.04, including Corrective Action relating to Pre-Existing Environmental Conditions identified at the time of such tank replacements other than a Company Assumption;

(vii)           any fines or penalties imposed on the Company arising from the Hawaii Consent Decree to the extent related to the acts or omissions of Seller or the Company prior to the Closing Date; and

(viii)           the Pearl City Superfund Site, including the presence or removal of any equipment located thereon, including any storage tanks or associated piping.

(b)           No Claim may be asserted nor may any Proceeding be commenced against Seller pursuant to this Section 5.02 unless written notice of such Claim or Proceeding is received by Seller describing in reasonable detail the facts and circumstances with respect to the subject matter of such Claim or Proceeding, and with respect to Claims or Proceedings based on the breach of any representation or warranty, on or prior to the date such representation or warranty ceases to survive as set forth in Section 5.01; provided, however, that no Claim may be asserted nor may any Proceeding be commenced by Buyer against Seller arising out of or related to a breach of any representation or warranty of which Buyer had Knowledge on or prior to the Closing Date and for which Buyer failed to deliver a Breach Notice in accordance with Section 2.02. If a Buyer Indemnitee has recovered any Losses pursuant to one subsection of this Section 5.02(a), such Buyer Indemnitee shall not be entitled to recover the same Losses under another subsection of this Section 5.02(a).

(c)           No Claim may be made against Seller for indemnification pursuant to Section 5.02(a)(i-iv) with respect to any individual action, occurrence or event subject to the indemnifications thereunder (or group of related actions, occurrences or events) unless such individual action, occurrence or event exceeds $5,000 for a Retail Asset, $25,000 for a Logistics Asset and $100,000 for the Refinery (individually, each as applicable, the “De Minimis Amount”) (nor shall any Loss below such De Minimis Amounts be applied to or considered for purposes of calculating the aggregate amount of the Buyer Indemnitees’ Losses).

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(d)           No Claim may be made against Seller for indemnification pursuant to Section 5.02(a)(i-iv) unless the aggregate amount of all Losses of the Buyer Indemnitees with respect to Section 5.02(a)(i-iv) (excluding individual Losses less than the De Minimis Amounts) shall exceed an amount equal to $1,000,000 (the “Environmental Deductible”), after which point Seller shall be obligated only to indemnify the Buyer Indemnitees from and against such aggregate Losses (excluding individual Losses less than the De Minimis Amounts) in excess of the Environmental Deductible.

(e)           The maximum amount that Seller shall be required to pay pursuant to Section 5.02(a)(i)-(v) and for Corrective Actions relating to Pre-Existing Environmental Conditions pursuant to5.02(a)(vi) in respect of all Losses by all Buyer Indemnitees shall equal $15,000,000 (the “Environmental Cap”), after which point Seller will have no Obligation to indemnify the Buyer Indemnitees from and against further such Losses; provided, however, that Seller’s obligations to pay pursuant to Section 5.02(a)(vii)-(viii) shall be excluded from the Environmental Cap. In addition, Seller shall have as an affirmative defense to any claim for indemnity under Section 5.02(a)(i) arising out of or related to a breach of any representation or warranty of Seller that Buyer had Knowledge of such breach on or prior to the Closing Date and Buyer failed to deliver a Breach Notice in accordance with Section 2.02.

(f)           All Claims made against Seller for indemnification pursuant to clauses (ii)- (viii) of Section 5.02(a), other than Claims for reasonable third party capital expenditures incurred by the Company for the construction, installation and commissioning of the Capital Projects pursuant to Section 3.03(c), must be made to Seller on or before the third (3rd) annual anniversary of the Closing Date and to the extent such Claims are made on or before such date, then Seller’s obligation to indemnify for such Claims shall remain in effect beyond such date.

(g)           For avoidance of doubt, Section 5.02(a)(iii) shall not apply to Third Party Claims arising out of a post-Closing Date fire, explosion or catastrophic incident allegedly occurring as a result of any pre-Closing non-compliance with Environmental Laws.

(h)           Seller’s indemnification obligations pursuant to Section 5.02(a) shall automatically terminate and be of no further force or effect in the event and to the extent (i) the Company sells, transfers, leases to a third party or exchanges any of the Assets (in which case such indemnification obligations shall terminate only with respect to those Assets that are sold, transferred, leased or exchanged and shall otherwise remain in full force and effect) or (ii) there is a Change in Control after the Closing; provided, however, that such limitations on indemnification would not apply to (A) transfers to a wholly owned subsidiary of the Company or (B) transfers of Owned Real Property parcels lying within the boundary fence line of the Refinery provided such Owned Real Property parcels are subject to deed restrictions reasonably acceptable to Seller that restrict the use of such parcels to industrial uses.

(i)           Seller’s indemnification obligations pursuant to this Environmental Agreement shall be reduced in the event and to the extent amounts for such indemnified obligations are taken into account as a liability for purposes of the Final Net Working Capital.

(j)           Amounts paid by Seller that are counted against or applied toward the Indemnification Deductible or the Indemnification Cap (as such terms are defined in the Purchase Agreement) shall not count against and be applied toward the Environmental Deductible and the Indemnification Cap and vice versa, amounts paid by Seller that are counted against or applied toward the Environmental Deductible or the Environmental Cap shall not count against and be applied toward the Indemnification Deductible and the Indemnification Cap.

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5.03                 Indemnification Provisions for the Benefit of Seller.

(a)           Subject to the other provisions of this Article V, Buyer and the Company agree, jointly and severally, to indemnify, defend, save and hold the Seller Indemnitees harmless from and against any Claims and Losses actually suffered or incurred by them to the extent arising out of or related to:

(i)           the breach of any covenants or agreements of Buyer contained in this Environmental Agreement;

(ii)           the Company Environmental Liabilities to the extent not indemnified by Seller pursuant to Section 5.02; and

(iii)           any Claims or Losses under Environmental Laws arising out of or related to the ownership of the TH Interest, the Company, the Acquired Subsidiary, or the Assets after the Closing Date, or the operation of the Business after the Closing Date.

(b)           No Claim may be asserted nor may any Proceeding be commenced against Buyer or the Company pursuant to this Section 5.03 unless written notice of such Claim or Proceeding is received by Buyer or the Company describing in reasonable detail the facts and circumstances with respect to the subject matter of such Claim or Proceeding. If a Seller Indemnitee has recovered any Losses pursuant to one subsection of this Section 5.03(a), such Seller Indemnitee shall not be entitled to recover the same Losses under another subsection of this Section 5.03(a).

(c)           No Claim may be made against Buyer or the Company for indemnification pursuant to clause (i) of Section 5.03(a): (i) with respect to any individual action, occurrence or event subject to the indemnifications thereunder (or group of related actions, occurrences or events) unless the such individual action, occurrence or event exceeds the respective De Minimis Amounts (nor shall any Claim or Loss below such threshold be applied to or considered for purposes of calculating the aggregate amount of Seller Indemnitees’ Losses) and (ii) unless the aggregate amount of all Claims and Losses of Seller Indemnitees with respect to clause (i) of Section 5.03(a) shall exceed the Indemnification Deductible (after which Buyer and the Company shall be obligated only to indemnify Seller Indemnitees from and against aggregate Losses in excess of the Indemnification Deductible). The maximum amount that Buyer and the Company shall be required to pay pursuant to clauses (i) of Section 5.03(a) in respect of all Claims and Losses by all Seller Indemnitees shall equal $15 million, after which point Buyer and the Company will have no Obligation to indemnify Seller Indemnitees from and against further such Claims or Losses.  For the avoidance of doubt, any Claims or Losses to be paid by Buyer or the Company pursuant to Section 5.03(a)(ii) is not subject to the limitations of this Section 5.03(c).

5.04                 Indemnification Procedures; Matters Involving Third Parties.

(a)           A Seller Indemnitee or Buyer Indemnitee, as the case may be (for purposes of this Section 5.04, an “Indemnified Party”), shall give the indemnifying party under Section 5.02 and Section 5.03, as applicable (for purposes of this Section 5.04, an “Indemnifying Party”), prompt written notice of any matter which it has determined has given or could give rise to a right of indemnification under this Environmental Agreement stating the nature of the Claim and an estimated or actual amount of the Loss, if known, and method of computation thereof, containing a reference to the provisions of this Environmental Agreement in respect of which such right of indemnification is claimed or arises; provided, however, that the failure to provide such notice shall not release the Indemnifying Party from its Obligations under this Article V except to the extent, and only to the extent, the Indemnifying Party is prejudiced by such failure or to the extent the survival period, if applicable, expires pursuant to Section 5.01 prior to the giving of such notice.

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(b)           If any third party shall notify an Indemnified Party with respect to any matter (a “Third-Party Claim”) that may give rise to a claim for indemnification against the Indemnifying Party under this Article V, then the Indemnified Party shall promptly (and in any event within five (5) Business Days after receiving notice of the Third-Party Claim) notify the Indemnifying Party thereof in writing; provided, however, that the failure to provide such notice shall not release the Indemnifying Party from its Obligations under this Article V except to the extent, and only to the extent, the Indemnifying Party is prejudiced by such failure.

(c)           The Indemnifying Party will have the right to assume and thereafter conduct the defense of the Third-Party Claim with counsel of its choice reasonably satisfactory to the Indemnified Party; provided, that the Indemnifying Party will not consent to the entry of any judgment or enter into any settlement with respect to the Third-Party Claim without the prior written consent of the Indemnified Party (not to be unreasonably withheld) unless the judgment or proposed settlement involves only the payment of money damages and does not impose an injunction or other equitable relief upon the Indemnified Party or would reasonably be expected to have a material adverse effect on the Indemnified Party.

(d)           Unless and until the Indemnifying Party assumes the defense of the Third Party Claim as provided in Section 5.04(c), the Indemnified Party may defend against the Third- Party Claim in any manner it may reasonably deem appropriate.

(e)           In no event will the Indemnified Party consent to the entry of any judgment or enter into any settlement with respect to the Third-Party Claim without the prior written consent of the Indemnifying Party (not to be unreasonably withheld).

(f)           If the Parties are unable to agree as to issues related to Seller’s environmental indemnification, then an independent and experienced third party environmental consulting firm that is mutually agreeable to Seller and Buyer shall evaluate and determine the non-legal issues that are in dispute.

5.05                 Determination of Losses.

(a)           The Losses giving rise to any indemnification Obligation hereunder shall be reduced by any insurance proceeds actually received by the Indemnified Party as a result of the events giving rise to the claim for indemnification, net of any expenses related to the receipt of such proceeds, including retrospective premium adjustments, if any. The amount of the indemnity payment shall be computed by taking into account the timing of the loss or payment, as applicable, at the Applicable Rate from the date the Indemnified Party provides notice of the Loss to the Indemnifying Party until the date paid. Upon the request of the Indemnifying Party, the Indemnified Party shall provide the Indemnifying Party with information sufficient to allow the Indemnifying Party to calculate the amount of the indemnity payment in accordance with this Section 5.05.

(b)           An Indemnified Party shall take all reasonable steps to mitigate damages in respect of any claim for which it is seeking indemnification and shall use reasonable efforts to avoid any costs or expenses associated with such claim and, if such costs and expenses cannot be avoided, to minimize the amount thereof; provided, that an Indemnified Party shall have no Obligation to make a claim for recovery against any insurer of such Indemnified Party with respect to any such Losses.

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(c)           For purposes of determining whether a breach has occurred and calculating a Loss in connection with a claim for indemnification under this Article V, each of the representations and warranties that contains any qualifications as to materiality or “Material Adverse Effect” will be determined with regard to such materiality or “Material Adverse Effect” qualifier contained in the terms of such representation and warranty; provided, however, that if the representation or warranty is breached (after taking into consideration such materiality or “Material Adverse Effect” qualifier) then the amount of Losses arising out of such breach will be determined without regards to such materiality or “Material Adverse Effect” qualifier.

5.06                 No Multiple Recoveries.  Any liability for indemnification hereunder shall be determined without duplication of recovery by reason of the state of facts giving rise to such liability constituting a breach of more than one representation, warranty or covenant.

5.07                 Limitations on Liability/Exclusive Remedies.

(a)           NOTWITHSTANDING  ANYTHING  TO  THE  CONTRARY CONTAINED IN THIS ENVIRONMENTAL AGREEMENT, NO PARTY HERETO SHALL BE ENTITLED TO RECOVER FROM ANY OTHER PARTY HERETO OR ANY OF SUCH PARTY’S AFFILIATES ANY AMOUNT IN RESPECT OF EXEMPLARY, PUNITIVE, SPECIAL, INDIRECT  OR  CONSEQUENTIAL  DAMAGES,  INCLUDING  LOST  PROFITS; EXCEPT, HOWEVER, WITH RESPECT TO ANY OF THE FOREGOING PAID OR OWING TO A THIRD PARTY WITH RESPECT TO A THIRD PARTY CLAIM, WHICH DAMAGES SHALL BE CONSIDERED PART OF LOSSES AND SHALL BE COVERED BY THE INDEMNIFICATIONS SET FORTH IN THIS ARTICLE V.

(b)           ALL  RELEASES, DISCLAIMERS,  LIMITATIONS  ON  LIABILITY  AND  INDEMNITIES  IN  THIS ENVIRONMENTAL AGREEMENT, INCLUDING THOSE IN THIS ARTICLE V, SHALL APPLY EVEN IN THE EVENT OF THE SOLE, JOINT OR CONCURRENT, ACTIVE OR PASSIVE NEGLIGENCE,  STRICT  LIABILITY  OR  FAULT  OF  THE  PARTY  WHOSE LIABILITY IS RELEASED, DISCLAIMED, LIMITED OR INDEMNIFIED.

5.08                 Governing Law.  This Environmental Agreement shall be construed (both as to validity and performance), interpreted and enforced in accordance with, and governed by, the Laws of the State of Texas, without regard to conflicts of laws rules or principles as applied in Texas.

5.09                 Jurisdiction; Consent to Service of Process; Waiver.  Each of the Parties agrees that it shall bring any Proceeding in respect of any claim arising out of or related to this Environmental Agreement, whether in tort or contract or at law or in equity, exclusively in any Federal or state court in Harris County, Texas and solely in connection with claims arising under such agreement or instrument or the transactions contained in or contemplated by such agreement or instrument, (i) irrevocably submits to the exclusive jurisdiction of such courts, (ii) waives any objection to laying venue in any such Proceeding in such courts, (iii) waives any objection that such courts are an inconvenient forum or do not have jurisdiction over it and (iv) agrees that service of process upon it may be effected by mailing a copy thereof by registered or certified mail (or any substantially similar form of mail), postage prepaid, to it at its address specified in Section 6.02. The foregoing consents to jurisdiction and service of process shall not constitute general consents to service of process in the State of Texas for any purpose except as provided herein and shall not be deemed to confer rights on any Person other than the Parties. EACH PARTY ACKNOWLEDGES AND AGREES THAT ANY DISPUTE IS LIKELY TO INVOLVE COMPLICATED AND DIFFICULT ISSUES, AND THEREFORE EACH SUCH PARTY HEREBY IRREVOCABLY AND UNCONDITIONALLY WAIVES ANY RIGHT SUCH PARTY MAY HAVE TO A TRIAL BY JURY IN RESPECT OF ANY LITIGATION DIRECTLY OR INDIRECTLY ARISING OUT OF OR RELATING TO THIS ENVIRONMENTAL AGREEMENT OR THE TRANSACTIONS CONTEMPLATED BY THIS ENVIRONMENTAL AGREEMENT. EACH PARTY CERTIFIES AND ACKNOWLEDGES THAT: (i) NO REPRESENTATIVE, AGENT OR ATTORNEY OF ANY OTHER PARTY HAS REPRESENTED, EXPRESSLY OR OTHERWISE, THAT SUCH OTHER PARTY WOULD NOT, IN THE EVENT OF LITIGATION, SEEK TO ENFORCE THE FOREGOING WAIVER; (ii) EACH PARTY UNDERSTANDS AND HAS CONSIDERED THE IMPLICATIONS OF THIS WAIVER; (iii) EACH PARTY MAKES THIS WAIVER VOLUNTARILY; AND (iv) EACH PARTY HAS BEEN INDUCED TO ENTER INTO THIS ENVIRONMENTAL AGREEMENT BY, AMONG OTHER THINGS, THE MUTUAL WAIVERS AND CERTIFICATIONS IN THIS  SECTION 5.09.

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ARTICLE VI

MISCELLANEOUS PROVISIONS

6.01                 Amendment.  This Environmental Agreement (including this Section 6.01) may not be amended except by an instrument in writing executed and delivered by the Parties. The failure of any Party at any time or times to require performance of any provision hereof shall in no manner affect the right at a later time to enforce the same.  No waiver by any Party of any condition, or of any breach of any term, covenant, representation or warranty contained in this Environmental Agreement, in any one or more instances, shall be deemed to be or construed as a further or continuing waiver of any such condition or breach or a waiver of any other condition or of any breach of any other term, covenant, representation or warranty.  No course of dealing between or among any Persons having any interest in this Environmental Agreement shall be deemed effective to modify, amend or discharge any part of this Agreement or any rights or obligations of any Person under or by reason of this Environmental Agreement.

6.02                 Notices.  All notices and other communications that are required to be or may be given pursuant to this Environmental Agreement shall be delivered in accordance with the notice provisions set forth in Section 12.2 of the Purchase Agreement.

6.03                 Expenses.  Except as otherwise expressly provided herein, all costs and expenses incurred by Seller or its Affiliates in connection with this Environmental Agreement and the transactions contemplated hereby shall be paid by Seller, and all costs and expenses incurred by Buyer or its Affiliates in connection with this Environmental Agreement and the transactions contemplated hereby shall be paid by Buyer.

6.04                 Headings.  The headings contained in this Environmental Agreement are for reference purposes only and shall not affect in any way the meaning or interpretation of this Environmental Agreement.

6.05                 No Strict Construction.  The Parties acknowledge that each of them has been represented by counsel in connection with this Environmental Agreement and the transactions contemplated hereby.  Notwithstanding the fact that this Environmental Agreement has been drafted or prepared by one of the Parties, the Parties confirm that they and their respective counsel have reviewed, negotiated and adopted this Environmental Agreement as the joint agreement and understanding of the Parties, and the language used in this Environmental Agreement shall be deemed to be the language chosen by the Parties to express their mutual intent, and no rule of strict construction shall be applied against any Person and any rule of Law that would require interpretation of any claimed ambiguities in this Environmental Agreement against the Party that drafted it has no application and is expressly waived.

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6.06                 Severability.  If any term or other provision of this Environmental Agreement is invalid, illegal or incapable of being enforced by any rule of Law or public policy, all other conditions and provisions of this Environmental Agreement shall nevertheless remain in full force and effect, and the invalid, illegal or unenforceable provision shall be reformed to the minimum extent required to render such provision valid, legal and enforceable and in a manner so as to preserve the economic and legal substance of the transactions contemplated hereby to the fullest extent permitted by Law. Upon such determination that any term or other provision is invalid, illegal or incapable of being enforced, the Parties shall negotiate in good faith to modify this Environmental Agreement so as to effect the original intent of the Parties as closely as possible in an acceptable manner to the end that transactions contemplated hereby are fulfilled to the extent possible.

6.07                 Assignment.  This Environmental Agreement shall not be assigned by any Party (including by operation of Law or otherwise) except with the prior written consent of the other Party. Any purported assignment of this Environmental Agreement in violation of this Section 6.07 shall be null and void.

6.08                 Parties in Interest.  This Environmental Agreement shall be binding upon and inure solely to the benefit of each Party and its permitted successors and assigns, and nothing in this Environmental Agreement, express or implied, is intended to or shall confer upon any other Person any right, benefit or remedy of any nature whatsoever under or by reason of this Environmental Agreement.

6.09                 Failure or Indulgence Not Waiver.  No failure or delay on the part of any Party in the exercise of any right hereunder shall impair such right or be construed to be a waiver of, or acquiescence in, any breach of any representation, warranty, covenant or agreement herein, nor shall any single or partial exercise of any such right preclude other or further exercise thereof or of any other right.

6.10                 Disclosure Schedules.  Any matter disclosed by Seller in the Schedules pursuant to any Section of this Environmental Agreement shall be deemed to have been disclosed by Seller for purposes of each other Section of this Environmental Agreement to which such disclosure is relevant as and to the extent that the relevance of such matter to such other Section is readily apparent on the face of such disclosure. The listing (or inclusion of a copy) of a document or other item in the Schedules shall be adequate to disclose an exception to a representation or warranty made herein if the nature and relevance of such exception is readily apparent from the listing (or inclusion of a copy) of such document.

6.11                 Time of the Essence.  Time is of the essence in this Environmental Agreement. If the date specified in this Environmental Agreement for giving any notice or taking any action is not a Business Day (or if the period during which any notice is required to be given or any action taken expires on a date which is not a Business Day), then the date for giving such notice or taking such action (and the expiration date of such period during which notice is required to be given or action taken) shall be the next day which is a Business Day.

6.12                 Entire Agreement.  This Environmental Agreement, the Purchase Agreement and the Related Agreements (together with the Exhibits, the Disclosure Schedules and the other Schedules hereto and thereto) constitute the entire agreement of the parties hereto and thereto, and supersede all prior agreements and undertakings, both written and oral, among the Parties, with respect to the subject matter hereof (other than the Confidentiality Agreement, which shall continue in full force and effect).

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6.13                 Specific Performance.  Each Party acknowledges that the breach of this Environmental Agreement by the other Party would cause irreparable damage to such Party and that money damages or other legal remedies would not be an adequate remedy for any such damages. Therefore, the obligations of each Party under this Environmental Agreement shall be enforceable by a decree of specific performance and appropriate injunctive relief may be applied for and granted in connection therewith, without the requirement to post any bond or security in connection therewith. Such remedies shall, however, be cumulative and not exclusive and shall be in addition to any other remedies which any Party may have under this Environmental Agreement or otherwise.

6.14                 Counterparts.  This Environmental Agreement may be executed in multiple counterparts and by the different Parties in separate counterparts, each of which when executed shall be deemed to be an original but all of which taken together shall constitute one and the same agreement. Signed counterparts of this Environmental Agreement may be delivered by facsimile and by scanned pdf image; provided that each Party uses Commercially Reasonable Efforts to deliver to each other Party original signed counterparts as soon as possible thereafter.

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The Parties have executed and delivered this Environmental Agreement as of the date first written above.

TESORO CORPORATION

By: /s/ Gregory J. Goff

Gregory J. Goff

President and Chief Executive Officer

HAWAII PACIFIC ENERGY, LLC (on behalf of itself and on behalf of the Company)

By: /s/ Brice Tarzwell                              

Brice Tarzwell

Vice President and Secretary

EX-10.17

Exhibit 10.17

Equity Group Investments

2 N Riverside Plaza, Suite 2100

Chicago, IL  60606

Attn: Jon Wasserman

Dear Mr. Wasserman:

This letter agreement, dated as of September __, 2013 but effective as of January 1, 2013, will confirm our understanding of the basis on which EGI Advisors, LLC (together with its affiliates, “EGI”) will provide, directly or indirectly, on a non-exclusive basis, certain advisory services to Par Petroleum Corporation (together with its affiliates and subsidiaries, the “Company”) in connection with Matters (as such term is defined herein).

1.           Strategic, Advisory and Consulting Services. EGI hereby agrees that, during the Term (as such term is defined herein), to the extent requested by the Company and deemed appropriate by EGI, EGI shall render to the Company, by and through itself, its affiliates, and its respective officers, members, employees and representatives as EGI in its sole discretion shall designate from time to time, advisory and consulting services in relation to the affairs of the Company in connection with ongoing strategic and operational oversight of the Company, which may include, without limitation, (a) advice on financing structures and relationships with the Company’s lenders and bankers; (b) advice regarding public and private offerings of debt and equity securities of the Company; (c) advice regarding asset dispositions, acquisitions or other asset management strategies; (d) advice regarding potential business acquisitions, dispositions or combinations involving the Company or its affiliates, (which advice may include, by way of illustration only, identifying and evaluating candidates for acquisitions, dispositions or business combination transactions, assisting the Company in evaluating and responding to inquiries and proposals that may be received by the Company regarding potential acquisitions, dispositions or business combination transactions, assisting the Company in negotiations in respect of acquisitions, dispositions or business combination transactions and consulting with and assisting counsel and accountants in the structuring and execution of acquisitions, dispositions or business combination transactions), and (e) such other advice directly related or ancillary to the above strategic, advisory and consulting services as may be reasonably requested by the Company (any transaction or matter being the subject matter of any advice provided hereunder directly or indirectly by EGI being referred to herein as a “Matter”).  Except as provided in Section 3 hereof, EGI shall not charge a fee for the provision of strategic, advisory and consulting services set forth in clauses (a) through (e) of this Section 1.   The Company acknowledges and agrees that the Company shall rely solely on the counsel of its own attorneys regarding legal matters and shall consult with and rely solely upon the advice of its own tax advisors and other advisers regarding the tax consequences and other economic considerations with respect to any Matter.

2.           Additional Services.  In addition to the strategic, advisory and consulting services set forth in clauses (a) through (e) of Section 1 hereof, upon the request of the Company, EGI may also provide such additional services as may be agreed upon in writing by the Company and

EGI and specifically set forth as an addendum to this letter agreement.  Such addendum shall set forth in reasonable detail the nature of the services to be provided and the charges associated with such services.

3.           Reimbursement of Expenses.  Whether or not any proposed Matter is consummated, the Company agrees to periodically reimburse EGI, upon request, for: (a) EGI’s travel and other out-of-pocket expenses, provided, however, that in the event such expenses exceed $50,000 in the aggregate with respect to any single proposed Matter, EGI shall first obtain the Company’s consent before incurring additional reimbursable expenses, and (b) provided the Company’s prior consent to their engagement with respect to any particular proposed Matter is obtained, all reasonable fees and disbursements of counsel, accountants and other professionals, in each case incurred in connection with EGI’s services under this letter agreement.  The Company agrees that, in lieu of reimbursing EGI for such expenses, EGI may forward to the Company invoices for the same, and the Company shall promptly pay such invoices directly to the payee.

4.           Confidentiality.  The Company acknowledges and agrees that from time to time Confidential Information of the Company has been, and in the future may be, shared between EGI and its Representatives and Representatives of the Company (including without limitation directors of the Company that may be otherwise affiliated with EGI) in connection with the provision of advice by EGI to the Company and such Representatives.  The parties hereby agree that such Confidential Information may continue to be shared, consistent with past practice and such sharing of information is ratified and approved; provided, that EGI will abide by the confidentiality provisions of any confidentiality agreement, non-disclosure agreement or similar agreement executed by the Company in connection with a Matter that pertain to Confidential Information; provided, however, that notwithstanding the foregoing, EGI shall have no obligation hereunder or under any such confidentiality agreement, non-disclosure agreement or similar agreement with respect to any Confidential Information which (a) is or becomes available to the public other than as a result of a disclosure by EGI or its Representatives (as such term is hereinafter defined) in violation hereof, (b) was available to EGI on a non-confidential basis prior to its disclosure by or at the request of the Company (including without limitation by any of the Representatives of the Company), (c) becomes available to EGI on a non-confidential basis from a person (other than the Company or any of its Representatives) who is not known to EGI to be prohibited from disclosing such information to EGI by a legal, contractual or fiduciary obligation, or (d) is independently developed by EGI or on EGI’s behalf without violating any of EGI’s obligations hereunder; and provided, further, that EGI and its Representatives and Representatives of the Company (including directors of the Company that may be otherwise affiliated with EGI) shall not be prohibited from obtaining, using or retaining any Confidential Information for purposes of monitoring and evaluating EGI’s (or its affiliates) investment in the Company or exercising any voting, governance, control or other rights and responsibilities in the capacity as a stockholder of the Company or as a member of the Board of Directors of the Company.  As used in this letter agreement, (i) the term “Confidential Information” means any and all information (whether in written, oral, digital or other tangible or intangible form) in respect of a Matter, any party thereto, any affiliate or subsidiary of any such party that is

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provided to EGI or its Representatives by or at the request of the Company (including without limitation by any of the Representatives of the Company), whether provided before or after the date of this letter agreement, together with all analyses, compilations, forecasts, studies or other documents or materials, whether prepared by EGI or its Representatives, that contain or otherwise reflect such information or its review of, or interest in, the Matter; (ii) the “Representatives” of a person are the directors, officers, managers, members, partners, employees, representatives, financial, legal, accounting and other advisors (including, without limitation, consultants, bankers, financial advisers and any representatives of any such advisers), affiliates, potential sources of capital, and agents of such person, and (iii) the term “person” shall be broadly interpreted to include without limitation the media and any corporation, partnership, group, individual or other entity.  The parties hereby agree that this paragraph shall survive the termination of this letter agreement.

5.           Indemnification; No Liability.  In consideration of EGI’s services as described herein or provided under this letter agreement, including, without limitation, any Addendum hereto, the Company agrees to indemnify and hold harmless EGI, its direct and indirect affiliates (including, without limitation, any trust companies) and each of their respective directors, officers, agents, employees, trustees, trust beneficiaries, other Representatives, stockholders, partners, members and other affiliated persons (each of the foregoing an “Indemnified Party”) against any and all losses, claims, damages or liabilities (or actions or proceedings in respect thereof) relating to or arising out of this letter agreement or EGI’s provision of any services hereunder and will reimburse each Indemnified Party for reasonable attorneys’, accountants’, investigators’, and experts’ fees and expenses and other out-of-pocket fees and expenses incurred in connection with investigating or defending any such loss, claim, damage, liability, action or proceeding, whether or not in connection with pending or threatened litigation in which any Indemnified Party is a party; provided, however, that the Company will not be liable in any such case for losses, claims, damages, liabilities or expenses that a court of competent jurisdiction shall have determined in a final unappealable judgment to have arisen primarily from the gross negligence, bad faith or willful misconduct of the Indemnified Party seeking indemnification.  In addition, neither EGI nor any other Indemnified Party shall have any liability (whether direct or indirect, in contract, tort or otherwise) related to or arising from this letter agreement or EGI’s provision of any services hereunder, except for liability for losses, claims, damages and expenses that a court of competent jurisdiction shall have determined in a final unappealable judgment to have arisen primarily from EGI’s gross negligence, bad faith or willful misconduct.  The Company expressly acknowledges and agrees that each Indemnified Party is an intended third party beneficiary of this Section 5, and that each Indemnified Party shall have the right individually to enforce the terms and provisions of this Section 5.

6.           Permissible Activities.  Subject to applicable law, nothing herein shall in any way preclude EGI or any other Indemnified Party from engaging in any business activities or from performing services for its or their own account or for the account of others, including for companies that may be in competition with the business conducted by the Company.

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7.           Term.  The term of this letter agreement (the “Term”) shall be for a period of one year beginning on the date hereof.  The Term shall be automatically extended for successive one-year periods unless EGI or the Company provides the other party hereto with written notice at least 60 days prior to any extension date that it desires to terminate this letter agreement. The provisions of Sections 4 and 5 and otherwise as the context so requires shall survive the termination of this letter agreement.

8.           Governing Law; Amendments.  This letter agreement (a) shall be governed by, and construed in accordance with, the laws of the State of Texas without regard to the principles of conflicts of law, (b) contains the complete and entire understanding and agreement of EGI and the Company with respect to the specific subject matter hereof, and supersedes all unperformed prior understandings, conditions and agreements, oral or written, express or implied, respecting EGI’s provision of services in connection with any contemplated Matter and the other subject matter specifically addressed herein, (c) may be amended or modified in a writing duly executed by both of the parties hereto and not by any course of conduct, course of dealing or purported oral amendment or modification, and (d) may be executed by the parties hereto on any number of separate counterparts, and all of said counterparts taken together shall be deemed to constitute one and the same instrument.  The waiver by either party of a breach of any provision of this letter agreement by the other party shall not operate or be construed as a waiver of any subsequent breach of that provision or any other provision hereof.

9.           Assignment.  Neither EGI nor the Company may assign or delegate their rights or obligations under this letter agreement without the express written consent of the other party hereto, except that (a) EGI may assign any and all of its rights under this letter agreement to receive reimbursement of EGI’s expenses as provided in this letter agreement, and (b) the Company’s rights and obligations hereunder may be assigned and delegated by operation of law pursuant to any merger, reorganization or similar business combination.  This letter agreement and all the obligations and benefits hereunder shall be binding upon and shall inure to the successors and permitted assigns of the parties.

10.           Severability. Any provision of this letter agreement which is prohibited or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof, and any such prohibition or unenforceability in any jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction.

[SIGNATURE PAGE FOLLOWS]

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If the foregoing accurately sets forth our understanding, please so signify by signing and returning to us the enclosed duplicate hereof.

Very truly yours,

PAR PETROLEUM CORPORATON

By:           /s/ Brice Tarzwell                                                      

Name: BRICE TARZWELL

Title:   SENIOR VICE PRESIDENT,

       CHIEF LEGAL OFFICER

Accepted and agreed

to as of the date

first above written:

EQUITY GROUP INVESTMENTS

By:            /s/ Jon Wasserman           

        Name: Jon Wasserman

        Title: Chief Legal Officer and

                   Managing Director

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ADDENDUM NO. 1

Public and Investor Relations and Communications Advisory Services

Upon the request of the Company, EGI shall provide, public and investor relations and general communications advisory services (collectively, the “Communication Services”) through its employee, Terry Holt, to the Company at the rate of $200 per hour measured in increments of 0.25 hours; provided, however, that the Company shall not be obligated to pay for such Communication Services unless and until 5.0 hours of Communication Services per Matter have been provided, at which time all of such Communication Services shall become due and payable.

This ADDENDUM No. 1 is agreed and accepted as of this ___ day of _______, 2013.

EQUITY GROUP INVESTMENTS

By:  ________________________

Name:

Title:

PAR PETROLEUM CORPORATION

By:  ________________________

        Name:

        Title:

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EX-10.18

Exhibit 10.18

Whitebox Advisors, LLC

3033 Excelsior Boulevard, Suite 300

Minneapolis, MN  55416

Attn: Jake Mercer

Dear Mr. Mercer:

This letter agreement, dated as of September 17, 2013 but effective as of January 1, 2013, will confirm our understanding of the basis on which Whitebox Advisors, LLC (together with its affiliates, “Whitebox”) will provide, directly or indirectly, on a non-exclusive basis, certain advisory services to Par Petroleum Corporation (together with its affiliates and subsidiaries, the “Company”) in connection with Matters (as such term is defined herein).

1.           Strategic, Advisory and Consulting Services.  By execution hereof, Whitebox  agrees that, during the Term (as such term is defined herein), to the extent requested by the Company and deemed appropriate by Whitebox, Whitebox shall render to the Company, by and through itself, its affiliates, and its respective officers, members, employees and representatives as Whitebox in its sole discretion shall designate from time to time, advisory and consulting services in relation to the affairs of the Company in connection with ongoing strategic and operational oversight of the Company, which may include, without limitation, (a) advice on financing structures and relationships with the Company’s lenders and bankers; (b) advice regarding public and private offerings of debt and equity securities of the Company; (c) advice regarding asset dispositions, acquisitions or other asset management strategies; (d) advice regarding potential business acquisitions, dispositions or combinations involving the Company or its affiliates, (which advice may include, by way of illustration only, identifying and evaluating candidates for acquisitions, dispositions or business combination transactions, assisting the Company in evaluating and responding to inquiries and proposals that may be received by the Company regarding potential acquisitions, dispositions or business combination transactions, assisting the Company in negotiations in respect of acquisitions, dispositions or business combination transactions and consulting with and assisting counsel and accountants in the structuring and execution of acquisitions, dispositions or business combination transactions), and (e) such other advice directly related or ancillary to the above strategic, advisory and consulting services as may be reasonably requested by the Company (any transaction or matter being the subject matter of any advice provided hereunder directly or indirectly by Whitebox being referred to herein as a “Matter”).  Except as provided in Section 3 hereof, Whitebox shall not charge a fee for the provision of strategic, advisory and consulting services set forth in clauses (a) through (e) of this Section 1.   The Company acknowledges and agrees that the Company shall rely solely on the counsel of its own attorneys regarding legal matters and shall consult with and rely solely upon the advice of its own tax advisors and other advisers regarding the tax consequences and other economic considerations with respect to any Matter.

2.           Additional Services.  In addition to the strategic, advisory and consulting services set forth in clauses (a) through (e) of Section 1 hereof, upon the request of the Company, Whitebox may also provide such additional services as may be agreed upon in writing by the Company and Whitebox and specifically set forth as an addendum to this letter agreement.  Such addendum shall set forth in reasonable detail the nature of the services to be provided and the charges associated with such services.

3.           Reimbursement of Expenses.  Whether or not any proposed Matter is consummated, the Company agrees to periodically reimburse Whitebox, upon request, for: (a) Whitebox’s travel and other out-of-pocket expenses, provided, however, that in the event such expenses exceed $50,000 in the aggregate with respect to any single proposed Matter, Whitebox shall first obtain the Company’s consent before incurring additional reimbursable expenses, and (b) provided the Company’s prior consent to their engagement with respect to any particular proposed Matter is obtained, all reasonable fees and disbursements of counsel, accountants and other professionals, in each case incurred in connection with Whitebox’s services under this letter agreement.  The Company agrees that, in lieu of reimbursing Whitebox for such expenses, Whitebox may forward to the Company invoices for the same, and the Company shall promptly pay such invoices directly to the payee.

4.           Confidentiality.  The Company acknowledges and agrees that from time to time Confidential Information of the Company has been, and in the future may be, shared between Whitebox and its Representatives and Representatives of the Company (including without limitation directors of the Company that may be otherwise affiliated with Whitebox) in connection with the provision of advice by Whitebox to the Company and such Representatives.  The parties hereby agree that such Confidential Information may continue to be shared, consistent with past practice and such sharing of information is ratified and approved; provided, that Whitebox will abide by the confidentiality provisions of any confidentiality agreement, non-disclosure agreement or similar agreement executed by the Company in connection with a Matter that pertain to Confidential Information; provided, however, that notwithstanding the foregoing, Whitebox shall have no obligation hereunder or under any such confidentiality agreement, non-disclosure agreement or similar agreement with respect to any Confidential Information which (a) is or becomes available to the public other than as a result of a disclosure by Whitebox or its Representatives (as such term is hereinafter defined) in violation hereof, (b) was available to Whitebox on a non-confidential basis prior to its disclosure by or at the request of the Company (including without limitation by any of the Representatives of the Company), (c) becomes available to Whitebox on a non-confidential basis from a person (other than the Company or any of its Representatives) who is not known to Whitebox to be prohibited from disclosing such information to Whitebox by a legal, contractual or fiduciary obligation, or (d) is independently developed by Whitebox or on Whitebox’s behalf without violating any of Whitebox’s obligations hereunder; and provided, further, that Whitebox and its Representatives and Representatives of the Company (including directors of the Company that may be otherwise affiliated with Whitebox) shall not be prohibited from obtaining, using or retaining any Confidential Information for purposes of monitoring and evaluating Whitebox’s (or its affiliates) investment in the Company or exercising any voting, governance, control or other rights and

2

responsibilities in the capacity as a stockholder of the Company or as a member of the Board of Directors of the Company.  As used in this letter agreement, (i) the term “Confidential Information” means any and all information (whether in written, oral, digital or other tangible or intangible form) in respect of a Matter, any party thereto, any affiliate or subsidiary of any such party that is provided to Whitebox or its Representatives by or at the request of the Company (including without limitation by any of the Representatives of the Company), whether provided before or after the date of this letter agreement, together with all analyses, compilations, forecasts, studies or other documents or materials, whether prepared by Whitebox or its Representatives, that contain or otherwise reflect such information or its review of, or interest in, the Matter; (ii) the “Representatives” of a person are the directors, officers, managers, members, partners, employees, representatives, financial, legal, accounting and other advisors (including, without limitation, consultants, bankers, financial advisers and any representatives of any such advisers), affiliates, potential sources of capital, and agents of such person, and (iii) the term “person” shall be broadly interpreted to include without limitation the media and any corporation, partnership, group, individual or other entity.  The parties hereby agree that this paragraph shall survive the termination of this letter agreement.

5.           Indemnification; No Liability.  In consideration of Whitebox’s services as described herein or provided under this letter agreement, including, without limitation, any Addendum hereto, the Company agrees to indemnify and hold harmless Whitebox, its direct and indirect affiliates (including, without limitation, any trust companies) and each of their respective directors, officers, agents, employees, trustees, trust beneficiaries, other Representatives, stockholders, partners, members and other affiliated persons (each of the foregoing an “Indemnified Party”) against any and all losses, claims, damages or liabilities (or actions or proceedings in respect thereof) relating to or arising out of this letter agreement or Whitebox’s provision of any services hereunder and will reimburse each Indemnified Party for reasonable attorneys’, accountants’, investigators’, and experts’ fees and expenses and other out-of-pocket fees and expenses incurred in connection with investigating or defending any such loss, claim, damage, liability, action or proceeding, whether or not in connection with pending or threatened litigation in which any Indemnified Party is a party; provided, however, that the Company will not be liable in any such case for losses, claims, damages, liabilities or expenses that a court of competent jurisdiction shall have determined in a final unappealable judgment to have arisen primarily from the gross negligence, bad faith or willful misconduct of the Indemnified Party seeking indemnification.  In addition, neither Whitebox nor any other Indemnified Party shall have any liability (whether direct or indirect, in contract, tort or otherwise) related to or arising from this letter agreement or Whitebox’s provision of any services hereunder, except for liability for losses, claims, damages and expenses that a court of competent jurisdiction shall have determined in a final unappealable judgment to have arisen primarily from Whitebox’s gross negligence, bad faith or willful misconduct.  The Company expressly acknowledges and agrees that each Indemnified Party is an intended third party beneficiary of this Section 5, and that each Indemnified Party shall have the right individually to enforce the terms and provisions of this Section 5.

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6.           Permissible Activities.  Subject to applicable law, nothing herein shall in any way preclude Whitebox or any other Indemnified Party from engaging in any business activities or from performing services for its or their own account or for the account of others, including for companies that may be in competition with the business conducted by the Company.

7.           Term.  The term of this letter agreement (the “Term”) shall be for a period of one year beginning on the date hereof.  The Term shall be automatically extended for successive one-year periods unless Whitebox or the Company provides the other party hereto with written notice at least 60 days prior to any extension date that it desires to terminate this letter agreement. The provisions of Sections 4 and 5 and otherwise as the context so requires shall survive the termination of this letter agreement.

8.           Governing Law; Amendments.  This letter agreement (a) shall be governed by, and construed in accordance with, the laws of the State of Texas without regard to the principles of conflicts of law, (b) contains the complete and entire understanding and agreement of Whitebox and the Company with respect to the specific subject matter hereof, and supersedes all unperformed prior understandings, conditions and agreements, oral or written, express or implied, respecting Whitebox’s provision of services in connection with any contemplated Matter and the other subject matter specifically addressed herein, (c) may be amended or modified in a writing duly executed by both of the parties hereto and not by any course of conduct, course of dealing or purported oral amendment or modification, and (d) may be executed by the parties hereto on any number of separate counterparts, and all of said counterparts taken together shall be deemed to constitute one and the same instrument.  The waiver by either party of a breach of any provision of this letter agreement by the other party shall not operate or be construed as a waiver of any subsequent breach of that provision or any other provision hereof.

9.           Assignment.  Neither Whitebox nor the Company may assign or delegate their rights or obligations under this letter agreement without the express written consent of the other party hereto, except that (a) Whitebox may assign any and all of its rights under this letter agreement to receive reimbursement of Whitebox’s expenses as provided in this letter agreement, and (b) the Company’s rights and obligations hereunder may be assigned and delegated by operation of law pursuant to any merger, reorganization or similar business combination.  This letter agreement and all the obligations and benefits hereunder shall be binding upon and shall inure to the successors and permitted assigns of the parties.

10.           Severability. Any provision of this letter agreement which is prohibited or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof, and any such prohibition or unenforceability in any jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction.

[SIGNATURE PAGE FOLLOWS]

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If the foregoing accurately sets forth our understanding, please so signify by signing and returning to us the enclosed duplicate hereof.

Very truly yours,

PAR PETROLEUM CORPORATION

By:    /s/ Brice Tarzwell                                                                                     

Name:  BRICE TARZWELL

Title:    SENIOR VICE PRESIDENT,

        CHIEF LEGAL OFFICER

Accepted and agreed

to as of the date

first above written:

WHITEBOX ADVISORS, LLC

By:      /s/ Jacob Mercer                       

        Name:  Jacob Mercer

        Title:   Senior Portfolio Manager

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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 quarterly report on Form 10-Q 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: November 14, 2013

/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, R. Seth Bullock, certify that:

1. I have reviewed this quarterly report on Form 10-Q 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: November 14, 2013

/s/ R. Seth Bullock

R. Seth Bullock

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

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

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Par Petroleum Corporation (the “Company”) on Form 10-Q for the period ended September 30, 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

November 14, 2013

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 Quarterly Report of Par Petroleum Corporation (the “Company”) on Form 10-Q for the period ended September 30, 2013 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, R. Seth Bullock, 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/ R. Seth Bullock

R. Seth Bullock

Chief Financial Officer

November 14, 2013

XML

(11) Earnings Per Share

9 Months Ended

Sep. 30, 2013

Notes

(11) Earnings Per Share

(11) Earnings Per Share

Basic earnings per share (“EPS”) are 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, representing 9,737,182 shares (see Note 5 and 6). U.S. GAAP requires the inclusion of these Warrants in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation as these shares are not considered earned until vesting. The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share amounts):

	Successor			Successor			Predecessor
	Three Months Ended September 30,  2013			One Month  Ended September 30,  2012			Two Months Ended August 31,  2012
Net loss attributable to common stockholders	$	(14,620	)	$	(2,002	)	$	(16,062	)
Basic weighted-average common stock outstanding		167,523			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		167,523			157,248			28,841
Basic loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)
Diluted loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)

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

	Successor		Successor		Predecessor
	Three Months  Ended September 30, 2013		One Month  Ended September 30, 2012		Two Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

	Successor			Successor			Predecessor
	Nine Months Ended  September 30,  2013			One Month  Ended  September 30,  2012			Eight Months  Ended August 31, 2012
Net loss attributable to common stockholders	$	(28,650	)	$	(2,002	)	$	(45,437	)
Basic weighted-average common stock outstanding		161,633			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		161,633			157,248			28,841
Basic loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)
Diluted loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)

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

	Successor		Successor		Predecessor
	Nine Months  Ended September 30,  2013		One Month  Ended September 30,  2012		Eight Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

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(5) Inventories: Schedule of Inventory (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Crude oil and feedstocks	$ 128,871
Refined products and blend stock	248,935
Warehouse stock and other	17,992
Titled Inventory
Refined products and blend stock	49,841
Warehouse stock and other	17,992
Supply and Exchange Agreements
Crude oil and feedstocks	128,871
Refined products and blend stock	$ 199,094

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CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	1 Months Ended	3 Months Ended	9 Months Ended	2 Months Ended	8 Months Ended
	Sep. 30, 2012 Successor	Sep. 30, 2013 Successor	Sep. 30, 2013 Successor	Aug. 31, 2012 Predecessor	Aug. 31, 2012 Predecessor
Revenue:
Operating revenues		$ 33,203,000	$ 128,960,000
Natural gas and oil sales	584,000	2,182,000	5,988,000	5,466,000	23,079,000
Total revenues	584,000	35,385,000	134,948,000	5,466,000	23,079,000
Operating expenses:
Cost of revenues		30,656,000	113,561,000
Lease operating expense	332,000	1,000,000	4,175,000	2,223,000	9,038,000
Transportation expense				1,677,000	6,963,000
Production taxes	3,000	15,000	39,000	180,000	979,000
Exploration expense				1,000	2,000
Dry hole costs and impairments				151,346,000	151,347,000
Depreciation, depletion, amortization and accretion	124,000	1,218,000	3,022,000	5,815,000	16,041,000
Trust litigation and settlements		549,000	5,713,000
General and administrative expense	356,000	10,363,000	19,422,000	1,641,000	9,386,000
Total operating expenses	815,000	43,801,000	145,932,000	162,883,000	193,756,000
Loss from unconsolidated affiliates	(1,525,000)	(907,000)	(1,772,000)
Operating loss	(1,756,000)	(9,323,000)	(12,756,000)	(157,417,000)	(170,677,000)
Other income and (expense):
Interest expense and financing costs, net	(246,000)	(3,935,000)	(9,806,000)	(1,990,000)	(6,852,000)
Other income (expense), net		28,000	797,000	526,000	516,000
Realized gain on derivative instruments, net			410,000
Unrealized loss on derivative instruments		(1,390,000)	(6,645,000)
Loss from unconsolidated affiliates				(29,000)	(20,000)
Total other expense, net	(246,000)	(5,297,000)	(15,244,000)	(1,493,000)	(6,356,000)
Loss before income taxes and reorganization items	(2,002,000)	(14,620,000)	(28,000,000)	(158,910,000)	(177,033,000)
Income tax expense			(650,000)
Loss before reorganization items	(2,002,000)	(14,620,000)	(28,650,000)	(158,910,000)	(177,033,000)
Reorganization items
Professional fees and administrative costs				10,719,000	22,354,000
Gain on settlement of liabilities				(168,332,000)	(168,715,000)
Fresh start adjustments				14,765,000	14,765,000
Net loss	$ (2,002,000)	$ (14,620,000)	$ (28,650,000)	$ (16,062,000)	$ (45,437,000)
Basic and diluted loss per common share	$ (0.01)	$ (0.09)	$ (0.18)	$ (0.56)	$ (1.57)

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(4) Acquisition

9 Months Ended

Sep. 30, 2013

Notes

(4) Acquisition

(4) Acquisitions

Texadian Energy, Inc. (formerly known as SEACOR Energy Inc.)

On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for $14.0 million plus estimated net working capital of approximately $4.0 million at closing resulting in approximately $18.0 million of cash paid at closing. Texadian operates an oil transportation, distribution and marketing business with significant logistics capabilities. We acquired Texadian in furtherance of our growth strategy that focuses on the acquisition of income producing businesses. The purchase price for the acquisition was funded with a combination of cash and additional borrowings under the Tranche B Loan (see Note 6).

 The purchase was accounted for as a business combination in accordance with ASC 805 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 is defined in ASC 805 as the future economic benefit of other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is 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		8,290
Net non cash working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	17,439

None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes.

The results of operations of Texadian are included in our consolidated statement of operations beginning January 1, 2013. We have not presented pro forma results for Predecessor periods as the entities are not comparable.

Hawaii Independent Energy, LLC (formerly known as Tesoro Hawaii, LLC)

On June 17 , 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, entered into a membership interest purchase agreement (the “Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the Purchase Agreement, Tesoro Hawaii, LLC (“Tesoro Hawaii”). Pursuant to the 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 purchased the Purchased Units for $75.0 million plus or minus adjustments for net working capital, plus adjustments for inventories at closing and plus certain contingent earnout payments of up to $40.0 million. 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 $165.0 million during such calendar years, with an annual cap of $20.0 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 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, amounts received pursuant to the Supply and Exchange Agreements as described below and the ABL Facility (see Note 6).

Prior to the Execution Date, the Seller had commenced activities to shutdown the Refinery and to convert it into an import terminal. The Purchase Agreement contains certain pre-closing covenants, including covenants related to the startup of operations at the Refinery (the “Refinery Startup Activities”). The expenses associated with the Refinery Startup Activities were approximately $28.0 million (the “Startup Expenses”). Pursuant to the terms of the Purchase Agreement, Hawaii Pacific Energy made an initial deposit of $15.0 million for the Startup Expenses on the Execution Date. The next $5.0 million of Startup Expenses were borne by the Seller, with all Startup Expenses in excess of $20.0 million borne by Hawaii Pacific Energy. Due to the Startup Expenses exceeding $20.0 million, Hawaii Pacific Energy made an additional deposit of $7.0 million for the Startup Expenses on August 5, 2013.  In addition, Hawaii Pacific Energy funded $2.3 million on July 23, 2013 for a major overhaul of a gas turbine engine used in the operations of the refinery's steam cogeneration. These amounts are considered as additional consideration for the Purchased Units.

 Supply and Exchange Agreements

On September 25, 2013 and in connection with the acquisition by Hawaii Pacific Energy of the Purchased Units, HIE entered into the following agreements with Barclays Bank PLC, a public limited company organized under the laws of England and Wales (“Barclays”): (i) a framework agreement (the “Framework Agreement”) to which Hawaii Pacific Energy is also a party; (ii) a 2002 ISDA Master Agreement, including the Schedule thereto, the Oil Annex incorporated therein, the 1994 Credit Support Annex (New York law), the Initial Crude Purchase Confirmation, the Initial Product Purchase Confirmation, the Crude Oil Supply Master Confirmation, the Oil Products Exchange Master Confirmation, the Products Offtake Master Confirmation and the Confirmation of Forward Purchase Agreement for Refined Products (collectively, the “ISDA Agreement”); (iii) a storage and services agreement (the “Storage and Services Agreement”); and (iv) an agency and advisory agreement (the “Advisory Agreement” and, collectively with the Framework Agreement, ISDA Agreement and Storage and Services Agreement, the “Supply and Exchange Agreements”).

Pursuant to the Supply and Exchange Agreements, Barclays purchased the crude oil and refined product inventory owned by HIE on the Effective Date, and following the Effective Date, will (A) provide crude oil supply and intermediation arrangements to meet the processing needs of HIE’s petroleum refinery located at the Campbell Industrial Park in Kapolei, Hawaii (the “Refinery”), (B) provide a refined product exchange mechanism to HIE permitting it to flow volumes of refined product through Barclay’s inventory, and (C) store its crude oil and refined product inventory at the terminals and related facilities owned and operated by HIE.

Set forth below are certain of the additional material terms of the Supply and Exchange Agreements:

Term: The Supply and Exchange Agreements will remain in effect for three years following the Effective Date, subject to HIE’s right to extend the term for two additional one-year terms.

Covenants: The Supply and Exchange Agreements require HIE and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting their respective businesses and operations, including compliance by HIE with a minimum liquidity requirement.

Exclusivity: During the term of the Supply and Exchange Agreements, HIE agrees not to purchase crude oil from any party other than Barclays, except for purchases of an amount and grade of crude oil roughly equivalent to that set forth in a transaction supplement pursuant to the ISDA Agreement that has been rejected by Barclays three consecutive times.

Collateral: All obligations arising under the Supply and Exchange Agreements are secured by a lien in favor of Wells Fargo Bank, N.A., as collateral agent for Barclays (in such capacity, the “Inventory Agent”), on substantially all of HIE’s assets, including, but not limited to, the Refinery and all of its accounts receivable, facilities, real property and improvements, pursuant to an inventory first lien security agreement (the “Inventory Security Agreement”), an inventory second lien security agreement (the “Inventory Second Lien Security Agreement”) and a first lien mortgage (the “Inventory Mortgage”). The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the collateral, are subject to an intercreditor agreement dated as of the Effective Date (the “HIE Intercreditor Agreement”), among Barclays, the Inventory Agent, Deutsche Bank AG New York Branch, acting as collateral agent under the ABL Facility (as defined below) and as administrative agent under the ABL Facility, and Hawaii Pacific Energy and HIE, as grantors. In addition, pursuant to the ISDA Agreement, HIE may be required to provide additional credit support to Barclays in the form of cash, letters of credit and/or negotiable debt obligations of the U.S. Treasury Department.

Guaranty and Pledge by Hawaii Pacific Energy: Hawaii Pacific Energy has granted a security interest in favor of the Inventory Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “Inventory Pledged Collateral”) pursuant to a Membership Interests First Lien Pledge Agreement in favor of the Inventory Agent (the “Inventory Pledge Agreement”). The obligations of HIE under the Supply and Exchange Agreements are guaranteed by Hawaii Pacific Energy, however, the recourse of the Inventory Agent under Hawaii Pacific Energy’s guaranty is limited to the Inventory Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the Inventory Agent, and the priority of the Inventory Agent’s security interest in the Inventory Pledged Collateral, are subject to the HIE Intercreditor Agreement.

The purchase of the purchased units was accounted for as a business combination in accordance with ASC 805 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 is defined in ASC 805 as the future economic benefit of other assets acquired in a business combination that are not individually identified and separately recognized. Goodwill is attributable to opportunities expected to arise from combining our operations with HIE’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 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.

The purchase price allocation is tentative and preliminary. We may have material changes to working capital, goodwill and various other assets and liabilities as better information becomes available in the fourth quarter. A summary of the preliminary estimated fair value of the assets acquired and liabilities assumed is as follows (in thousands):

Property, plant and equipment	$	66,144
Land		39,800
Goodwill		5,203
Intangible assets		4,782
Net working capital		462,427
Contingent consideration liability		(10,500	)
Other noncurrent liabilities		(8,249	)
Total, net of cash acquired	$	559,607

The acquisition was partially funded from net proceeds totaling approximately $384.9 million from the Supply and Exchange Agreements described above. We incurred approximately $1.0 million of expense associated with the acquisition. The results of operations of HIE are included in our consolidated statement of operations beginning September 25, 2013. We have not presented pro forma results for Predecessor periods as those Predecessor periods are not comparable to the current periods.

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(4) Acquisition: Schedule of Recognized Identified Assets Acquired and Liabilities Assumed (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

Intangible assets	$	8,809
Goodwill		8,290
Net non cash working capital		3,097
Deferred tax liabilities		(2,757	)
Total, net of cash acquired	$	17,439

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(9) Stockholders' Equity: Schedule of Share-based Compensation, Activity (Details) (USD $)	9 Months Ended
	Sep. 30, 2013
Details
Non vested balance, beginning of period	2,191,834
Nonvested, Weighted Average Grant Date Fair Value, Beginning Balance	$ 1.09
Granted	3,094,168
Granted, Weighted Average Grant Date Fair Value	$ 1.77
Vested	0
Vested, Weighted Average Grant Date Fair Value	$ 0
Forfeited	0
Forfeited, Weighted Average Grant Date Fair Value	$ 0
Non vested balance, end of period	5,286,002
Nonvested, Weighted Average Grant Date Fair Value, Ending Balance	$ 1.49

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(6) Debt: Schedule of Long-term Debt Instruments (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Total debt, net of unamortized debt discount	$ 67,448
Long term debt, net of current maturities and unamortized discount	67,448
Warrant
Debt Instrument, Unamortized Discount	(4,701)
New Tranche B Term Loan
Loans Payable, Noncurrent	18,760
Senior Secured Delayed Draw Term Loan
Loans Payable, Noncurrent	32,389
ABL Revolving Credit Facility
Loans Payable, Noncurrent	$ 21,000

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(12) Segment Information

9 Months Ended

Sep. 30, 2013

Notes

(12) Segment Information

(12) Segment Information

Following our acquisitions of HIE and Texadian, we have four business segments, (i) natural gas and oil exploration and production, (ii) commodity transportation and marketing (iii) refining and (iv) retail. The retail segment is comprised of 31 retail locations that sell various refined products and merchandise to customers located across Oahu, Maui and Hawaii. Summarized financial information concerning reportable segments consists of the following (in thousands):

For the three months ended September 30, 2013:	Natural Gas and Oil Exploration and Production	Commodity Transportation  and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Sales and operating revenues	$2,182	$4,598	$26,133	$2,472	—	$35.385
Operating income	648	1,952	405	494	(549)	2,950
Loss from unconsolidated affiliate	(907)	—	—	—	—	(907)
Capital expenditures	37	—	—	—	—	37
Capital additions from acquisitions*	—	—	101,103	4,670	—	105,773
Depreciation, depletion, amortization and accretion	519	599	96	—	—	1,214

For the nine months ended September 30, 2013:	Natural Gas  and Oil Exploration and Production	Commodity Transportation and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Sales and operating revenues	$5,988	$100,355	$26,133	$2,472	$—	$134,948
Operating income (loss)	483	13,773	405	494	(5,713)	9,442
Loss from unconsolidated affiliate	(1,773)	—	—	—	—	(1,773)
Capital expenditures	128	—	—	—	—	128
Capital additions from acquisitions*	—	—	101,103	4,670	—	105,773
Depreciation, depletion, amortization and accretion	1,291	1,631	96	—	—	3,018

* Includes only amounts capitalized as property, plant and equipment from the acquisition of HIE.

At September 30, 2013, our reportable segment assets consisted of the following (in thousands):

	Natural Gas  and Oil Exploration and Production	Commodity Transportation  and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Current assets	3,273	$33,847	489,056	6,441	$720	533,337
Property and equipment, net	4,697	47	103,715	2,120	—	110,579
Investments in unconsolidated affiliates	102,923	—	—	—	—	102,923
Goodwill and other intangible assets, net	—	15,593	9,801	—	—	25,394
Other long term assets	9	—	17,132	—	—	17,141
Totals	110,902	$49,487	619,704	8,561	$720	789,374

Reconciliation of reportable segment assets to our consolidated totals is as follows (in thousands):

	September 30,  2013
Total assets for reportable segments	789,374
Cash and restricted cash not allocated to segments	33,064
Property and equipment	4,446
Prepaid expenses and other assets	1,230
Total assets	828,114

For the comparable periods in 2012, 100% of our activities were natural gas and oil exploration and production so no comparable segment information has been provided.

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(3) Investments in Piceance Energy: Summary of Balance Sheet of Equity Investment (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Accounts receivable	$ 93,625	$ 17,730
Total current assets	567,632	59,926
Office furniture and equipment	1,853
Total	116,752	6,219
Less accumulated depreciation, depletion, and amortization	(1,728)	(373)
Total property and equipment, net	115,024	5,846
Total assets	828,114	189,582
Total current liabilities	431,368	69,977
Total liabilities	552,946	88,825
Accumulated deficit	(37,489)	(8,839)
Piceance Energy
Cash and equivalents	23
Accounts receivable	3,486
Prepaids and other assets	1,323
Total current assets	4,832
Natural gas and oil property, successful efforts method of accounting	549,327
Other real estate and land	14,314
Office furniture and equipment	3,110
Total	566,751
Less accumulated depreciation, depletion, and amortization	(107,216)
Total property and equipment, net	459,535
Deferred issue costs and other assets, net	953
Total assets	465,320
Accounts payable and accrued liabilities	5,023
Natural gas and oil sales payable	11,041
Derivative liabilities	542
Total current liabilities	16,606
Note payable	90,000
Asset retirement obligations	2,959
Liabilities, Noncurrent	92,959
Total liabilities	109,565
Members' equity	365,046
Accumulated deficit	(9,291)
Total Members' Equity	355,755
Total liabilities and members' equity	465,320
Piceance Energy | Parent Company
Cash and equivalents	8
Accounts receivable	1,162
Prepaids and other assets	441
Total current assets	1,611
Natural gas and oil property, successful efforts method of accounting	183,146
Other real estate and land	4,772
Office furniture and equipment	1,037
Total	188,955
Less accumulated depreciation, depletion, and amortization	(35,746)
Total property and equipment, net	153,209
Deferred issue costs and other assets, net	318
Total assets	155,138
Accounts payable and accrued liabilities	1,675
Natural gas and oil sales payable	3,681
Derivative liabilities	181
Total current liabilities	5,537
Note payable	30,006
Asset retirement obligations	987
Liabilities, Noncurrent	30,993
Total liabilities	36,530
Members' equity	121,706
Accumulated deficit	(3,098)
Total Members' Equity	118,608
Total liabilities and members' equity	$ 155,138

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(6) Debt: Schedule of Debt Instruments Interest and Financing Costs (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Paid-in-Kind Interest	$ 2,395	$ 5,196
Amortization of Debt Discount (Premium)	493	1,372
Amortization of Financing Costs	35	247
Interest Expense, Debt, Excluding Amortization	79	91
Interest Costs Incurred	3,935	9,806
3% Repayment Premium | Delayed Draw Term Loan Agreement
Accretion Expense	24	72
5% Exit Fee | Tranche B Term Loan
Accretion Expense		1,750
2.5% Exit Fee | New Tranche B Term Loan
Accretion Expense	$ 909	$ 1,078

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(11) Earnings Per Share: Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

	Successor		Successor		Predecessor
	Three Months  Ended September 30, 2013		One Month  Ended September 30, 2012		Two Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

	Successor			Successor			Predecessor
	Nine Months Ended  September 30,  2013			One Month  Ended  September 30,  2012			Eight Months  Ended August 31, 2012
Net loss attributable to common stockholders	$	(28,650	)	$	(2,002	)	$	(45,437	)
Basic weighted-average common stock outstanding		161,633			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		161,633			157,248			28,841
Basic loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)
Diluted loss per common share:	$	(0.18	)	$	(0.01	)	$	(1.57	)

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

	Successor		Successor		Predecessor
	Nine Months  Ended September 30,  2013		One Month  Ended September 30,  2012		Eight Months  Ended August 31,  2012
Stock issuable upon conversion of convertible notes		—		—		379
Stock options		—		—		150
Non-vested restricted stock		5,231		—		558
Total potentially dilutive securities		5,231		—		1,087

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(6) Debt: Repayment of Premium Equal to the Percentage of Principal Repaid (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Repayment of Premium Equal to the Percentage of Principal Repaid

Period	Repayment  Premium
From the Emergence Date through the first anniversary of the Emergence Date		3	%
From the day after the first anniversary of the Emergence Date through the second anniversary of the Emergence Date		2	%

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(5) Inventories: Schedule of Inventory (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Inventory

	Titled Inventory		Supply and Exchange Agreements		Total
Crude oil and feedstocks	$	—	$	128,871	$	128,871
Refined products and blend stock		49,841		199,094		248,935
Warehouse stock and other		17,992		—		17,992
	$	67,833	$	327,965	$	395,798

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(3) Investments in Piceance Energy (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Jun. 04, 2012
Number of hedging units	15,000
Derivative, Floor Price	$ 3.37
Derivative, Average Cap Price	$ 4.28
Derivative, Average Floor Price	$ 3.46
Reorganized Delta Petroleum
Line of Credit Facility, Amount Outstanding		$ 13.0
Piceance Energy
Partners' Capital Account, Contributions	60
Secured revolving credit facility	400.0
Initial borrowing base	140
Line of Credit Facility, Amount Outstanding	90.0	100.0
Equity Value in Excess of Carrying Value	15.7
Piceance Energy | Reorganized Delta Petroleum
Equity Method Investment, Ownership Percentage	33.34%	33.34%
Partners' Capital Account, Distributions	$ 20

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(8) Commitments and Contingencies: Schedule of Future Minimum Payments for Operating Leases (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Future Minimum Payments for Operating Leases

2013	$	12,105
2014		11,312
2015		10,384
2016		9,432
2017		8,712
Thereafter		32,172
Total minimum rental payments	$	84,117

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(1) Reorganization Under Chapter 11 (Details) (USD $)					3 Months Ended	9 Months Ended		9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012	Aug. 31, 2012 Reorganized Delta Petroleum	Jun. 04, 2012 Reorganized Delta Petroleum	Sep. 30, 2013 Piceance Energy	Sep. 30, 2013 Piceance Energy	Jun. 04, 2012 Piceance Energy	Sep. 30, 2013 Piceance Energy Laramie	Jun. 04, 2012 Piceance Energy Laramie	Sep. 30, 2013 Piceance Energy Reorganized Delta Petroleum	Jun. 04, 2012 Piceance Energy Reorganized Delta Petroleum
Equity Method Investment, Ownership Percentage									66.66%	33.34%	33.34%
Line of Credit Facility, Amount Outstanding				$ 13,000,000	$ 90,000,000	$ 90,000,000	$ 100,000,000
Debtor-in-Possession Financing, Amount Arranged									24,900,000		72,600,000
Significant shareholder ownership percentage			5.00%
Number of members in board of directors			5
Common Stock, shares issued	299,053,989	150,080,927	147,700,000
Management Fee Expense, per month					$ 1,950	$ 5,850		$ 650,000

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(3) Investments in Piceance Energy: Summary of Income Statement of Equity Investment (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Net loss		$ (28,650,000)
Piceance Energy
Natural gas, oil and natural gas liquids revenues	14,622	44,076
Natural gas and oil operating expenses	7,416	22,160
Depletion, depreciation and amortization	6,897	17,557
Management fee	1,950	5,850
General and administrative	447	2,420
Total operating expenses	16,710	47,987
Loss from operations	(2,088)	(3,911)
Income from derivatives	106	825
Interest expense and debt issue costs	(718)	(2,139)
Other expense	(20)	(91)
Total other expense, net	(632)	(1,405)
Net loss	(2,720)	(5,316)
Piceance Energy | Parent Company
Natural gas, oil and natural gas liquids revenues	4,875	14,695
Natural gas and oil operating expenses	2,473	7,388
Depletion, depreciation and amortization	2,299	5,854
Management fee	650	1,950
General and administrative	149	807
Total operating expenses	5,571	15,999
Loss from operations	(696)	(1,304)
Income from derivatives	35	275
Interest expense and debt issue costs	(239)	(713)
Other expense	(7)	(30)
Total other expense, net	(211)	(468)
Net loss	$ (907)	$ (1,772)

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(7) Fair Value Measurements: Fair Value, Liabilities Measured on Recurring Basis (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Fair Value, Liabilities Measured on Recurring Basis

Our liabilities measured at fair value on a recurring basis as of September 30, 2013 consist of the following (in thousands):

	September 30, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Derivatives:
Warrants	$	(17,437	)	$	—	$	—	$	(17,437	)
Contingent consideration liability		(10,500	)	$	—		—		(10,500	)
Embedded derivatives		(153)			—		—		(153	)
	$	(28,090	)	$	—	$	—	$	(28,090	)

	Location on Consolidated Balance Sheet	Fair Value at September 30, 2013
		(in thousands)
Warrant derivatives	Noncurrent liabilities	$	(17,437	)
Contingent consideration liability	Noncurrent liabilities	$	(10,500	)
Embedded derivative	Noncurrent liabilities	$	(153	)

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(8) Commitments and Contingencies: Schedule of Future Minimum Payments for Operating Leases (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Details
2013	$ 12,105
2014	11,312
2015	10,384
2016	9,432
2017	8,712
Thereafter	32,172
Total minimum rental payments	$ 84,117

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(12) Segment Information: Schedule of Segment Reporting Information, by Segment (Details) (USD $)			3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended	9 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 Natural Gas and Oil Exploration and Production	Sep. 30, 2013 Natural Gas and Oil Exploration and Production	Sep. 30, 2013 Commodity Transportation and Marketing	Sep. 30, 2013 Commodity Transportation and Marketing	Sep. 30, 2013 Refining		Sep. 30, 2013 Refining		Sep. 30, 2013 Retail		Sep. 30, 2013 Retail		Sep. 30, 2013 Trust Litigation and Settlements	Sep. 30, 2013 Trust Litigation and Settlements	Sep. 30, 2013 Reportable Segments		Sep. 30, 2013 Reportable Segments		Sep. 30, 2013 Reconciliation of Reportable Segment
Total revenues			$ 2,182,000	$ 5,988,000	$ 4,598,000	$ 100,355,000	$ 26,133,000		$ 26,133,000		$ 2,472,000		$ 2,472,000				$ 35,385		$ 134,948,000
Loss from operations			648,000	483,000	1,952,000	13,773,000	405,000		405,000		494,000		494,000		(549,000)	(5,713,000)	2,950,000		9,442,000
Loss from unconsolidated affiliates			(907,000)	(1,773,000)													(907,000)		(1,773,000)
Capital expenditures			37,000	128,000													37,000		128,000
Capital additions from acquisitions*							101,103,000	[1]	101,103,000	[1]	4,670,000	[1]	4,670,000	[1]			105,773,000	[1]	105,773,000	[1]
Depreciation, depletion, amortization and accretion			519,000	1,291,000	599,000	1,631,000	96,000		96,000								1,214,000		3,018,000
Total current assets	567,632,000	59,926,000	3,273,000	3,273,000	33,847,000	33,847,000	489,056,000		489,056,000		6,441,000		6,441,000		720,000	720,000	533,337,000		533,337,000		789,374,000
Property and equipment, net	115,024,000	5,846,000	4,697,000	4,697,000	47,000	47,000	103,715,000		103,715,000		2,120,000		2,120,000				110,579,000		110,579,000		4,446,000
Investment in unconsolidated affiliate	102,923,000	104,434,000	102,923,000	102,923,000													102,923,000		102,923,000
Intangible Assets, Net (Including Goodwill)					15,593,000	15,593,000	9,801,000		9,801,000								25,394,000		25,394,000
Other long-term assets	17,141,000	11,000	9,000	9,000			17,132,000		17,132,000								17,141,000		17,141,000
Total assets	828,114,000	189,582,000	110,902,000	110,902,000	49,487,000	49,487,000	619,704,000		619,704,000		8,561,000		8,561,000		720,000	720,000	789,374,000		789,374,000		828,114,000
Restricted Cash and Cash Equivalents																					33,064,000
Prepaid Expense																					$ 1,230,000

[1] * Includes only amounts capitalized as property, plant and equipment from the acquisition of HIE.

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(8) Commitments and Contingencies: Schedule Of Reorganization Distributions To Satisfy Allowed Claims (Details) (USD $)	0 Months Ended	4 Months Ended	9 Months Ended
	Aug. 31, 2012	Dec. 31, 2012	Sep. 30, 2013
Bankruptcy Claims, Amount of Claims Filed			$ 6,400,000
U.S. Government Claims
Filing Claims Count	106	81	34
Bankruptcy Claims, Amount of Claims Filed	73,729,373	67,129,261	49,614,488
Bankruptcy Claims, Number of Claims Settled		0	47
Bankruptcy Claims, Amount of Claims Settled		0	0
Bankruptcy Claims, Amount Paid to Settle Claims		0	0
Stock issued to settle bankruptcy claims		0	0
Former Employee Claims
Filing Claims Count	32	19	0
Bankruptcy Claims, Amount of Claims Filed	16,379,849	12,694,596	0
Bankruptcy Claims, Number of Claims Settled		0	19
Bankruptcy Claims, Amount of Claims Settled		0	0
Bankruptcy Claims, Amount Paid to Settle Claims		0	0
Stock issued to settle bankruptcy claims		0	0
Macquarie Capital (USA) Inc.
Filing Claims Count	1	1	1
Bankruptcy Claims, Amount of Claims Filed	8,671,865	8,671,865	8,671,865
Bankruptcy Claims, Number of Claims Settled		0	0
Bankruptcy Claims, Amount of Claims Settled		0	0
Bankruptcy Claims, Amount Paid to Settle Claims		0	0
Stock issued to settle bankruptcy claims		0	0
Swann and Buzzard Creek Royalty Trust
Filing Claims Count	1	1	0
Bankruptcy Claims, Amount of Claims Filed	3,200,000	3,200,000	0
Bankruptcy Claims, Number of Claims Settled		0	1
Bankruptcy Claims, Amount of Claims Settled		0	0
Bankruptcy Claims, Amount Paid to Settle Claims		0	0
Stock issued to settle bankruptcy claims		0	0
Other Various Claims
Filing Claims Count	69	57	31
Bankruptcy Claims, Amount of Claims Filed	23,113,659	20,198,800	18,578,623
Bankruptcy Claims, Number of Claims Settled		0	26
Bankruptcy Claims, Amount of Claims Settled		0	0
Bankruptcy Claims, Amount Paid to Settle Claims		$ 0	$ 0
Stock issued to settle bankruptcy claims		0	0

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(2) Summary of Significant Accounting Policies: Property and Equipment (Details)	9 Months Ended
	Sep. 30, 2013
Property, Plant and Equipment, Depreciation Methods	straight-line method
Refining Assets | Minimum
Property, Plant and Equipment, Useful Life	8 years
Refining Assets | Maximum
Property, Plant and Equipment, Useful Life	47 years
Logistics Assets | Minimum
Property, Plant and Equipment, Useful Life	3 years
Logistics Assets | Maximum
Property, Plant and Equipment, Useful Life	30 years
Retail Assets | Minimum
Property, Plant and Equipment, Useful Life	14 years
Retail Assets | Maximum
Property, Plant and Equipment, Useful Life	18 years
Corporate Assets | Minimum
Property, Plant and Equipment, Useful Life	3 years
Corporate Assets | Maximum
Property, Plant and Equipment, Useful Life	7 years
Software and Software Development Costs
Property, Plant and Equipment, Useful Life	3 years

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(11) Earnings Per Share (Details)	Sep. 30, 2013
Details
Class of Warrant or Right, Outstanding	9,737,182

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(4) Acquisition: Schedule of Purchase Price Allocation, Preliminary Estimated Fair Value of the Assets Acquired and Liabilities Assumed (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Purchase Price Allocation, Preliminary Estimated Fair Value of the Assets Acquired and Liabilities Assumed

Property, plant and equipment	$	66,144
Land		39,800
Goodwill		5,203
Intangible assets		4,782
Net working capital		462,427
Contingent consideration liability		(10,500	)
Other noncurrent liabilities		(8,249	)
Total, net of cash acquired	$	559,607

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CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	1 Months Ended	9 Months Ended	8 Months Ended
	Sep. 30, 2012 Successor	Sep. 30, 2013 Successor	Aug. 31, 2012 Predecessor
Cash flows from operating activities:
Net loss	$ (2,002,000)	$ (28,650,000)	$ (45,437,000)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation, depletion, amortization and accretion	124,000	3,022,000	16,041,000
Interest, prepayments premiums and exit penalty capitalized into note balance		8,036,000	2,989,000
Amortization of deferred financing costs and bond discount	132,000	1,619,000
Change in asset values due to fresh start accounting adjustments			14,765,000
Gain on extinguishment of senior debt			(166,144,000)
Gain on settlement of liabilities			(2,188,000)
Gain on sale of assets held for sale		(50,000)
Loss on disposal of other assets		33,000	126,000
Dry hole costs and impairment			151,347,000
Stock-based compensation		491,000	1,895,000
Unrealized loss on derivative contracts		6,645,000
Loss from unconsolidated affiliates	1,525,000	1,772,000	20,000
Other			(699,000)
Net changes in operating assets and liabilities:
Trade accounts receivable	(581,000)	(16,161,000)	3,472,000
Deposits and prepaid assets	(190,000)	54,000	(1,378,000)
Inventories		34,778,000
Supply and exchange agreement		(51,349,000)
Other assets		2,000
Accounts payable and other current accrued liabilities	645,000	43,230,000	(4,187,000)
Other accrued liabilities		1,034,000
Settlement claim liability		4,526,000
Accrued reorganization costs			9,116,000
Net cash provided by (used in) operating activities	(347,000)	9,032,000	(20,262,000)
Cash flows from investing activities:
Purchase of HIE, net of cash acquired		(559,607,000)
Additions to property and equipment		(4,627,000)	(1,613,000)
Cash restricted for letter of credit		(1,030,000)
Capitalized drilling costs owed to operator		(261,000)
Proceeds from sale of oil and gas properties			74,209,000
Proceeds from sale of other fixed assets			26,000
Proceeds from sale of assets held for sale		2,850,000
Net cash used in investing activities		(562,675,000)	72,622,000
Cash flows from financing activities:
Funding of purchase of HIE from supply and exchange agreements		384,948,000
Proceeds from sale of common stock, net of offering cost		199,170,000
Proceeds from borrowings		67,655,000	23,000,000
Repayments of borrowing		(52,007,000)	(59,535,000)
Payment of deferred loan costs		(2,264,000)
Fund distribution agent account			(21,805,000)
Release of restricted cash held to secure letters of credit		19,000,000
Proceeds from (funding of) Wapiti and General Recovery Trust	2,000,000		(2,000,000)
Net cash provided by (used in) financing activities	2,000,000	616,502,000	(60,340,000)
Net increase (decrease) in cash and cash equivalents	1,653,000	62,859,000	(7,980,000)
Cash at beginning of period	4,882,000	6,185,000	12,862,000
Cash at end of period	6,535,000	69,044,000	4,882,000
Non cash investing and financing activities and supplemental disclosure of cash paid:
Stock issued to settle bankruptcy claims		2,468,000
Stock issued in exchange of liability		932,000
Cash paid for interest and financing costs		93,000	3,745,000
Restricted cash used to settle bankruptcy claims		4,250,000
Interest capitalized into note balances	114,000	7,839,000
Net settlement of supply and exchange agreements		$ 21,639,000

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(2) Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2013

Notes

(2) Summary of Significant Accounting Policies

(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. At September 30, 2013, the majority of our natural gas and oil activities were conducted through partnerships and joint ventures. We will include our proportionate share of assets, liabilities, revenues and expenses from these entities in our consolidated financial statements. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.

Our wholly owned primary subsidiaries include Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3), Texadian Energy, Inc. (formerly known as SEACOR Energy Inc. (“Texadian”)), which we acquired on December 31, 2012 (see Note 4) and Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”)  which acquired all of the outstanding membership interests of Hawaii Independent Energy, LLC (formerly known as Tesoro Hawaii, LLC (“HIE”)), on September 25, 2013 (see Note 4).

The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to Form 10-Q. Some information and footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”), have been condensed or omitted pursuant to the Securities and Exchange Commission’s (“SEC”) rules and regulations. In our opinion, all adjustments, consisting only of normal recurring accruals, considered necessary to state fairly the information in our unaudited condensed consolidated financial statements have been included. Operating results for interim periods are not necessarily indicative of the results that may be expected for the complete fiscal year. As a result, these unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto previously filed with our Annual Report on Form 10-K for the year ended December 31, 2012.

Fresh Start Accounting and the Effects of the Plan

As required by U.S. GAAP, effective as of August 31, 2012, Par adopted fresh start accounting following the guidance of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 852 “Reorganizations” (“ASC 852”). Fresh start accounting 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 “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 two and eight months ended August 31, 2012 have been omitted. Fresh start accounting 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 accounting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities.

Cash Equivalents

We consider all highly liquid investments with maturities at date of acquisition of three months or less to be cash equivalents.

Restricted Cash

As of September 30, 2013, restricted cash totaled approximately $1.7 million and consisted of approximately $720,000 designated to settle bankruptcy matters that is not available for operating activities (see Note 8) and approximately $1.0 million held at a commercial bank to support a letter of credit facility related to our acquisition of HIE. At December 31, 2012, restricted cash totaled approximately $24 million, including amounts held at a commercial bank to support a letter of credit facility totaling approximately $19.0 million (see Note 6) and approximately $4.8 million designated to settle bankruptcy matters. During the nine months ended September 30, 2013, the $19.0 million of restricted cash supporting a letter of credit facility was released to us and was made available for general corporate purposes.

Trade Receivables

Texadian’s customers primarily included major independent refining and marketing companies. HIE’s receivables include receivables from the sale of refined products and proprietary credit card receivables from sales at its retail locations. Customers are required to pay in advance or are granted credit on a short-term basis when credit risks are considered acceptable. We routinely review our trade receivables and make provisions for doubtful accounts based on existing customer and economic conditions; however, those provisions are estimates and actual results could differ from those estimates and those differences may be material. Trade receivables that are deemed uncollectible are removed from accounts receivable and from the allowance for doubtful accounts when collection efforts have been unsuccessful. As of September 30, 2013, we had no significant allowance for doubtful accounts. Several of Texadian’s physical purchases and sales are with the same counterparty and are settled on a net basis and therefore Texadian’s receivables are recorded net of any corresponding payables. 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.

Refined Product Exchanges

As further described in Note 4, HIE has entered into supply and exchange contracts whereby it agrees 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 that are settled in kind on a volumetric basis, 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

Texadian’s inventories, which consist of in-transit oil, are stated at the lower of cost or market. We record impairments, as needed, to adjust the carrying amount of inventories to the lower of cost or market.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 4. Legal title to the crude oil is held by Barclays and the crude oil is stored in HIE’s storage tanks for the benefit of Barclays pursuant to a storage agreement until it is needed for further use in the refining process. At that time, certain nominated volumes are drawn out of the storage tanks and purchased by us. After processing and subject to the supply and exchange agreements described in Note 4, Barclays takes title to the refined products when the refined products enters the tanks which are then stored in HIE’s storage tanks until sold at 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. Inventories are stated at the lower of cost or market. We use last-in, first-out as the primary method to determine the cost of crude oil and refined product inventories in our refining and retail segments. We value merchandise along with spare parts, materials and supplies at average cost.

 Investment in Unconsolidated Affiliate

Investments in operating entities where we have the ability to exert significant influence, but do not control the operating and financial policies, are accounted for using the equity method. Our share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations.

Our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3).

Assets Held for Sale

As of December 31, 2012, we classified our 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 $50,000.

Property and Equipment

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 amortized 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 amortized as the related reserves are produced.

HIE’s operations, especially those of the refining segment, are highly capital intensive. The refinery consists of a series of interconnected, highly integrated and interdependent crude oil processing facilities and supporting logistical infrastructure, and these units are regularly improved. We plan for these improvements by developing a multi-year capital program that is updated and revised based on changing internal and external factors.

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. The useful lives range from 8 to 47 years for refining assets, 3 to 30 years for logistics assets, 14 to 18 years for retail assets, 3 to 7 years for corporate assets and 3 for software. 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.

Goodwill and Other Intangible Assets

We recorded goodwill as a result of our acquisitions of Texadian and have preliminarily recognized goodwill with the acquisition of HIE. Goodwill was attributable to opportunities expected to arise from combining our operations with Texadian’s and HIE’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, as a result of our acquisitions of Texadian and HIE, we recorded certain other identifiable intangible assets. These 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.

Impairment of Goodwill and Long-Lived Assets

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. Qualitative factors assessed for the reporting unit would include the competitive environments and financial performance of the reporting unit. 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, based upon a multiple of estimated earnings. 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. The fair value calculation uses Level 3 (see Note 7) inputs and includes multiple assumptions and estimates, including the projected cash flows and discount rates applied. Changes in these assumptions and estimates could result in a goodwill impairment that could materially adversely impact our financial position or results of operations.

 We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist under authoritative guidance. 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 fair value. These impairment tests are heavily influenced by assumptions and estimates that are subject to change as additional information becomes available.

Our natural gas and oil assets, including our investment in our unconsolidated affiliate, are reviewed for impairment quarterly or when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Estimates of expected future cash flows represent our best estimate based on reasonable and supportable assumptions and projections.

For proved properties, if the expected future cash flows exceed the carrying value of the asset, no impairment is recognized. If the carrying value of the asset exceeds the expected future cash flows, an impairment exists and is measured by the excess of the carrying value over the estimated fair value of the asset. Any impairment provisions recognized are permanent and may not be restored in the future.

We assess proved properties on an individual field basis for impairment each quarter when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For proved properties, the review consists of a comparison of the carrying value of the asset with the asset’s expected future undiscounted cash flows without interest costs.

For unproved properties, the need for an impairment charge is based on our plans for future development and other activities impacting the life of the property and our ability to recover our investment. When we believe the costs of the unproved property are no longer recoverable, an impairment charge is recorded based on the estimated fair value of the property.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the net book values 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’ net book value. If this occurs, an impairment loss is recognized for the difference between the fair value and net book 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.

Asset Retirement Obligations

An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. Our AROs arise from plugging and abandonment liabilities for our natural gas and oil wells, as well as AROs arising from HIE’s refinery and retail operations. We record 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. 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. 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 associated with HIE 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 primarily in operating expenses in our statements of consolidated operations.

Derivatives and Other Financial Instruments

We may 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.

Texadian 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.  Texadian’s policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and it will not net settle.  Should Texadian not designate a contract as a normal purchase or normal sale or should a scheduled delivery under the terms of contract not occur, then these exceptions may require the recording of the contract as a derivative.  If derivative accounting treatment is required then these contracts would be recorded at fair value as either an asset or a liability and marked to market each reporting period with changes in fair value being charged to earnings. As of September 30, 2013, we have elected the normal purchase normal sale exemption for these contracts. As such, 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 Texadian’s open contracts that 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 6) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our delayed draw term loan facility contains certain puts that are 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.

The carrying value of trade accounts receivable and accounts payable approximates fair value due to their short term nature. Our

long-term debt is recorded on the amortized cost basis. We estimate our long term debt’s fair value to be approximately $61.3 million at September 30, 2013 using a discounted cash flow analysis and an estimate of the current yield 5.7% by reference to market interest rates for term debt of comparable companies which is considered to be a Level 3 fair value measurement (see Note 7).

Accrued Settlement Claims

As of September 30, 2013, we have accrued approximately $6.4 million relating to claims resulting from our bankruptcy (see Note 8). 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 in the financial statements 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 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 HIE’s and Texadian’s operations.  They operate in states where we have no net operating loss carryovers available to offset taxable income generated within those states.  Accordingly, we have accrued state income tax expense of approximately $0 and $650,000 for the three and nine months ended September 30, 2013, respectively.

Stock Based Compensation

We recognize the cost of share based payments over the period the employee provides service, generally the vesting period, and includes such costs in general and administrative expense in the 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

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 September 30, 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Marketing and Transportation

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.

Texadian earns 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 and Retail

HIE recognizes 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

Other Income

For the nine months ended September 30, 2013, other income totaled approximately $797,000 and consists primarily of a state tax refund totaling approximately $483,000 and a legal settlement of approximately $200,000.

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 foreign currency gains or losses, net in the accompanying consolidated statements of operations in the period in which the currency exchange rates change.

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 under fresh start accounting, fair value of assets and liabilities recorded under purchase accounting, natural gas and oil reserves, bad debts, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

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(5) Inventories

9 Months Ended

Sep. 30, 2013

Notes

(5) Inventories

(5) Inventories

Inventories at September 30, 2013 consist of the following:

	Titled Inventory		Supply and Exchange Agreements		Total
Crude oil and feedstocks	$	—	$	128,871	$	128,871
Refined products and blend stock		49,841		199,094		248,935
Warehouse stock and other		17,992		—		17,992
	$	67,833	$	327,965	$	395,798

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(13) Related Party Transactions (Details) (USD $)	9 Months Ended
	Sep. 30, 2013
Details
Professional and Contract Services Expense	$ 50,000
Consulting Agreement Service, Description	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.

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(3) Investments in Piceance Energy

9 Months Ended

Sep. 30, 2013

Notes

(3) Investments in Piceance Energy

(3) Investments 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, and as a result, we do not meet the accounting

criteria which require us to consolidate the joint venture. The 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 $140 million.  As of September 30, 2013, the balance outstanding on the revolving credit facility was approximately $90.0 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.

Piceance Energy holds various commodity hedging instruments to mitigate a portion of the effect of natural gas and oil price fluctuations. The contracts are in the form of costless collars of 15,000 MMBtu/day with floors of an average of $3.37 and ceilings of an average of $4.28 with 5,000 MMBtu/day through March 2014 and 10,000 MMBtu/day  through September 2014, and as well as swaps of 10,000 MMBtu/day for an average price of $3.46 through September 2014. Piceance Energy also holds natural gas gathering and processing contracts for a fixed rate expiring on various dates beginning in 2017 through 2032. Some of our contracts require a minimum throughput commitment.

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

	Three Months Ended September 30,  2013			Nine Months Ended September 30,  2013
	(in thousands)
Beginning balance	$	103,815			$	104,434
Income (loss) from unconsolidated affiliates		(907	)			(1,772	)
Capitalized drilling costs obligation paid		15				261
Ending balance	$	102,923			$	102,923

Summarized balance sheet information and our share of the equity investment are as follows:

	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Assets
Cash and equivalents	$	23		$	8
Accounts receivable		3,486			1,162
Prepaids and other assets		1,323			441
Total current assets		4,832			1,611
Natural gas and oil property, successful efforts method of accounting		549,327			183,146
Other real estate and land		14,314			4,772
Office furniture and equipment		3,110			1,037
Total		566,751			188,955
Less: accumulated depletion, depreciation and amortization		(107,216	)		(35,746	)
Total property and equipment, net		459,535			153,209
Deferred issue costs and other assets, net		953			318
Total assets	$	465,320		$	155,138

	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Accounts payable and accrued liabilities	$	5,023		$	1,675
Natural gas and oil sales payable		11,041			3,681
Derivative liabilities		542			181
Total current liabilities		16,606			5,537
Note payable		90,000			30,006
Asset retirement obligations		2,959			987
Total non-current liabilities		92,959			30,993
Total liabilities		109,565			36,530
Members equity
Members’ equity		365,046			121,706
Accumulated deficit		(9,291	)		(3,098	)
Total members’ equity		355,755			118,608
Total liabilities and members’ equity	$	465,320		$	155,138

At September 30, 2013, our members’ equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment recorded on our consolidated balance sheet by approximately $15.7 million. We attribute this difference, which is expected to be permanent, to lack of control and marketability discounts.

Summarized income statement information and our share for the period for which our investment was accounted for under the equity method is as follows:

	Three Months Ended September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	14,622		$	4,875
Natural gas and oil operating expenses		7,416			2,473
Depletion, depreciation and amortization		6,897			2,299
Management fee		1,950			650
General and administrative		447			149
Total operating expenses		16,710			5,571
Loss from operations		(2,088	)		(696	)
Other income (expense)
Income from derivatives		106			35
Interest expense and debt issue costs		(718	)		(239	)
Other expense		(20	)		(7	)
Total other expense, net		(632	)		(211	)
Net loss	$	(2,720	)	$	(907	)

	Nine Months Ended  September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	44,076		$	14,695
Natural gas and oil operating expenses		22,160			7,388
Depletion, depreciation and amortization		17,557			5,854
Management fee		5,850			1,950
General and administrative		2,420			807
Total operating expenses		47,987			15,999
Loss from operations		(3,911	)		(1,304	)
Other income (expense)
Income from derivatives		825			275
Interest expense and debt issue costs		(2,139	)		(713	)
Other expense		(91	)		(30	)
Total other expense, net		(1,405	)		(468	)
Net loss	$	(5,316	)	$	(1,772	)

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(2) Summary of Significant Accounting Policies: Restricted Cash (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Restricted cash	$ 1,750,000	$ 23,970,000
Letter of Credit
Restricted cash	1,000,000	19,000,000
Bankruptcy Settlement Interests
Restricted cash	$ 720,000	$ 4,800,000

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(6) Debt: Schedule of Long-term Debt Instruments (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Long-term Debt Instruments

Delayed Draw Term Loan Agreement, including interest in-kind	$	32,389
New Tranche B Loan, including interest in-kind		18,760
ABL Facility		21,000
Less: unamortized debt discount – warrants and embedded derivative		(4,701	)
Total debt, net of unamortized debt discount		67,448
Less: current maturities		—
Long term debt, net of current maturities and unamortized discount	$	67,448

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(7) Fair Value Measurements: Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

A rollforward of Level 3 derivative warrants and the embedded derivative measured at fair value using Level 3 on a reoccurring basis for the nine months ended September 30, 2013 is as follows (in thousands):

Description
Balance, at December 31, 2012	$	(10,945	)
Purchases, issuances, and settlements		(10,500	)
Total unrealized losses included in earnings		(6,645	)
Transfers		—
Balance, at September 30, 2013	$	(28,090	)

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

	For the three months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(1,390	)
Embedded derivatives	Other income (expense)		285
Commodities - exchange traded futures	Other income (expense)		—
Commodities - physical forward contracts	Other income (expense)		—

	For the nine months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(6,645	)
Embedded derivatives	Other income (expense)		45
Commodities - exchange traded futures	Other income (expense)		104
Commodities - physical forward contracts	Other income (expense)		306

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(11) Earnings Per Share: Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	1 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	2 Months Ended	8 Months Ended	2 Months Ended	8 Months Ended	2 Months Ended	8 Months Ended	2 Months Ended	8 Months Ended
	Sep. 30, 2012 Successor	Sep. 30, 2013 Successor	Sep. 30, 2013 Successor	Sep. 30, 2013 Successor Non-Vested Restricted Stock	Sep. 30, 2013 Successor Non-Vested Restricted Stock	Aug. 31, 2012 Predecessor	Aug. 31, 2012 Predecessor	Aug. 31, 2012 Predecessor Stock Issuable upon Conversion of Convertible Notes	Aug. 31, 2012 Predecessor Stock Issuable upon Conversion of Convertible Notes	Aug. 31, 2012 Predecessor Equity Option	Aug. 31, 2012 Predecessor Equity Option	Aug. 31, 2012 Predecessor Non-Vested Restricted Stock	Aug. 31, 2012 Predecessor Non-Vested Restricted Stock
Total potentially dilutive securities		5,231	5,231	5,231	5,231	1,087	1,087	379	379	150	150	558	558
Net loss attributable to common stockholders	$ (2,002)	$ (14,620)	$ (28,650)			$ (16,062)	$ (45,437)
Basic weighted-average common stock outstanding	157,248	167,523	161,633			28,841	28,841
Diluted weighted-average common stock outstanding	157,248	167,523	161,633			28,841	28,841
Basic loss per common share:	$ (0.01)	$ (0.09)	$ (0.18)			$ (0.56)	$ (1.57)
Diluted loss per common share:	$ (0.01)	$ (0.09)	$ (0.18)			$ (0.56)	$ (1.57)

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(11) Earnings Per Share: Schedule of Earnings Per Share, Basic and Diluted (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Earnings Per Share, Basic and Diluted

	Successor			Successor			Predecessor
	Three Months Ended September 30,  2013			One Month  Ended September 30,  2012			Two Months Ended August 31,  2012
Net loss attributable to common stockholders	$	(14,620	)	$	(2,002	)	$	(16,062	)
Basic weighted-average common stock outstanding		167,523			157,248			28,841
Add: dilutive effects of common stock equivalents		—			—			—
Diluted weighted-average common stock outstanding		167,523			157,248			28,841
Basic loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)
Diluted loss per common share:	$	(0.09	)	$	(0.01	)	$	(0.56	)

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(11) Earnings Per Share: Schedule of Earnings Per Share, Basic and Diluted (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	1 Months Ended	3 Months Ended	9 Months Ended	2 Months Ended	8 Months Ended
	Sep. 30, 2012 Successor	Sep. 30, 2013 Successor	Sep. 30, 2013 Successor	Aug. 31, 2012 Predecessor	Aug. 31, 2012 Predecessor
Net loss attributable to common stockholders	$ (2,002)	$ (14,620)	$ (28,650)	$ (16,062)	$ (45,437)
Basic weighted-average common stock outstanding	157,248	167,523	161,633	28,841	28,841
Diluted weighted-average common stock outstanding	157,248	167,523	161,633	28,841	28,841
Basic loss per common share:	$ (0.01)	$ (0.09)	$ (0.18)	$ (0.56)	$ (1.57)
Diluted loss per common share:	$ (0.01)	$ (0.09)	$ (0.18)	$ (0.56)	$ (1.57)

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(6) Debt: Repayment of Premium Equal to the Percentage of Principal Repaid (Details)	9 Months Ended
	Sep. 30, 2013
First Anniversary
Percentage Of Repayment Premium	3.00%
Second Anniversary
Percentage Of Repayment Premium	2.00%

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(4) Acquisition (Details) (USD $)	9 Months Ended		12 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 Membership Interest Purchase Agreement	Dec. 31, 2012 Texadian Energy Inc
Payments to Acquire Businesses, Gross		$ 75,000,000	$ 14,000,000
Business acquisition purchase price allocation working capital			4,000,000
Business Combination, Separately Recognized Transactions, Additional Disclosures, Acquisition Costs			18,000,000
Purchase of HIE, net of cash acquired		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 $165.0 million during such calendar years, with an annual cap of $20.0 million
Total operating expenses		28,000,000
Deposit Assets		15,000,000
Significant Acquisitions and Disposals, Description		The next $5.0 million of Startup Expenses were borne by the Seller, with all Startup Expenses in excess of $20.0 million borne by Hawaii Pacific Energy. Due to the Startup Expenses exceeding $20.0 million, Hawaii Pacific Energy made an additional deposit of $7.0 million for the Startup Expenses on August 5, 2013. In addition, Hawaii Pacific Energy funded $2.3 million on July 23, 2013 for a major overhaul of a gas turbine engine used in the operations of the refinery's steam cogeneration.
Funding of purchase of HIE from supply and exchange agreements	384,900,000
Acquisition Related Expense	$ 1,000,000

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(2) Summary of Significant Accounting Policies: Income Taxes (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Details
Deferred State and Local Income Tax Expense (Benefit)	$ 0	$ 650,000

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CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position
Preferred Stock, par or stated value	$ 0.01	$ 0.01
Preferred Stock, shares authorized	3,000,000	3,000,000
Preferred Stock, shares issued	0	0
Common Stock, par or stated value	$ 0.01	$ 0.01
Common Stock, shares authorized	500,000,000	300,000,000
Common Stock, shares issued	299,053,989	150,080,927
Allowance for doubtful accounts	$ 0	$ 0

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(8) Commitments and Contingencies

9 Months Ended

Sep. 30, 2013

Notes

(8) Commitments and Contingencies

(8) Commitments and Contingencies

Environmental Matters

Like other petroleum refiners, 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.

Hawaii Consent Decree On September 25, 2013, Hawaii Pacific Energy, Tesoro and HIE entered into an Environmental Agreement (the “Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities relating to the acquisition of HIE, including the Consent Decree as described below.

Tesoro is currently negotiating a consent decree with the United States Environmental Protection Agency (“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 by Tesoro and its affiliates (the “Consent Decree”), including the Refinery.  It is anticipated that the Consent Decree will be finalized sometime during the first quarter of 2014 and will require certain capital improvements to the 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 of the Purchase Agreement (the “Closing Date”). Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, this obligation terminates on the third anniversary of the Closing Date.

Regulation of Greenhouse Gases The EPA began regulating greenhouse gases in January 2011 under the Clean Air Act Amendment of 1990 (the “Clean Air Act”).  Any new construction or material expansions will require that, among other things, a greenhouse gas permit be issued at either or both the state or federal level in accordance with the Clean Air Act regulations, and we will be required to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce greenhouse gas emissions.  The determination would be on a case by case basis, and the EPA has provided only general guidance on which controls will be required or delegated to the states through State Implementation Plans.

Furthermore, the 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 but have not yet been delineated.  Any such controls, however, 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 34, which required that greenhouse gas emissions be rolled back on a state wide basis to 1990 levels by the year 2020. Although delayed by two years, the Hawaii Department of Health (“DOH”) is on schedule to finalize and issue regulations by the end of 2013 that would require each major facility to reduce CO2 emission by 16% by 2020 relative to calendar year 2010 baseline (the first year in which greenhouse gas was reported to the EPA under 40 CFR Part 98). 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 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 16.55 billion gallons of renewable fuel usage in 2013, increasing 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 productions and logistic challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase credits from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.

In October 2010, the EPA issued a partial waiver decision under the 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 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 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 May 2013, the EPA published a proposed Tier 3 gasoline standard that would lower the allowable sulfur level in gasoline to 10 ppm, lower the standards for Reid vapor pressure, and also lower the allowable benzene, aromatics and olefins content of gasoline, while possibly increasing octane requirements. The proposed 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 have already filed extensive comments and intend to challenge the proposed 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.

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, 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 $1.0 million each pursuant to the Plan.

On September 19, 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. Further distributions are not anticipated from the Wapiti Trust and the Wapiti Trust is anticipated to be 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 former Chief Executive Officer is the 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 for each of the Recovery Trusts, subject to the terms of the respective trust agreements 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 September 30, 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, 106 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 202,753 shares of common stock.  Pursuant to the Plan, during the nine months ended September 30, 2013, the Recovery Trustee settled an additional 47 claims with an aggregate face amount of $17.5 million for approximately $2.7 million in cash and 2,013,773 shares of common stock.

As of September 30, 2013, it is estimated that a total of 34 claims totaling approximately $49.6 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. In addition, litigation and/or settlement efforts are ongoing with other claim holders.

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 544 shares per $1,000 of claim. At September 30, 2013, we have reserved approximately $6.4 million 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:

	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	$	22,364,000		—	$	—	$	—		—		3	$	22,364,000
Former Employee Claims		32		16,379,849		13		3,685,253		229,478		202,231		19		12,694,596
Macquarie Capital (USA) Inc.		1		8,671,865		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		—		—		—		—		1		3,200,000
Other Various Claims*		69		23,113,659		12		2,914,859		29,427		522		57		20,198,800
Total		106	$	73,729,373		25	$	6,600,112	$	258,905		202,753		81	$	67,129,261

	For the Nine Months Ended September 30, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364,000
Former Employee Claims		19		12,694,596		339,588		1,614,988		—		—
Macquarie Capital (USA) Inc.		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		2,000,000		—		—		—
Other Various Claims*		26		1,620,177		397,754		398,785		31		18,578,623
Total		47	$	17,514,773	$	2,737,342		2,013,773		34	$	49,614,488

*          Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Subsequent to September 30, 2013, the Recovery Trustee settled the Macquarie Capital (USA) Inc. claim for $2.5 million in cash. In addition, two claims with an aggregate face amount of approximately $678,000 were settled for $145,000 in cash and 46,935 shares of common stock.

HIE

Operating Leases

HIE has 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. In general, these leases have remaining primary terms of up to 32 years and typically contain multiple renewal options.

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. HIE has 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.

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

2013	$	12,105
2014		11,312
2015		10,384
2016		9,432
2017		8,712
Thereafter		32,172
Total minimum rental payments	$	84,117

Capital Leases

HIE’s capital lease obligations relate 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		968
Total minimum rental payments	$	1,782

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 purchase commitment during the initial term is approximately $28.0 million.

As of September 30, 2013, Texadian had various agreements to lease 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. Leases generally range in duration of five years or less and contain lease renewal options at fair value.

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CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY (Unaudited) (USD $)	Total	Common stock	Additional paid-in capital	Accumulated deficit
Stockholders' Equity at Dec. 31, 2012	$ 100,757,000	$ 1,501,000	$ 108,095,000	$ (8,839,000)
Shares, Outstanding at Dec. 31, 2012		150,081,000
Stock issued in a private transaction, net of offering cost, value	199,170,000	1,439,000	197,731,000
Stock issued in a private transaction, net of offering cost, shares		143,885,000
Stock issued to settle bankruptcy claims, value	2,468,000	20,000	2,448,000
Stock issued to settle bankruptcy claims, shares		2,014,000
Stock issued in exchange for liability, value	932,000	6,000	926,000
Stock issued in exchange for liability, shares		565,000
Stock based compensation, value	491,000	25,000	466,000
Stock based compensation, shares		2,509,000
Net loss	(28,650,000)			(28,650,000)
Stockholders' Equity at Sep. 30, 2013	$ 275,168,000	$ 2,991,000	$ 309,666,000	$ (37,489,000)
Shares, Outstanding at Sep. 30, 2013		299,054,000

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(7) Fair Value Measurements: Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013 Net working capital	Sep. 30, 2013 Property, plant and equipment	Sep. 30, 2013 Land	Sep. 30, 2013 Trade names and trade marks	Sep. 30, 2013 Goodwill	Sep. 30, 2013 Contingent consideration liability	Sep. 30, 2013 Other Noncurrent Liabilities	Sep. 25, 2013 Purchase Price Allocation of HIE	Sep. 25, 2013 Purchase Price Allocation of HIE Property, Plant and Equipment, Other Types	Sep. 25, 2013 Purchase Price Allocation of HIE Land
Net working capital								$ 462,427
Property, Plant, and Equipment, Fair Value Disclosure									66,144	39,800
Trade names and trade marks								4,782
Goodwill								5,203
Contingent consideration liability								(10,500)
Other noncurrent liabilities								(8,249)
Fair Value, Net Asset (Liability)								$ 559,607
Fair Value Measurements, Valuation Techniques	Current assets acquired and liabilities assumed were recorded at their estimated fair value.	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.	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.	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.	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.	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.	Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.

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CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current assets:
Cash and cash equivalents	$ 69,044	$ 6,185
Restricted cash	1,750	23,970
Trade accounts receivable, net of allowance for doubtful accounts of $0 at September 30, 2013 and December 31, 2012	93,625	17,730
Inventories	395,798	10,466
Prepaid and other current assets	7,415	1,575
Total current assets	567,632	59,926
Property and equipment:
Land	39,800
Property, plant and equipment	66,144
Furniture and fixtures	1,853
Software	2,646
Other	1,400	1,415
Natural gas and oil properties, at cost, successful efforts method of accounting:
Proved	4,909	4,804
Total property and equipment	116,752	6,219
Less accumulated depreciation, depletion, and amortization	(1,728)	(373)
Property and equipment, net	115,024	5,846
Long-term assets:
Investment in unconsolidated affiliate	102,923	104,434
Intangible assets, net	12,085	8,809
Goodwill	13,309	7,756
Assets held for sale		2,800
Other long-term assets	17,141	11
Total long-term assets	145,458	123,810
Total assets	828,114	189,582
Current liabilities:
Current maturities of debt		35,000
Obligations under supply and exchange agreements	333,599
Accounts payable	65,795	25,329
Other accrued liabilities	25,499	981
Accrued settlement claims	6,475	8,667
Total current liabilities	431,368	69,977
Long-term liabilities:
Long - term debt, net of current maturities and unamortized discount	67,448	7,391
Derivative liabilities	17,590	10,945
Obligations under supply and exchange agreements	17,132
Other liabilities	19,408	512
Total liabilities	552,946	88,825
Commitments and contingencies
Stockholders' Equity:
Preferred stock, $0.01 par value: authorized 3,000,000 shares, none issued
Common stock, $0.01 par value; authorized 500,000,000 shares at September 30, 2013 and December 31, 2012, issued 299,053,989 shares and 150,080,927 shares at September 30, 2013 and December 31, 2012, respectively	2,991	1,501
Additional paid-in capital	309,666	108,095
Accumulated deficit	(37,489)	(8,839)
Total stockholders' equity	275,168	100,757
Total liabilities and stockholders' equity	$ 828,114	$ 189,582

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(4) Acquisition: Schedule of Recognized Identified Assets Acquired and Liabilities Assumed (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Total assets	$ 828,114	$ 189,582
Texadian Energy Inc
Intangible assets		8,809
Goodwill		8,290
Net non cash working capital		3,097
Deferred tax liabilities		(2,757)
Total assets		$ 17,439

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(6) Debt: Schedule of Debt Instruments Interest and Financing Costs (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Debt Instruments Interest and Financing Costs

 Interest and financing costs consists of the following:

	Three Months Ended September 30, 2013		Nine Months Ended September 30,  2013
	(in thousands)
Interest accrued in kind	$	2,395	$	5,196
Amortization of debt discount relating to the warrants and embedded derivative		493		1,372
Accretion of 3% repayment premium on the Delayed Draw Term Loan Agreement		24		72
Accretion of 5% exit fee on the Tranche B Loan		—		1,750
Accretion of 2.5% exit fee on the New Tranche B Loan		909		1,078
Amortization of deferred loan costs		35		247
Miscellaneous		79		91
Interest and financing costs, net	$	3,935	$	9,806

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(3) Investments in Piceance Energy: Summary of Income Statement of Equity Investment (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Summary of Income Statement of Equity Investment

Summarized income statement information and our share for the period for which our investment was accounted for under the equity method is as follows:

	Three Months Ended September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	14,622		$	4,875
Natural gas and oil operating expenses		7,416			2,473
Depletion, depreciation and amortization		6,897			2,299
Management fee		1,950			650
General and administrative		447			149
Total operating expenses		16,710			5,571
Loss from operations		(2,088	)		(696	)
Other income (expense)
Income from derivatives		106			35
Interest expense and debt issue costs		(718	)		(239	)
Other expense		(20	)		(7	)
Total other expense, net		(632	)		(211	)
Net loss	$	(2,720	)	$	(907	)

	Nine Months Ended  September 30, 2013
	100%			Our Share
	(Unaudited)
	(in thousands)
Natural gas, oil and natural gas liquids revenues	$	44,076		$	14,695
Natural gas and oil operating expenses		22,160			7,388
Depletion, depreciation and amortization		17,557			5,854
Management fee		5,850			1,950
General and administrative		2,420			807
Total operating expenses		47,987			15,999
Loss from operations		(3,911	)		(1,304	)
Other income (expense)
Income from derivatives		825			275
Interest expense and debt issue costs		(2,139	)		(713	)
Other expense		(91	)		(30	)
Total other expense, net		(1,405	)		(468	)
Net loss	$	(5,316	)	$	(1,772	)

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(2) Summary of Significant Accounting Policies: Accrued settlement claims (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Details
Bankruptcy Claims, Amount of Claims Filed	$ 6.4

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(6) Debt (Details) (USD $)	9 Months Ended							9 Months Ended		9 Months Ended			9 Months Ended		9 Months Ended		9 Months Ended	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 Tranche B Term Loan Fourth Amendment to Loan Agreement	Sep. 30, 2013 Tranche B Term Loan Sixth Amendment to Loan Agreement	Sep. 30, 2013 Tranche B Term Loan Eighth Amendment to Loan Agreement	Sep. 30, 2013 Tranche B Term Loan Tenth Amendment to Loan Agreement	Sep. 30, 2013 Senior Secured Delayed Draw Term Loan	Dec. 28, 2012 Senior Secured Delayed Draw Term Loan Tranche B Term Loan	Sep. 30, 2013 ABL Revolving Credit Facility	Sep. 25, 2013 ABL Revolving Credit Facility	Sep. 30, 2013 Texadian Uncommitted Credit Agreement	Sep. 30, 2013 Letter of Credit Facility	Dec. 27, 2012 Letter of Credit Facility	Sep. 30, 2013 Letter of Credit Facility Senior Secured Delayed Draw Term Loan	Aug. 31, 2012 Letter of Credit Facility Senior Secured Delayed Draw Term Loan	Sep. 30, 2013 Financial Standby Letter of Credit	Dec. 27, 2012 Financial Standby Letter of Credit	Sep. 30, 2013 Warrant Issuance Agreement	Dec. 31, 2012 Warrant Issuance Agreement
Secured revolving credit facility								$ 125,000,000		$ 50,000,000		$ 30,000,000		$ 30,000,000
Letter of credit issued														13,000,000		11,710,000
Line of Credit Facility, Increase (Decrease), Net													17,000,000
Interest rate under credit facility						9.75%
Minimum repayment premium						3.00%
Interest rate after an event of default						11.75%
Repayment As Percentage Of Principal Amount						100.00%
Percent Of Prepayment Premium						6.00%
Fair value of embedded derivatives						65,000
Debt Instrument, Maturity Date		Dec. 31, 2013		Aug. 31, 2016		Aug. 31, 2016
Term loan facility							35,000,000
Terms of Net Cash Proceeds		(a) 50% of the net cash proceeds are to be applied to pay (i) first, an amendment fee and (ii) second, to repay the Tranche B Loan in accordance with each Tranche B Lender’s pro rata share, and (ii) 50% of the net cash proceeds are to be retained by us and used for general corporate purposes.
Debt Instrument Prepayment Terms		other than net cash proceeds from asset sales for fair market value resulting in no more than $150,000 in net cash proceeds per disposition (or series of related dispositions) and less than $300,000 in aggregate net cash proceeds before the Maturity Date
Repayments of Long-term Debt		1,300,000
General Partners' Contributed Capital			5,000,000
Cash Deposits			25,000,000
Short-term Debt, Refinanced, Description				we entered into an Eighth Amendment to our Loan Agreement, pursuant to which the Lenders agreed to refinance and replace the Tranche B Loan outstanding immediately prior to the Eighth Amendment with new Tranche B Loans in the aggregate principal amount of $65.0 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Existing Tranche B Loans, to make payments due under the Purchase Agreement, to consummate acquisitions permitted under the Loan Agreement and for working capital and general corporate purposes.
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum				9.75%	9.75%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum				14.75%	14.75%
Debt Instrument, Interest Rate Terms				At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.	At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.			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). Notwithstanding the foregoing, for the remainder of the current fiscal year of the ABL Borrowers, the margin will be 1.25% for Base Rate loans and 2.25% for LIBO Rate loans. 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 LIBO Rate for a particular interest period is equal to the rate determined by the ABL Agent at approximately 11:00 a.m. (London time) on the date that is two business days prior to the commencement of the particular interest period by reference to the Reuters Screen LIBOR01 for deposits in dollars for a particular interest period
Long-term Debt, Maturities, Repayment Terms				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.
Cash Deposits				2.50%
Line of Credit Facility, Capacity Available for Issuances of Letters of Credit								50,000,000
Line of Credit Facility, Amount Outstanding									15,000,000
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.
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.
Line of Credit Facility, Covenant Terms										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.
Line of Credit Facility, Expiration Date											Dec. 26, 2013				Feb. 05, 2013
Cash pledged as percentage of undrawn amount of all outstanding letters of credit											105.00%
Letter of credit fee											1.50%
Non-Option Equity Instruments, Granted																		9,592,125
Class of Warrant or Right, Exercise Price of Warrants or Rights																	$ 0.01
Common stock warrant expiration date																	Aug. 31, 2022
Exercise price of warrants multiplier fraction, numerator	9,737,182																147,655,815
Stock issued to settle bankruptcy claims																	2,232,934
Fair Value Of Warrants At Grant Date																	$ 6,600,000

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(8) Commitments and Contingencies: Schedule of Future Minimum Lease Payments for Capital Leases (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Details
2013	$ 382
2014	382
2015	382
2016	382
2017	382
Thereafter	840
Total minimum lease payments	2,750
Less amount representing interest	968
Total minimum rental payments	$ 1,782

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(12) Segment Information: Schedule of Segment Reporting Information, by Segment (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Segment Reporting Information, by Segment

For the three months ended September 30, 2013:	Natural Gas and Oil Exploration and Production	Commodity Transportation  and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Sales and operating revenues	$2,182	$4,598	$26,133	$2,472	—	$35.385
Operating income	648	1,952	405	494	(549)	2,950
Loss from unconsolidated affiliate	(907)	—	—	—	—	(907)
Capital expenditures	37	—	—	—	—	37
Capital additions from acquisitions*	—	—	101,103	4,670	—	105,773
Depreciation, depletion, amortization and accretion	519	599	96	—	—	1,214

For the nine months ended September 30, 2013:	Natural Gas  and Oil Exploration and Production	Commodity Transportation and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Sales and operating revenues	$5,988	$100,355	$26,133	$2,472	$—	$134,948
Operating income (loss)	483	13,773	405	494	(5,713)	9,442
Loss from unconsolidated affiliate	(1,773)	—	—	—	—	(1,773)
Capital expenditures	128	—	—	—	—	128
Capital additions from acquisitions*	—	—	101,103	4,670	—	105,773
Depreciation, depletion, amortization and accretion	1,291	1,631	96	—	—	3,018

* Includes only amounts capitalized as property, plant and equipment from the acquisition of HIE.

At September 30, 2013, our reportable segment assets consisted of the following (in thousands):

	Natural Gas  and Oil Exploration and Production	Commodity Transportation  and Marketing	Refining	Retail	Trust Litigation and Settlements	Total
Current assets	3,273	$33,847	489,056	6,441	$720	533,337
Property and equipment, net	4,697	47	103,715	2,120	—	110,579
Investments in unconsolidated affiliates	102,923	—	—	—	—	102,923
Goodwill and other intangible assets, net	—	15,593	9,801	—	—	25,394
Other long term assets	9	—	17,132	—	—	17,141
Totals	110,902	$49,487	619,704	8,561	$720	789,374

Reconciliation of reportable segment assets to our consolidated totals is as follows (in thousands):

	September 30,  2013
Total assets for reportable segments	789,374
Cash and restricted cash not allocated to segments	33,064
Property and equipment	4,446
Prepaid expenses and other assets	1,230
Total assets	828,114

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(8) Commitments and Contingencies: Schedule of Future Minimum Lease Payments for Capital Leases (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Future Minimum Lease Payments for Capital Leases

2013	$	382
2014		382
2015		382
2016		382
2017		382
Thereafter		840
Total minimum lease payments		2,750
Less amount representing interest		968
Total minimum rental payments	$	1,782

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(9) Stockholders' Equity: Schedule of Share-based Compensation, Activity (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule of Share-based Compensation, Activity

	Shares		Weighted- Average Grant Date Fair Value
Stock Awards:
Non vested balance, beginning of period		2,191,834	$	1.09
Granted		3,094,168		1.77
Vested		—		—
Forfeited		—		—
Non vested balance, end of period		5,286,002	$	1.49

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(7) Fair Value Measurements

9 Months Ended

Sep. 30, 2013

Notes

(7) Fair Value Measurements

(7) Fair Value Measurements

We follow accounting guidance which defines fair value, establishes a framework for measuring fair value in U.S. GAAP, and requires additional disclosures about fair value measurements. As required, we applied the following fair value hierarchy:

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 transfer 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. These valuation policies are determined by our Chief Financial Officer, with the assistance of third party experts as needed, and approved by our Chief Executive Officer. They are discussed with our Audit Committee as deemed appropriate. Each quarter, our Chief Financial Officer and Chief Executive Officer update the inputs used in the fair value measurement and internally review the changes from period to period for reasonableness. 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 Measure at Fair Value on a Nonrecurring Basis

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 the Level 3 valuation techniques described in notes (a) through (g) described below.

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,427		(a)
Property, plant and equipment		66,144		(b)
Land		39,800		(c)
Trade names and trade marks		4,782		(d)
Goodwill		5,203		(e)
Contingent consideration liability		(10,500	)	(f)
Other noncurrent liabilities		(8,249	)	(g)
	$	559,607

(a)       Current assets acquired and liabilities assumed were recorded at their estimated fair 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.

(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

Derivative liabilities associated with our debt agreement – Derivative liabilities include the Warrants and fair value is estimated using an income valuation technique 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 the stock price of $1.81 per share, initial exercise price $0.01, term of 8.92 years, risk free rate of 2.42%, and expected volatility of 72.5%. 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 $1.79 per share, or approximately $17.4 million, as of September 30, 2013. 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.

In addition, our Loan Agreement contains 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 consider 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 is 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 September 30, 2013, we estimate the fair value of the embedded derivative to be $153,000 based on the probability of us repaying the loan prior to maturity.

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 September 30, 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 September 30, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts except for contracts treated as normal purchase or normal sale contracts as discussed in our Summary of Significant Accounting Policies.

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 $10.5 million as described in (f) above. The liability will be 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 September 30, 2013.

Our liabilities measured at fair value on a recurring basis as of September 30, 2013 consist of the following (in thousands):

	September 30, 2013
	Fair Value			Level 1		Level 2		Level 3
Liabilities
Derivatives:
Warrants	$	(17,437	)	$	—	$	—	$	(17,437	)
Contingent consideration liability		(10,500	)	$	—		—		(10,500	)
Embedded derivatives		(153)			—		—		(153	)
	$	(28,090	)	$	—	$	—	$	(28,090	)

	Location on Consolidated Balance Sheet	Fair Value at September 30, 2013
		(in thousands)
Warrant derivatives	Noncurrent liabilities	$	(17,437	)
Contingent consideration liability	Noncurrent liabilities	$	(10,500	)
Embedded derivative	Noncurrent liabilities	$	(153	)

A rollforward of Level 3 derivative warrants and the embedded derivative measured at fair value using Level 3 on a reoccurring basis for the nine months ended September 30, 2013 is as follows (in thousands):

Description
Balance, at December 31, 2012	$	(10,945	)
Purchases, issuances, and settlements		(10,500	)
Total unrealized losses included in earnings		(6,645	)
Transfers		—
Balance, at September 30, 2013	$	(28,090	)

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

	For the three months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(1,390	)
Embedded derivatives	Other income (expense)		285
Commodities - exchange traded futures	Other income (expense)		—
Commodities - physical forward contracts	Other income (expense)		—

	For the nine months ended September 30, 2013
	Income Statement Classification	Gain (loss) recognized in income
Derivatives not designated as hedges:
Warrants	Other income (expense)	$	(6,645	)
Embedded derivatives	Other income (expense)		45
Commodities - exchange traded futures	Other income (expense)		104
Commodities - physical forward contracts	Other income (expense)		306

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(8) Commitments and Contingencies (Details) (USD $)	9 Months Ended	4 Months Ended	9 Months Ended			9 Months Ended	12 Months Ended		13 Months Ended
	Sep. 30, 2013	Dec. 31, 2012 Macquarie Capital (USA) Inc.	Sep. 30, 2013 Macquarie Capital (USA) Inc.	Sep. 30, 2013 Subsequent Event	Sep. 30, 2013 Subsequent Event Macquarie Capital (USA) Inc.	Sep. 30, 2013 Predecessor	Dec. 31, 2012 Wapiti Oil And Gas	Dec. 31, 2012 Wapiti Trust	Sep. 30, 2013 Wapiti Trust
Recovery Trust Funded Amount	$ 1,000,000
One Time Cash Payment As Consideration For Release Of Claims							1,500,000
Distribution From Trust								1,000,000	5,200,000
Percentage Of Beneficial Interest Owned						2.42%
Shares Of Beneficial Interest Owned Per $1,000 of claim						544
Loss Contingency, Estimate of Possible Loss	6,400,000
Bankruptcy Claims, Amount Paid to Settle Claims		0	0	145,000	2,500,000
Bankruptcy Claims, Number of Claims Settled		0	0	2
Bankruptcy Claims, Amount of Claims Settled		0	0	678,000
Stock issued to settle bankruptcy claims		0	0	46,935
Terminaling and storage agreement	$ 28,000,000

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(7) Fair Value Measurements: Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques

	Fair Value at September 25, 2013			Fair Value Technique
	(in thousands)
Net working capital	$	462,427		(a)
Property, plant and equipment		66,144		(b)
Land		39,800		(c)
Trade names and trade marks		4,782		(d)
Goodwill		5,203		(e)
Contingent consideration liability		(10,500	)	(f)
Other noncurrent liabilities		(8,249	)	(g)
	$	559,607

(a)       Current assets acquired and liabilities assumed were recorded at their estimated fair 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.

(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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(2) Summary of Significant Accounting Policies (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Feb. 20, 2013
Assets Held-for-sale, Long Lived		$ 2,900,000
Gain on disposal of other assets	50,000
Long-term Debt, Fair Value	61,300,000
Other Income	797,000
Proceeds from Income Tax Refunds	483,000
Proceeds from Legal Settlements	$ 200,000
Borrowings
Fair Value Inputs, Discount Rate	5.70%

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(10) Income Taxes

9 Months Ended

Sep. 30, 2013

Notes

(10) Income Taxes

(10) 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 $230 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 continues to conclude 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 September 30, 2013.

During the three and nine month periods ended September 30, 2013, 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.  State income tax expense of approximately $0 and $650,000 was recognized for the three and nine months ending September 30, 2013, respectively.

During 2013 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.

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(6) Debt

9 Months Ended

Sep. 30, 2013

Notes

(6) Debt

(6) Debt

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 $30.0 million. We borrowed $13.0 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 the nine months ended September 30, 2013, we borrowed an additional $17.0 million for general corporate use.  As of September 30, 2013, we have no capacity for future borrowings under this Loan Agreement.

Below are certain of the material terms of the Loan Agreement:

Interest. At our election, any Loans will bear interest at a rate equal to 9.75% per annum payable either (i) in cash, quarterly, in arrears at the end of each calendar quarter or (ii) in-kind, accruing quarterly. In addition, all repayments made under the Loan Agreement will be charged a minimum of a 3% repayment premium. Accordingly, we will accrue amounts due for the minimum repayment premium over the term of loan using the effective interest method.

At any time after an event of default under the Loan Agreement has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 11.75% and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. We may prepay Loans at any time, in any amount. Such prepayment is to include all accrued and unpaid interest on the portion of the obligations being prepaid through the prepayment date. If at any time within the twelve months following the Emergence Date, we prepay the obligations due, in whole, but not in part, then in addition to the repayment of 100% of the principal amount of the obligations being prepaid plus accrued and unpaid interest thereon, we are required to pay the interest that would have accrued on the prepaid amount through the first anniversary of the Emergence Date plus a 6% prepayment premium.

In addition to the above described prepayment premium, we will pay an additional repayment premium equal to the percentage of the principal repaid during the following periods: 

Period	Repayment  Premium
From the Emergence Date through the first anniversary of the Emergence Date		3	%
From the day after the first anniversary of the Emergence Date through the second anniversary of the Emergence Date		2	%

We are also required to make certain mandatory repayments after certain dispositions of property, debt issuances, and joint venture distributions from Piceance Energy, casualty events and equity issuances, in each case subject to customary reinvestment provisions. These mandatory repayments are subject to the prepayment premiums described above.

The contingent repayments described above are required to be accounted for as an embedded derivative. The estimated fair value of the embedded derivative at issuance was approximately $65,000 and was recorded as a derivative liability with the offset to debt discount. Subsequent changes in fair value are reflected in earnings (see Note 7).

Collateral. The Loans and all obligations arising under the Loan Agreement are secured by (i) a perfected, first-priority security interest in all of our assets other than our equity interest in Piceance Energy held by Par Piceance Energy Equity, LLC, one of our wholly owned subsidiaries (“Par Piceance Energy Equity”) , pursuant to a pledge and security agreement made by us and certain of our subsidiaries in favor of the Agent, and (ii) a perfected, second-lien security interest in our equity interest in Piceance Energy held by Par Piceance Energy Equity, pursuant to a pledge agreement by Par Piceance Energy Equity in favor of the Agent. The priority of the Lenders’ security interest in our assets is specified in that certain intercreditor agreement (the “Intercreditor Agreement”), among JPMorgan Chase Bank, N.A., as administrative agent for the First Priority Secured Parties (as defined in the Intercreditor Agreement), the Agent, as administrative agent for the Second Priority Secured Parties (as defined in the Intercreditor Agreement), the Company and Par Piceance Energy Equity.

Guaranty. All of our obligations under the Loan Agreement are unconditionally guaranteed by the Guarantors.

Fees and Commissions. We agreed to pay the Agent an annual nonrefundable administrative fee that was earned in full on the Emergence Date. In addition, we agreed to pay the Lenders a nonrefundable closing fee that was earned in full on the Emergence Date.

Warrants. As consideration for granting the Loans, we have also issued warrants to the Lenders to purchase shares of our common stock as described under “– Warrant Issuance Agreement” below.

Term. All loans and all other obligations outstanding under the Loan Agreement are payable in full on August 31, 2016.

Covenants. The Loan Agreement has no financial covenants that we are required to comply with; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations with which we were in compliance at September 30, 2013.

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 $35.0 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 a Letter of Credit Facility with Compass Bank (as described below). The Tranche B Loan was refinanced and replaced on July 24, 2013 by the New Tranche B Loan (as described below).

On April 19, 2013, we entered into a Fourth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Fourth Amendment:

Lender Consent to Compressor Disposition. The Lenders agreed that, in connection with the previous sale of our natural gas compressor assets held for sale (see Note 2) (a) 50% of the net cash proceeds are to be applied to pay (i) first, an amendment fee and (ii) second, to repay the Tranche B Loan in accordance with each Tranche B Lender’s pro rata share, and (ii) 50% of the net cash proceeds are to be retained by us and used for general corporate purposes.

Collateral. The Lenders agreed to the release of their liens and security interests on the assets of Texadian, including a release of any lien on the equity interests of Texadian pledged by us, and a release of Texadian from its guarantee under the Loan Agreement, if necessary. Such releases will only be made in connection with the closing of a definitive trade finance credit facility by Texadian and is subject in all respects to the satisfaction of the conditions to release described in the Fourth Amendment.

Mandatory Prepayment. Net cash proceeds of asset dispositions (other than as a result of a casualty), debt issuances and equity issuances can no longer be invested by us, and must be used to prepay the Loan Agreement, other than net cash proceeds from asset sales for fair market value resulting in no more than $150,000 in net cash proceeds per disposition (or series of related dispositions) and less than $300,000 in aggregate net cash proceeds before the Maturity Date.

Maturity Date. The Lenders agreed to extend the maturity date of the Tranche B Loan to December 31, 2013.

With the execution of the Fourth Amendment, we repaid approximately $1.3 million of the Tranche B Loan.

On June 4, 2013, we entered into a Fifth Amendment to our Loan Agreement allowing us to form a subsidiary, Hawaii Pacific Energy, in furtherance of our acquisition of HIE.

On June 12, 2013, we entered into a Sixth Amendment to our Loan Agreement.

Set forth below are certain material terms of the Sixth Amendment:

Pledge of Equity Interests. We are expressly permitted to pledge our equity interests in Texadian to secure the loans and other obligations of Texadian and Texadian Canada under the Uncommitted Credit Agreement (as described below).

Capital Contributions. We are permitted to make up to an aggregate amount of $5 million of capital contributions and/or loans to Texadian per year.

In connection with Hawaii Pacific Energy's entry into the Purchase Agreement, on June 17, 2013, we entered into a Seventh Amendment to the Loan Agreement.

Set forth below are certain of the material terms of the Seventh Amendment:

Lender Consent to Purchase Agreement. The Lenders consented to the execution of the Purchase Agreement by Hawaii Pacific Energy, and the performance of Hawaii Pacific Energy's obligations thereunder.

Lender Consent to Refinery Startup Reimbursement. The Lenders consented to the payment by Hawaii Pacific Energy of a cash deposit of up to $25 million, in addition to the reimbursement obligations specified in the Purchase Agreement in connection with the Refinery Startup Activities.

Lender Consent to the Consummation of the Acquisition of HIE. The Lenders consented to our use of any advance under the Loan Agreement to consummate the acquisition of HIE pursuant to the Purchase Agreement.

Lender Consent to Purchase Agreement Guaranty. The Lenders consented to the execution of our guaranty of certain obligations under the Purchase Agreement.

On June 24, 2013, we entered into an Eighth Amendment to our Loan Agreement, pursuant to which the Lenders agreed to refinance and replace the Tranche B Loan outstanding immediately prior to the Eighth Amendment with new Tranche B Loans in the aggregate principal amount of $65.0 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Existing Tranche B Loans, to make payments due under the Purchase Agreement, to consummate acquisitions permitted under the Loan Agreement and for working capital and general corporate purposes.

Set forth below are certain of the material terms of the New Tranche B Loans:

Interest. The New Tranche B Loans will bear interest (a) through September 29, 2013 at a rate equal to 9.75% per annum payable, at our election, either (i) in cash or (ii) in-kind, and (b) from and after September 29, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in-kind.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

Prepayment. 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.

Collateral. 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.

Guaranty. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.

Fees and Commissions. 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. Accordingly, we will accrete amounts due for the nonrefundable exit fee over the term of loan using the effective interest method.

Maturity Date. The New Tranche B Loans mature and are payable in full on August 31, 2016.

On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to our Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the Purchase Agreement and the use of a portion of the proceeds from the sale of our common stock in a private transaction to fund a portion of the consideration in connection with the transactions contemplated by the Purchase Agreement and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the 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 Purchase Agreement and the sale of our common stock.

The consent provided by the Lenders was conditioned on, among other things, (A) 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 the proceeds from the sale of our common stock and (B) the proceeds from the sale of our common stock being used to consummate the transactions contemplated by the Purchase Agreement.

Set forth below are certain of the additional material terms of the Tenth Amendment:

Interest: The term loans (other than the New Tranche B Loans that remain outstanding following the repayment described above) under the Loan Agreement will bear 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.

At any time after an event of default has occurred and is continuing, (i) all outstanding obligations will, to the extent permitted by applicable law, bear interest at a rate per annum equal to 2% plus the rate otherwise applicable and (ii) all interest accrued and accruing will be payable in cash on demand.

The New Tranche B Loans will 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.

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 ABL credit agreement (the “ABL Facility”) with Deutsche Bank AG New York Branch, as administrative agent and ABL loan collateral agent (in such capacities, the “ABL Agent”) for the lenders party thereto from time to time, including Deutsche Bank AG New York Branch (collectively, the “ABL Lenders”), pursuant to which the ABL Lenders agreed 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.

Set forth below are certain of the material terms of the ABL Facility:

Interest: 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). Notwithstanding the foregoing, for the remainder of the current fiscal year of the ABL Borrowers, the margin will be 1.25% for Base Rate loans and 2.25% for LIBO Rate loans. 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 LIBO Rate for a particular interest period is equal to the rate determined by the ABL Agent at approximately 11:00 a.m. (London time) on the date that is two business days prior to the commencement of the particular interest period by reference to the Reuters Screen LIBOR01 for deposits in dollars for a particular interest period.

Collateral: 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, including, but not limited to, accounts receivable, inventory that we own, the Refinery and all of its facilities, real property and improvements, pursuant to an ABL loan second lien security agreement, an ABL loan first lien security agreement and a second lien mortgage. The rights and remedies of the ABL Agent and ABL Lenders and the priority of the ABL Agent’s security interest in the collateral are subject to the HIE Intercreditor Agreement.

Guaranty and Pledge by HPE: Hawaii Pacific Energy has granted a security interest in favor of the ABL Agent in all of the membership interests Hawaii Pacific Energy owns in HIE (the “ABL Pledged Collateral”) pursuant to a Membership Interests Second Lien Pledge Agreement in favor of ABL Agent. The obligations of the ABL Borrowers under the ABL Facility are guaranteed by Hawaii Pacific Energy, however, the recourse of the ABL Agent under Hawaii Pacific Energy’s guaranty is limited to the ABL Pledged Collateral plus certain fees and expenses specified therein to the extent incurred by Barclays or the Inventory Agent in connection with the enforcement or protection of their rights thereunder. The rights and remedies of the ABL Agent, and the priority of the ABL Agent’s security interest in the ABL Pledged Collateral, are subject to the HIE Intercreditor Agreement.

Fees and Commissions: 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.

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

Covenants: 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.

Texadian Uncommitted Credit Agreement

On June 12, 2013, Texadian and its wholly owned subsidiary Texadian Canada entered into an uncommitted credit agreement with BNP Paribas, as the initial lender party thereto, and BNP Paribas, as the administrative agent and collateral agent for the lenders and as an issuing bank (the “Uncommitted Credit Agreement”). The Uncommitted Credit Agreement 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 $50.0 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 September 30, 2013, Texadian was in compliance with these covenants.

Letter of Credit Facility

On December 27, 2012, we entered into a letter of credit facility agreement with Compass Bank, as the lender (the “Compass Letter of Credit Facility”). The Compass Letter of Credit Facility, which matures on December 26, 2013, provides for a letter of credit facility in an aggregate principal amount of $30.0 million that is available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries’ account. Letters of credit issued under the Compass Letter of Credit Facility are secured by an amount of cash pledged and delivered by us to Compass equal to one hundred five percent (105%) of the undrawn amount of all outstanding letters of credit. We agreed to pay a letter of credit fee equal to one and one half percent (1.5%) per annum of the stated face amount of each letter of credit for the number of days such letter of credit is to remain outstanding plus standard and customary administrative fees. The Compass Letter of Credit Facility does not contain any financial covenants; however, it does require us to comply with various affirmative and negative covenants affecting our business and operations. The Compass Letter of Credit Facility was terminated on June 7, 2013.

In connection with the acquisition of Texadian, Compass Bank issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.71 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that either of the following letters of credit is drawn: (i) the letter of credit issued by DNB Bank, ASA in favor of Suncor Energy Marketing Inc., with an original maturity date of February 5, 2013; or (ii) the letter of credit issued by DNB Bank, ASA in favor of Cenovus Energy Marketing Services Limited, with an original maturity date of February 5, 2013. Those letters of credit have been terminated and released.

Cross Default Provisions

Included within each of the Company’s 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.

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 9,592,125 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 $0.01 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 Warrant Shares issued on the Emergence Date was determined based on the number of shares of our common stock issued as allowed claims on or about the Emergence Date by the Bankruptcy Court pursuant to the Plan of Reorganization. The Warrant Issuance Agreement provides that the number of Warrant Shares and the Exercise Price shall be adjusted in the event that any additional shares of common stock or securities convertible into common stock (the “Unresolved Bankruptcy Shares”) are authorized to be issued under the Plan by the Bankruptcy Court after the Emergence Date as a result of any unresolved bankruptcy claims under the Plan. Upon each issuance of any Unresolved Bankruptcy Shares, the Exercise Price shall be reduced to an amount equal to the product obtained by multiplying (A) the Exercise Price in effect immediately prior to such issuance or sale, by (B) a fraction, the numerator of which shall be (x)  147,655,815 and (y) the denominator of which shall be the sum of (1) 147,655,815 and (2) and the number of additional Unresolved Bankruptcy Shares authorized for issuance under the Plan. Upon each such adjustment of the Exercise Price, the number of Warrant Shares shall be increased to the number of shares determined by multiplying (A) the number of Warrant Shares which could be obtained upon exercise of such Warrant immediately prior to such adjustment by (B) a fraction, the numerator of which shall be the Exercise Price in effect immediately prior to such adjustment and the denominator of which shall be the Exercise Price in effect immediately after such adjustment. In the event that any Lender or its affiliates fails to fund its pro rata portion of any Loans required to be made under the Loan Agreement, then the number of Warrant Shares exercisable under the Warrants held by such Lender will be reduced to an amount equal to the product of (i) the number of Warrant Shares initially exercisable under the Warrant held by the Lender and (ii) a fraction equal to one minus the quotient obtained by dividing (x) the amount of Loans previously made under the Loan Agreement by such Lender by (y) such Lender’s full commitment for Loans.

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 September 30, 2013, we issued an additional 2,232,934 Unresolved Bankruptcy Shares. This entitles the Lenders to receive an additional 145,057 Warrant Shares based on the formula described above increasing the total Warrant Shares to 9,737,182 at September 30, 2013.

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 will be amortized over the life of the Loan Agreement, using the effective interest method. Subsequent changes in the fair value of the Warrants are reflected in earnings (see Note 7).

Summary

Our debt at September 30, 2013 is as follows (in thousands):

Delayed Draw Term Loan Agreement, including interest in-kind	$	32,389
New Tranche B Loan, including interest in-kind		18,760
ABL Facility		21,000
Less: unamortized debt discount – warrants and embedded derivative		(4,701	)
Total debt, net of unamortized debt discount		67,448
Less: current maturities		—
Long term debt, net of current maturities and unamortized discount	$	67,448

 Interest and financing costs consists of the following:

	Three Months Ended September 30, 2013		Nine Months Ended September 30,  2013
	(in thousands)
Interest accrued in kind	$	2,395	$	5,196
Amortization of debt discount relating to the warrants and embedded derivative		493		1,372
Accretion of 3% repayment premium on the Delayed Draw Term Loan Agreement		24		72
Accretion of 5% exit fee on the Tranche B Loan		—		1,750
Accretion of 2.5% exit fee on the New Tranche B Loan		909		1,078
Amortization of deferred loan costs		35		247
Miscellaneous		79		91
Interest and financing costs, net	$	3,935	$	9,806

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(1) Reorganization Under Chapter 11

9 Months Ended

Sep. 30, 2013

Notes

(1) Reorganization Under Chapter 11

(1) Reorganization under Chapter 11

In December 2011, Delta Petroleum Corporation (“Delta”) and its subsidiaries Amber Resources Company of Colorado, DPCA, LLC, Delta Exploration Company, Inc., Delta Pipeline, LLC, DLC, Inc., CEC, Inc. and Castle Texas Production Limited Partnership 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”). In January 2012, Castle Exploration Company, Inc., a subsidiary of Delta Pipeline, LLC, also filed a voluntary petition under Chapter 11 in the Bankruptcy Court. Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”

In December 2011, the Debtors filed a motion requesting an order to approve matters relating to a proposed sale of Delta’s assets, including bidding procedures, establishment of a sale auction date and establishment of a sale hearing date. In January 2012, the Bankruptcy Court issued an order approving these matters. In March, 2012, Delta announced that it was seeking court approval to amend the bidding procedures for its upcoming auction to allow bids relating to potential plans of reorganization as well as asset sales. On March 22, 2012, the Bankruptcy Court approved the revised procedures.

Following the auction, 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 of Reorganization” or the “Plan”) by which Laramie and Delta intended to form a new joint venture called Piceance Energy, LLC (“Piceance Energy”). In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with Piceance Energy and Laramie to effect the transactions contemplated by the Plan.

On June 4, 2012, the Debtors filed a disclosure statement relating to the Plan of Reorganization. The Plan was confirmed on August 15, 2012 and 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 (referred to after the closing of the transaction as “Successor”). 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.

On the Emergence Date, Delta also amended and restated its certificate of incorporation and bylaws and changed its name to Par Petroleum Corporation (“Par”). The amended and restated certificate of incorporation contains restrictions that render void certain transfers of the Company stock that involve a holder of five percent or more of its shares. The purpose of this provision is to preserve certain of the Company’s tax attributes including net operating loss carryforwards that the Company believes may have value. Under the amended and restated bylaws, the Company’s board of directors has five members, each of whom was appointed by its stockholders pursuant to a Stockholders’ Agreement entered into on the Emergence Date.

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 147.7 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 governs the operations of Piceance Energy (the “LLC Agreement”).

In addition, Laramie and Piceance Energy entered into a Management Services Agreement pursuant to which Laramie provides certain services to Piceance Energy for a fee of $650,000 per month.

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(4) Acquisition: Schedule of Purchase Price Allocation, Preliminary Estimated Fair Value of the Assets Acquired and Liabilities Assumed (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Property and equipment, net	$ 115,024	$ 5,846
Land	39,800
Goodwill	13,309	7,756
Other liabilities	19,408	512
Total assets	828,114	189,582
Membership Interest Purchase Agreement
Property and equipment, net	66,144
Land	39,800
Goodwill	5,203
Intangible Assets, Current	4,782
Net non cash working capital	462,427
Business Combination, Contingent Consideration, Liability	(10,500)
Other liabilities	(8,249)
Total assets	$ 559,607

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(3) Investments in Piceance Energy: Equity Investment Change, Piceance Energy (Details) (Piceance Energy, USD $) In Thousands, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Piceance Energy
Beginning balance	$ 103,815	$ 104,434
Income (loss) from unconsolidated affiliates	(907)	(1,772)
Capitalized drilling costs obligation paid	15	261
Ending balance	$ 102,923	$ 102,923

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(8) Commitments and Contingencies: Schedule Of Reorganization Distributions To Satisfy Allowed Claims (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Schedule Of Reorganization Distributions To Satisfy Allowed 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	$	22,364,000		—	$	—	$	—		—		3	$	22,364,000
Former Employee Claims		32		16,379,849		13		3,685,253		229,478		202,231		19		12,694,596
Macquarie Capital (USA) Inc.		1		8,671,865		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		—		—		—		—		1		3,200,000
Other Various Claims*		69		23,113,659		12		2,914,859		29,427		522		57		20,198,800
Total		106	$	73,729,373		25	$	6,600,112	$	258,905		202,753		81	$	67,129,261

	For the Nine Months Ended September 30, 2013
	Settled Claims								Remaining Filed Claims
					Consideration
	Count		Amount		Cash		Stock		Count		Amount
U.S. Government Claims		1	$	—	$	—		—		2	$	22,364,000
Former Employee Claims		19		12,694,596		339,588		1,614,988		—		—
Macquarie Capital (USA) Inc.		—		—		—		—		1		8,671,865
Swann and Buzzard Creek Royalty Trust		1		3,200,000		2,000,000		—		—		—
Other Various Claims*		26		1,620,177		397,754		398,785		31		18,578,623
Total		47	$	17,514,773	$	2,737,342		2,013,773		34	$	49,614,488

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(9) Stockholders' Equity (Details) (USD $)	9 Months Ended		3 Months Ended	9 Months Ended	12 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended		9 Months Ended
	Sep. 30, 2013	Dec. 20, 2012	Sep. 30, 2013 Restricted Stock	Sep. 30, 2013 Restricted Stock	Dec. 31, 2012 Restricted Stock	Sep. 30, 2013 Employee Restricted Stock	Sep. 30, 2013 Common stock	Sep. 30, 2013 Common stock	Sep. 13, 2013 Common stock	Sep. 30, 2013 Common stock Key Employees and Directors	Sep. 30, 2013 Common stock Bankruptcy Settlement
Sale of Stock, Price Per Share									$ 1.39
Sale of Stock, Number of Shares Issued in Transaction							143,884,892
Proceeds from sale of common stock, net of offering cost								$ 200,000,000
Stock issued to settle bankruptcy claims, shares								2,014,000			2,014,000
Stock based compensation, shares								2,509,000		3,129,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized		16,000,000
Equity Instruments Other than Options, Grants in Period	3,094,168			3,094,168	2,191,834
Award Vesting Period						5 years
Allocated Share-based Compensation Expense			210,000	491,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized			$ 6,300,000	$ 6,300,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition				4 years 7 months 6 days

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(7) Fair Value Measurements (Details) (Fair Value, Inputs, Level 3, USD $)	9 Months Ended
	Sep. 30, 2013
Fair Value, Inputs, Level 3
Stock Price	$ 1.81
Fair Value Assumptions, Exercise Price	$ 0.01
Fair Value Assumptions, Expected Term	8 years 11 months 1 day
Fair Value Assumptions, Risk Free Interest Rate	2.42%
Fair Value Assumptions, Expected Volatility Rate	72.50%
Fair Value Assumptions Historical Volatilities Period	10 years
Fair value of warrants issued, per share	$ 1.79
Fair value of warrants issued	$ 17,400,000
Derivative Liability	$ 153,000

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(13) Related Party Transactions

9 Months Ended

Sep. 30, 2013

Notes

(13) Related Party Transactions

(13) 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 6).

On September 17, 2013 (but effective January 1, 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 $50,000 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 unless 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.

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(9) Stockholders' Equity

9 Months Ended

Sep. 30, 2013

Notes

(9) Stockholders' Equity

 (9) Stockholders’ Equity

Common Stock

On September 13, 2013, we entered into the Common Stock Purchase Agreement pursuant to which we agreed to sell, contemporaneously with the consummation of the acquisition of HIE, shares of our common stock at a price of $1.39 per share (the “Shares”) in a private transaction (the “Stock Sale”). 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 Stock Sale and issued 143,884,892 Shares. The Stock Sale resulted in aggregate gross proceeds to us of approximately $200.0 million. We did not engage any investment advisors with respect to the Stock Sale, and no finders’ fees or commissions will be paid to any party in connection therewith. The Shares have been issued and sold by us in a private placement transaction in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933, as amended.

During the nine months ended September 30, 2013, we issued approximately 2,014,000 shares of our common stock for settlement of bankruptcy claims and approximately 3,129,000 shares of restricted and unrestricted common stock to certain key employees and directors.

Registration Rights Agreement

In connection with the closing of the sale of the Shares, we entered into a registration rights agreement (the “Registration Rights Agreement”), with the purchasers of the Shares. Under the Registration Rights Agreement, we agreed to file a registration statement relating to the Shares 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.

The 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, the Registration Rights Agreement contains customary indemnification rights and obligations for both us and the holders of registrable securities.

If the 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 the 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 16 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.

On December 31, 2012, a total of 2,191,834 shares of our restricted common stock were granted to members of the Board of Directors and certain key employees. During the nine months ended September 30, 2013, an additional 3,094,168 shares of our restricted stock were granted to certain key 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 nine months ended September 30, 2013, the following activity occurred under our Incentive Plan:

	Shares		Weighted- Average Grant Date Fair Value
Stock Awards:
Non vested balance, beginning of period		2,191,834	$	1.09
Granted		3,094,168		1.77
Vested		—		—
Forfeited		—		—
Non vested balance, end of period		5,286,002	$	1.49

For the three and nine months ended September 30, 2013, we recognized compensation costs of approximately $210,000 and $491,000, respectively, related to the restricted stock awards. As of September 30, 2013, there are approximately $6.3 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 4.6 years. The grant date fair value was estimated using the previous 20 days average trading price of our common stock.

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(10) Income Taxes (Details) (USD $)	3 Months Ended	6 Months Ended	9 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Sep. 30, 2013
Details
Operating Loss Carryforwards, Change in Amount			$ 230,000,000
State and Local Income Tax Expense (Benefit), Continuing Operations	$ 0	$ 650,000

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(3) Investments in Piceance Energy: Summary of Balance Sheet of Equity Investment (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Summary of Balance Sheet of Equity Investment

Summarized balance sheet information and our share of the equity investment are as follows:

	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Assets
Cash and equivalents	$	23		$	8
Accounts receivable		3,486			1,162
Prepaids and other assets		1,323			441
Total current assets		4,832			1,611
Natural gas and oil property, successful efforts method of accounting		549,327			183,146
Other real estate and land		14,314			4,772
Office furniture and equipment		3,110			1,037
Total		566,751			188,955
Less: accumulated depletion, depreciation and amortization		(107,216	)		(35,746	)
Total property and equipment, net		459,535			153,209
Deferred issue costs and other assets, net		953			318
Total assets	$	465,320		$	155,138

	September 30, 2013
		100%		Our Share
	(Unaudited)
	(in thousands)
Accounts payable and accrued liabilities	$	5,023		$	1,675
Natural gas and oil sales payable		11,041			3,681
Derivative liabilities		542			181
Total current liabilities		16,606			5,537
Note payable		90,000			30,006
Asset retirement obligations		2,959			987
Total non-current liabilities		92,959			30,993
Total liabilities		109,565			36,530
Members equity
Members’ equity		365,046			121,706
Accumulated deficit		(9,291	)		(3,098	)
Total members’ equity		355,755			118,608
Total liabilities and members’ equity	$	465,320		$	155,138

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(2) Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2013

Policies

Fresh Start Accounting and The Effects of The Plan

Fresh Start Accounting and the Effects of the Plan

As required by U.S. GAAP, effective as of August 31, 2012, Par adopted fresh start accounting following the guidance of the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 852 “Reorganizations” (“ASC 852”). Fresh start accounting 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 “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 two and eight months ended August 31, 2012 have been omitted. Fresh start accounting 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 accounting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities.

Cash Equivalents

Cash Equivalents

We consider all highly liquid investments with maturities at date of acquisition of three months or less to be cash equivalents.

Restricted Cash

Restricted Cash

As of September 30, 2013, restricted cash totaled approximately $1.7 million and consisted of approximately $720,000 designated to settle bankruptcy matters that is not available for operating activities (see Note 8) and approximately $1.0 million held at a commercial bank to support a letter of credit facility related to our acquisition of HIE. At December 31, 2012, restricted cash totaled approximately $24 million, including amounts held at a commercial bank to support a letter of credit facility totaling approximately $19.0 million (see Note 6) and approximately $4.8 million designated to settle bankruptcy matters. During the nine months ended September 30, 2013, the $19.0 million of restricted cash supporting a letter of credit facility was released to us and was made available for general corporate purposes.

Trade Receivables

Trade Receivables

Texadian’s customers primarily included major independent refining and marketing companies. HIE’s receivables include receivables from the sale of refined products and proprietary credit card receivables from sales at its retail locations. Customers are required to pay in advance or are granted credit on a short-term basis when credit risks are considered acceptable. We routinely review our trade receivables and make provisions for doubtful accounts based on existing customer and economic conditions; however, those provisions are estimates and actual results could differ from those estimates and those differences may be material. Trade receivables that are deemed uncollectible are removed from accounts receivable and from the allowance for doubtful accounts when collection efforts have been unsuccessful. As of September 30, 2013, we had no significant allowance for doubtful accounts. Several of Texadian’s physical purchases and sales are with the same counterparty and are settled on a net basis and therefore Texadian’s receivables are recorded net of any corresponding payables. 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.

Refined Product Exchanges

Refined Product Exchanges

As further described in Note 4, HIE has entered into supply and exchange contracts whereby it agrees 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 that are settled in kind on a volumetric basis, 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

Inventories

Texadian’s inventories, which consist of in-transit oil, are stated at the lower of cost or market. We record impairments, as needed, to adjust the carrying amount of inventories to the lower of cost or market.

HIE acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 4. Legal title to the crude oil is held by Barclays and the crude oil is stored in HIE’s storage tanks for the benefit of Barclays pursuant to a storage agreement until it is needed for further use in the refining process. At that time, certain nominated volumes are drawn out of the storage tanks and purchased by us. After processing and subject to the supply and exchange agreements described in Note 4, Barclays takes title to the refined products when the refined products enters the tanks which are then stored in HIE’s storage tanks until sold at 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. Inventories are stated at the lower of cost or market. We use last-in, first-out as the primary method to determine the cost of crude oil and refined product inventories in our refining and retail segments. We value merchandise along with spare parts, materials and supplies at average cost.

Investment in Unconsolidated Affiliate

 Investment in Unconsolidated Affiliate

Investments in operating entities where we have the ability to exert significant influence, but do not control the operating and financial policies, are accounted for using the equity method. Our share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations.

Our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3).

Property and Equipment

Property and Equipment

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 amortized 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 amortized as the related reserves are produced.

HIE’s operations, especially those of the refining segment, are highly capital intensive. The refinery consists of a series of interconnected, highly integrated and interdependent crude oil processing facilities and supporting logistical infrastructure, and these units are regularly improved. We plan for these improvements by developing a multi-year capital program that is updated and revised based on changing internal and external factors.

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. The useful lives range from 8 to 47 years for refining assets, 3 to 30 years for logistics assets, 14 to 18 years for retail assets, 3 to 7 years for corporate assets and 3 for software. 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.

Goodwill and Other Intangible Assets

Goodwill and Other Intangible Assets

We recorded goodwill as a result of our acquisitions of Texadian and have preliminarily recognized goodwill with the acquisition of HIE. Goodwill was attributable to opportunities expected to arise from combining our operations with Texadian’s and HIE’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, as a result of our acquisitions of Texadian and HIE, we recorded certain other identifiable intangible assets. These 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.

Impairment of Goodwill and Long-lived Assets

Impairment of Goodwill and Long-Lived Assets

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. Qualitative factors assessed for the reporting unit would include the competitive environments and financial performance of the reporting unit. 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, based upon a multiple of estimated earnings. 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. The fair value calculation uses Level 3 (see Note 7) inputs and includes multiple assumptions and estimates, including the projected cash flows and discount rates applied. Changes in these assumptions and estimates could result in a goodwill impairment that could materially adversely impact our financial position or results of operations.

 We evaluate the carrying value of our intangible assets when impairment indicators are present or when circumstances indicate that impairment may exist under authoritative guidance. 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 fair value. These impairment tests are heavily influenced by assumptions and estimates that are subject to change as additional information becomes available.

Our natural gas and oil assets, including our investment in our unconsolidated affiliate, are reviewed for impairment quarterly or when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Estimates of expected future cash flows represent our best estimate based on reasonable and supportable assumptions and projections.

For proved properties, if the expected future cash flows exceed the carrying value of the asset, no impairment is recognized. If the carrying value of the asset exceeds the expected future cash flows, an impairment exists and is measured by the excess of the carrying value over the estimated fair value of the asset. Any impairment provisions recognized are permanent and may not be restored in the future.

We assess proved properties on an individual field basis for impairment each quarter when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For proved properties, the review consists of a comparison of the carrying value of the asset with the asset’s expected future undiscounted cash flows without interest costs.

For unproved properties, the need for an impairment charge is based on our plans for future development and other activities impacting the life of the property and our ability to recover our investment. When we believe the costs of the unproved property are no longer recoverable, an impairment charge is recorded based on the estimated fair value of the property.

We review property, plant and equipment and other long-lived assets whenever events or changes in business circumstances indicate the net book values 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’ net book value. If this occurs, an impairment loss is recognized for the difference between the fair value and net book 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.

Asset Retirement Obligations

Asset Retirement Obligations

An asset retirement obligation (“ARO”) is an estimated liability for the cost to retire a tangible asset. Our AROs arise from plugging and abandonment liabilities for our natural gas and oil wells, as well as AROs arising from HIE’s refinery and retail operations. We record 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. 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. 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 associated with HIE 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

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 primarily in operating expenses in our statements of consolidated operations.

Derivatives and Other Financial Instruments

Derivatives and Other Financial Instruments

We may 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.

Accrued settlement claims

Accrued Settlement Claims

As of September 30, 2013, we have accrued approximately $6.4 million relating to claims resulting from our bankruptcy (see Note 8). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.

Income Taxes

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 in the financial statements 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 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 HIE’s and Texadian’s operations.  They operate in states where we have no net operating loss carryovers available to offset taxable income generated within those states.  Accordingly, we have accrued state income tax expense of approximately $0 and $650,000 for the three and nine months ended September 30, 2013, respectively.

Stock Based Compensation

Stock Based Compensation

We recognize the cost of share based payments over the period the employee provides service, generally the vesting period, and includes such costs in general and administrative expense in the 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

Revenue Recognition

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 September 30, 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.

Marketing and Transportation

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.

Texadian earns 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 and Retail

HIE recognizes 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

Foreign Currency Transactions

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 foreign currency gains or losses, net in the accompanying consolidated statements of operations in the period in which the currency exchange rates change.

Use of Estimates

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 under fresh start accounting, fair value of assets and liabilities recorded under purchase accounting, natural gas and oil reserves, bad debts, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.

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Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 14, 2013
Document and Entity Information:
Entity Registrant Name	PAR PETROLEUM CORP/CO
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Amendment Flag	false
Entity Central Index Key	0000821483
Current Fiscal Year End Date	--12-31
Entity Common Stock Shares Outstanding		299,075,145
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3

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(3) Investments in Piceance Energy: Equity Investment Change, Piceance Energy (Tables)

9 Months Ended

Sep. 30, 2013

Tables/Schedules

Equity Investment Change, Piceance Energy

	Three Months Ended September 30,  2013			Nine Months Ended September 30,  2013
	(in thousands)
Beginning balance	$	103,815			$	104,434
Income (loss) from unconsolidated affiliates		(907	)			(1,772	)
Capitalized drilling costs obligation paid		15				261
Ending balance	$	102,923			$	102,923

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(7) Fair Value Measurements: Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Warrant
Total unrealized losses included in earnings	$ (1,390)	$ (6,645)
Gain (loss) recognized in income	(1,390)	(6,645)
Embedded Derivative
Total unrealized losses included in earnings	285	45
Gain (loss) recognized in income	285	45
Exchange Traded Futures
Total unrealized losses included in earnings	0	104
Gain (loss) recognized in income	0	104
Physical Forward Contacts
Total unrealized losses included in earnings	0	306
Gain (loss) recognized in income	0	306
Fair Value, Inputs, Level 3
Balance, at December 31, 2012		(10,945)
Purchases, issuances, and settlements		(10,500)
Total unrealized losses included in earnings		(6,645)
Transfers		0
Balance, at September 30, 2013	(28,090)	(28,090)
Gain (loss) recognized in income		$ (6,645)

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(7) Fair Value Measurements: Fair Value, Liabilities Measured on Recurring Basis (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Derivative Liability, Fair Value, Gross Liability	$ (28,090)
Warrant
Derivative Liability, Fair Value, Gross Liability	(17,437)
Contingent consideration liability
Derivative Liability, Fair Value, Gross Liability	(10,500)
Embedded Derivative
Derivative Liability, Fair Value, Gross Liability	(153)
Fair Value, Inputs, Level 3
Derivative Liability, Fair Value, Gross Liability	(28,090)
Fair Value, Inputs, Level 3 | Warrant
Derivative Liability, Fair Value, Gross Liability	(17,437)
Fair Value, Inputs, Level 3 | Contingent consideration liability
Derivative Liability, Fair Value, Gross Liability	(10,500)
Fair Value, Inputs, Level 3 | Embedded Derivative
Derivative Liability, Fair Value, Gross Liability	$ (153)