Dune Energy (DUNRQ) 10-Q 2013 Q2 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

Form 10-Q

x Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 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 001-32497

DUNE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware	95-4737507
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

Two Shell Plaza, 777 Walker Street, Suite 2300, Houston, Texas	77002
(Address of principal executive offices)	(Zip Code)

(713) 229-6300

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  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 RegulationS-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant to submit and post such files).    Yes  x    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, anon-accelerated filer or a smaller reporting company. See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

Large Accelerated Filer	¨	Accelerated Filer	¨
Non-Accelerated Filer	¨  (Do not check if a smaller reporting company)	Smaller Reporting Company	x

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 71,497,324 shares of Common Stock, $.001 par value per share, as of August 7, 2013.

PART 1

FINANCIAL INFORMATION

Item 1. Financial Statements.

Dune Energy, Inc.

Consolidated Balance Sheets

(Unaudited)

	June 30, 2013			December 31, 2012
ASSETS
Current assets:
Cash	$	16,236,288		$	22,793,916
Accounts receivable		8,306,955			6,723,233
Current derivative asset		451,953			765,992
Prepayments and other current assets		1,343,365			5,160,533
Total current assets		26,338,561			35,443,674
Oil and gas properties, using successful efforts accounting—proved		268,281,667			239,233,653
Less accumulated depreciation, depletion and amortization		(21,749,779	)		(13,806,672	)
Net oil and gas properties		246,531,888			225,426,981
Property and equipment, net of accumulated depreciation of $186,066 and $256,380		188,871			71,080
Deferred financing costs, net of accumulated amortization of $1,167,515 and $771,061		2,137,521			2,428,453
Noncurrent derivative asset		379,925			397,886
Other assets		3,209,481			2,692,797
		5,915,798			5,590,216
TOTAL ASSETS	$	278,786,247		$	266,460,871
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	10,389,706		$	6,987,857
Accrued liabilities		10,568,110			12,529,899
Current maturities on long-term debt (see note 2)		231,935			1,623,541
Total current liabilities		21,189,751			21,141,297
Long-term debt (see note 2)		78,699,326			83,429,862
Other long-term liabilities		14,469,747			13,860,597
Total liabilities		114,358,824			118,431,756
Commitments and contingencies		—			—
STOCKHOLDERS’ EQUITY
Preferred stock, $.001 par value, 1,000,000 shares authorized, 250,000 shares undesignated, no shares issued and outstanding		—			—
Common stock, $.001 par value, 4,200,000,000 shares authorized, 71,907,952 and 59,022,445 shares issued		71,908			59,022
Treasury stock, at cost (63,810 and 1,056 shares)		(121,146	)		(1,914	)
Additional paid-in capital		176,881,059			155,824,868
Accumulated deficit		(12,404,398	)		(7,852,861	)
Total stockholders’ equity		164,427,423			148,029,115
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	278,786,247		$	266,460,871

See notes to unaudited consolidated financial statements.

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Dune Energy, Inc.

Consolidated Statements of Operations

(Unaudited)

	Three months ended June 30, 2013			Three months ended June 30, 2012			Six months ended June 30, 2013			Six months ended June 30, 2012
Revenues:
Oil and gas revenues	$	16,783,479		$	13,106,809		$	28,905,142		$	26,501,925
Other revenues		—			—			963,150			—
Total revenues		16,783,479			13,106,809			29,868,292			26,501,925
Operating expenses:
Lease operating expense and production taxes		7,848,003			6,699,881			14,709,404			12,858,666
Accretion of asset retirement obligation		402,732			365,439			805,464			730,878
Depletion, depreciation and amortization		4,793,818			4,986,322			7,961,704			9,271,983
General and administrative expense		3,129,377			2,322,537			5,717,459			5,423,594
Gain (loss) on settlement of asset retirement obligation liability		(22,920	)		465,024			—			888,946
Total operating expense		16,151,010			14,839,203			29,194,031			29,174,067
Operating income (loss)		632,469			(1,732,394	)		674,261			(2,672,142	)
Other income (expense):
Other income		90			2,405			692			13,702
Interest expense		(2,484,209	)		(2,411,781	)		(4,919,188	)		(4,781,467	)
Gain (loss) on derivative instruments		510,288			5,020,058			(307,302	)		4,727,636
Total other income (expense)		(1,973,831	)		2,610,682			(5,225,798	)		(40,129	)
Net income (loss)	$	(1,341,362	)	$	878,288		$	(4,551,537	)	$	(2,712,271	)
Net income (loss) per share:
Basic and diluted	$	(0.02	)	$	0.02		$	(0.07	)	$	(0.07	)
Weighted average shares outstanding:
Basic and diluted		63,238,696			39,402,243			61,156,848			39,114,285

See notes to unaudited consolidated financial statements.

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Dune Energy, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

	Six months ended June 30, 2013			Six months ended June 30, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss	$	(4,551,537	)	$	(2,712,271	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depletion, depreciation and amortization		7,961,704			9,271,983
Amortization of deferred financing costs		396,454			364,154
Stock-based compensation		1,288,589			1,028,225
Loss on settlement of asset retirement obligation liability		—			888,946
Accretion of asset retirement obligation		805,464			730,878
Unrealized loss (gain) on derivative instruments		332,000			(3,972,122	)
Changes in:
Accounts receivable		(1,693,865	)		1,546,048
Prepayments and other assets		3,817,168			1,274,502
Payments made to settle asset retirement obligations		(196,314	)		(1,910,086	)
Accounts payable and accrued liabilities		2,805,040			6,902,054
NET CASH PROVIDED BY OPERATING ACTIVITIES		10,964,703			13,412,311
CASH FLOWS FROM INVESTING ACTIVITIES
Cash investment in proved and unproved properties		(27,143,528	)		(17,721,344	)
Decrease in restricted cash		—			17,184
Purchase of furniture and fixtures		(145,477	)		(94,487	)
Decrease (increase) in other assets		(516,684	)		314,969
NET CASH USED IN INVESTING ACTIVITIES		(27,805,689	)		(17,483,678	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from sale of common stock		20,000,000			—
Common stock issuance costs		(219,513	)		—
Payments on short-term debt		(1,391,607	)		(4,333,592	)
Increase in long-term debt issuance costs		(105,522	)		(96,548	)
Payments on long-term debt		(8,000,000	)		(3,000,000	)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		10,283,358			(7,430,140	)
NET CHANGE IN CASH BALANCE		(6,557,628	)		(11,501,507	)
Cash balance at beginning of period		22,793,916			20,393,672
Cash balance at end of period	$	16,236,288		$	8,892,165
SUPPLEMENTAL DISCLOSURES
Interest paid	$	1,226,811		$	1,415,771
Income taxes paid		—			—
NON-CASH INVESTING AND FINANCIAL DISCLOSURES
Accrued interest converted to long-term debt	$	3,269,464		$	2,822,263
Non-cash investment in proved and unproved properties in accounts payable		1,904,486			1,514,623

See notes to unaudited consolidated financial statements.

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NOTE 1—ACCOUNTING POLICIES AND BASIS OF PRESENTATION

Dune Energy, Inc., a Delaware corporation (“Dune” or the “Company”), is an independent energy company that was formed in 1998. Since May 2004, we have been engaged in the exploration, development, exploitation and production of oil and natural gas. Dune sells its oil and gas production primarily to domestic pipelines and refineries. Its operations are presently focused in the states of Texas and Louisiana.

Dune prepared these financial statements according to the instructions for Form 10-Q. Therefore, the financial statements do not include all disclosures required by generally accepted accounting principles in the United States. However, Dune has recorded all transactions and adjustments necessary to fairly present the financial statements included in this Form 10-Q. The adjustments made are normal and recurring. The following notes describe only the material changes in accounting policies, account details or financial statement notes during the first six months of 2013. Therefore, please read these financial statements and notes to the financial statements together with the audited financial statements and notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2012. The income statement for the six months ended June 30, 2013 cannot necessarily be used to project results for the full year.

Financial Restructuring

On December 22, 2011, the Company completed its financial restructuring (the “Restructuring”). The Restructuring was accounted for as a purchase and was effective December 22, 2011. However, due to the immateriality of the nine day activity period from December 23, 2011 through December 31, 2011, the Restructuring was treated for accounting purposes as effective December 31, 2011. The Restructuring resulted in a new basis of accounting reflecting estimated fair values for assets and liabilities at December 22, 2011. Accordingly, the financial statements for the periods subsequent to December 31, 2011 are presented on the Company’s new basis of accounting.

Revenue recognition

Dune records oil and gas revenues following the entitlement method of accounting for production in which any excess amount received above Dune’s share is treated as a liability. If less than Dune’s share is received, the underproduction is recorded as an asset. Dune did not have an imbalance position in terms of volumes or values at June 30, 2013. Additionally, Dune records the sale of emission credits as other revenue in the period they are sold.

Loss per share

Basic earnings per share amounts are calculated based on the weighted average number of shares of common stock outstanding during each period. Diluted earnings per share is based on the weighted average numbers of shares of common stock outstanding for the periods, including dilutive effects of stock options and warrants granted. Dilutive options and warrants that are issued during a period or that expire or are canceled during a period are reflected in the computations for the time they were outstanding during the periods being reported. Since Dune has incurred losses for all periods, the impact of the common stock equivalents would be antidilutive and therefore are not included in the calculation.

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NOTE 2—DEBT FINANCING

Long-term debt consists of:

	June 30, 2013			December 31, 2012
Revolving credit loan	$	20,000,000		$	28,000,000
Insurance note payable		231,935			1,623,541
Floating Rate Senior Secured Notes due 2016		58,699,326			55,429,862
Total long-term debt		78,931,261			85,053,403
Less: current maturities		(231,935	)		(1,623,541	)
Long-term debt, net of current maturities	$	78,699,326		$	83,429,862

Credit Agreement

On December 22, 2011, concurrent with our Restructuring, Wayzata assigned to Bank of Montreal its rights and obligations under our existing Credit Agreement pursuant to an agreement, by and among the Company and Dune Properties, Inc., as borrowers, Dune Operating Company, as guarantor, and Wells Fargo and Wayzata, as agents and lenders. In connection with such assignment, on December 22, 2011, the Company entered into the Amended and Restated Credit Agreement, dated as of December 22, 2011 (the “New Credit Agreement”), among the Company, as borrower, Bank of Montreal, as administrative agent, CIT Capital Securities LLC, as syndication agent, and the lenders party thereto (the “Lenders”).

The New Credit Agreement will mature on December 22, 2015. The Lenders have committed to provide up to $200 million of loans and up to $10 million of letters of credit, provided that the sum of the outstanding loans and the face amount of the outstanding letters of credit cannot exceed $200 million at any time and further provided that the availability of loans under the New Credit Agreement will be limited by a borrowing base (initially set at $63 million and reduced to $50 million as of May 1, 2012) as in effect from time to time, which is determined by the Lenders at their discretion based upon their evaluation of the Company’s oil and gas properties. The principal balance of the loans may be prepaid at any time, in whole or in part, without premium or penalty, except for losses incurred by the Lenders as a consequence of such prepayment. Amounts repaid under the New Credit Agreement may be reborrowed.

The New Credit Agreement contains various affirmative and negative covenants as well as other customary representations and warranties and events of default.

On September 25, 2012, the parties entered into an Amendment to the New Credit Agreement. Prior to the amendment, the New Credit Agreement provided that the Company would not, as of the last day of any fiscal quarter, permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than 4.0 to 1.0. The Amendment to the New Credit Agreement provided that the Company will not, as of the last day of the fiscal quarter ending September 30, 2012 or December 31, 2012, permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than 5.0 to 1.0. On March 31, 2013, and thereafter, the Company would not, as of the last day of the fiscal quarter, permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than 4.0 to 1.0. An amendment fee of $100,000 was paid for this change.

On May 3, 2013, the parties entered into the Second Amendment to the New Credit Agreement. The Second Amendment to the New Credit Agreement provided that the Company will not, as of the last day of the fiscal quarter ending March 31, 2013 permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than 5.0 to 1.0. It further provides that the Company will not, as of the last day of the fiscal quarter ending June 30, 2013 permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than

5

4.5 to 1.0. On September 30, 2013, and thereafter, the Company will not, as of the last day of the fiscal quarter, permit its ratio of Total Debt as of such day to EBITDAX for the immediately preceding four fiscal quarters ending on such day to be greater than 4.0 to 1.0. An amendment fee of $100,000 was paid for this change.

Borrowings under the New Credit Agreement equaled $20.0 million and $2 million of letters of credit as of June 30, 2013.

Restructuring of Senior Secured Notes

On December 22, 2011, the Company completed its restructuring, which included the consummation of the exchange of $297,012,000 aggregate principal amount, or approximately 99%, of the Senior Secured Notes for 2,485,616 shares of the Company’s newly issued common stock, 247,506 shares of a new series of preferred stock that mandatorily converted into 35,021,098 shares of the Company’s newly issued common stock and approximately $49.5 million aggregate principal amount of newly issued Floating Rate Senior Secured Notes due 2016 (the “New Notes”). In addition to completing the exchange offer for the Senior Secured Notes, the Company completed a consent solicitation of the holders of the Senior Secured Notes, in which it procured the requisite consent of the holders of approximately 99% of the aggregate principal amount of the Senior Secured Notes to eliminate all the restrictive covenants and certain events of default in the Indenture.

The New Notes were issued pursuant to an indenture, dated December 22, 2011 (the “New Notes Indenture”), by and among the Company, the guarantors named therein and U.S. Bank National Association, as trustee and collateral agent. The New Notes will mature on December 15, 2016. The Company did not receive any proceeds from the issuance of the New Notes.

Interest on the New Notes is payable quarterly in arrears on March 15, June 15, September 15 and December 15 of each year, beginning on March 15, 2012. Subject to applicable law, interest accrues on the New Notes at a variable rate per annum equal to 13% plus the greater of 1.5% and Three-Month LIBOR, determined as of two London banking days prior to the original issue date and reset quarterly on each interest payment date. Such interest consists of (a) a mandatory cash interest component (that shall accrue at a fixed rate of 3% per annum and be payable solely in cash) and (b) a component that shall accrue at a variable rate and be payable in either cash or by accretion of principal. As of June 30, 2013, the Company has elected to increase the aggregate principal amount of the New Notes by a cumulative amount of $9,195,335 in lieu of making cash quarterly interest payments, including $3,269,464 during the six months ended June 30, 2013. This results in an outstanding balance of $58,699,326.

NOTE 3—COMMON STOCK SALE

On December 21, 2012, the Company issued 18,749,997 shares of its common stock to the Company’s major stockholders (the “Investors”), pursuant to a Stock Purchase Agreement (collectively the “Stock Purchase Agreements” and such transaction the “Financing”) between the Company and each such stockholder, resulting in gross proceeds to the Company of $30,000,000. Upon our election, and subject to our meeting certain performance objectives, we could conduct two additional closings with the Investors prior to December 31, 2013 (each a “Subsequent Closing”). In each Subsequent Closing, we would issue up to 6,250,000 shares of our common stock at a purchase price of $1.60 per share or a total purchase price of up to $10,000,000. The Investors could also elect to require us to conduct a closing in which we will issue the remaining shares to be issued in the Financing, upon the occurrence of certain events specified in the Stock Purchase Agreements. In the Financing, each of the Investors received a “Preemptive Right” to purchase such investor’s pro rata percentage of new stock or new debt financings (excluding certain reserve based revolver financings) undertaken by Dune, on substantially the same terms as offered to any outside investor.

On May 8, 2013, pursuant to the terms of the Stock Purchase Agreements, the Company conducted a Subsequent Closing with the Investors in which the Company issued 6,249,996 shares of its common stock, resulting in gross proceeds to the Company of $10,000,000.

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On June 28, 2013, pursuant to the terms of the Stock Purchase Agreements, the Company conducted the final Subsequent Closing with the Investors in which the Company issued 6,249,996 shares of its common stock, resulting in gross proceeds to the Company of $10,000,000.

NOTE 4—OIL AND GAS COMMODITY DERIVATIVES

In accordance with the requirements of the New Credit Agreement entered into in connection with the Restructuring, the Company entered into hedge agreements in January 2012. All derivative contracts are recorded at fair market value in accordance with FASB ASC 815 and ASC 820 and included in the consolidated balance sheets as assets or liabilities. The Company did not designate derivative instruments as accounting hedges and recognizes gains or losses on the change in fair value of the hedge instruments in current earnings.

For the three and six months ended June 30, 2013, Dune recorded a gain (loss) on the derivatives of $510,288 and ($307,302) composed of an unrealized gain (loss) on changes in mark-to-market valuations of $510,288 and ($332,000) and a realized gain on cash settlements of $-0- and $24,698, respectively.

DUNE ENERGY, INC.

Current Hedge Positions as of June 30, 2013

Crude Trade Details

Instrument	Beginning Date		Ending Date		Floor		Ceiling		Fixed		Total Bbls 2013		Bbl/d		Total Bbls 2014		Bbl/d		Total Volumes
Collar		01/01/13		12/31/13	$	92.00	$	104.60				84,000		457		—		—		84,000
Collar		01/01/14		12/31/14	$	90.00	$	99.00				—		—		137,000		375		137,000
												84,000		457		137,000		375		221,000
										Days		184				365
Hedged Daily Production (Bbl)												457				375
Natural Gas Trade Details
Instrument	Beginning Date		Ending Date		Floor		Ceiling		Fixed		Total Mmbtu 2013		Mmbtu/d		Total Mmbtu 2014		Mmbtu/d		Total Volumes
Collar		01/01/13		12/31/13	$	3.50	$	4.42				311,000		1,690		—		—		311,000
Collar		01/01/14		12/31/14	$	3.75	$	5.01				—		—		619,000		1,696		619,000
												311,000		1,690		619,000		1,696		930,000
										Days		184				365
Hedged Daily Production (Mmbtu)												1,690				1,696

NOTE 5—RESTRICTED STOCK, STOCK OPTIONS AND WARRANTS

The Company utilizes restricted stock, stock options and warrants to compensate employees, officers, directors and consultants. Total stock-based compensation expense including options, warrants and restricted stock was $656,284 and $1,288,589 for the three and six months ended June 30, 2013 and $374,931 and $1,028,225 for the three and six months ended June 30, 2012, respectively.

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The 2007 Stock Incentive Plan, which was approved by Dune’s stockholders, authorizes the issuance of up to 32,000 shares of common stock to employees, officers and non-employee directors. The Plan is administered by the Compensation Committee of Dune’s board of directors. The following table reflects the vesting activity associated with the 2007 Stock Incentive Plan at June 30, 2013:

Grant Date	Shares Awarded		Shares Canceled			Shares Vested			Shares Unvested
December 17, 2007		2,486		(715	)		(1,771	)		—
March 13, 2008		1,054		—			(1,054	)		—
August 1, 2008		6,227		(1,114	)		(5,113	)		—
October 1, 2009		4,500		(1,485	)		(3,015	)		—
December 31, 2009		5,738		(1,542	)		(4,196	)		—
November 8, 2010		9,389		(748	)		(5,815	)		2,826
December 30, 2010		44		—			(44	)		—
		29,438		(5,604	)		(21,008	)		2,826

Common shares available to be awarded at June 30, 2013 are as follows:

Total shares authorized	32,000
Total shares issued	(29,438	)
Total shares canceled	5,604
Total shares available	8,166

Pursuant to a unanimous written consent dated March 5, 2012, the board of directors of the Company authorized the adoption of the Dune Energy, Inc. 2012 Stock Incentive Plan (the “2012 Plan”), to become effective immediately. The 2012 Plan is administered by the Compensation Committee of Dune’s board of directors. Under the 2012 Plan, the Compensation Committee may grant any one or a combination of incentive options, non-qualified stock options, restricted stock, stock appreciation rights and phantom stock awards, as well as purchased stock, bonus stock and other performance awards. The aggregate number of shares of common stock that may be issued or transferred to grantees under the Plan could not exceed 3,250,000 shares. On April 25, 2013, the Company’s board of directors approved an amendment to the Company’s 2012 Plan. The Plan amendment provides for an increase of 1,750,000 in the number of authorized shares in the Plan from 3,250,000 to 5,000,000. This amendment was subsequently approved by Dune’s shareholders.

In January 2013, two members of the Company’s board of directors resigned. In connection with an amendment to these two directors’ option agreements that were entered into in connection with their respective resignations, all unvested stock options issued to these individuals, amounting to 133,334 shares of common stock, vested immediately.

In February 2013, the Company issued 103,978 shares of common stock related to 50% of the 2012 annual bonus for an officer of the Company. The restricted common stock was equal to 125% of the cash bonus to be paid and will vest over three years from the date of grant. The fair value of the restricted stock grant was $227,712.

On April 25, 2013, the board unanimously approved the grant to each of the six non-employee directors of 57,803 deferred stock units (a total of $100,000 worth of deferred stock units at a price of $1.73 per share per director) as recommended by the Compensation Committee. With respect to each director, subject to each director’s continuous service to the Company, the units vest over a two year period with one-third vesting immediately and the remaining two-thirds vesting ratably on the anniversary date in subsequent years. The Company will issue to each director one share of common stock on the settlement date for each vested unit held by the director. The settlement date will be the first to occur (i) the fifth anniversary of the date of grant and (ii) a Change of Control (as defined in the deferred stock unit agreement).

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The following table reflects the vesting activity associated with the 2012 Plan:

Grant Date	Shares Awarded		Shares Canceled			Shares Vested			Shares Unvested
March 5, 2012 stock options		600,000		—			(466,668	)		133,332
March 5, 2012 stock grants		831,500		(82,365	)		(213,880	)		535,255
October 1, 2012 stock grants		225,000		—			—			225,000
December 3, 2012 stock grants		659,933		(4,900	)		—			655,033
February 20, 2013 stock grant		103,978		—			—			103,978
April 25, 2013 deferred stock units		346,818		—			(115,608	)		231,210
		2,767,229		(87,265	)		(796,156	)		1,883,808

Common shares available to be awarded at June 30, 2013 are as follows:

Total shares authorized	5,000,000
Total shares issued	(2,767,229	)
Total shares canceled	87,265
Total shares available	2,320,036

NOTE 6— INCOME TAXES

Dune is in a position of cumulative reporting losses for the current and preceding reporting periods. The volatility of energy prices and uncertainty of when energy prices may rebound is not readily determinable by management. At this date, this general fact pattern does not allow the Company to project sufficient sources of future taxable income to offset tax loss carry forwards and net deferred tax assets. Under these current circumstances, it is management’s opinion that the realization of these tax attributes does not reach the “more likely than not criteria” under FASB ASC 740—Income Taxes. As a result, the Company’s taxes through June 30, 2013 are subject to a full valuation allowance.

During 2011, the Company negotiated a workout of certain debt obligations and as a result, a change of control pursuant to Section 382 of the Internal Revenue Code of 1986, as amended, occurred. Accordingly, the Company will be limited to utilizing a portion of the NOL’s to offset taxable income generated by the Company during the tax year ended December 31, 2013 and future years until the NOL’s are completely exhausted or expire unutilized. The amount of the limitation is estimated to be less than $1 million annually.

NOTE 7—FAIR VALUE MEASUREMENTS

Certain assets and liabilities are reported at fair value on a recurring basis in Dune’s consolidated balance sheet. The following table summarizes the valuation of our investments and financial instruments by FASB ASC 820-10-05 pricing levels as of June 30, 2013:

	Fair Value Measurements at June 30, 2013 Using
	Level 1		Level 2		Level 3		Total
Oil and gas derivative assets	$	—	$	831,878	$	—	$	831,878
Oil and gas derivative liabilities		—		—		—		—
Total	$	—	$	831,878	$	—	$	831,878

NOTE 8—COMMITMENTS AND CONTINGENCIES

The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment.

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These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. Dune maintains insurance coverage, which it believes is customary in the industry, although Dune is not fully insured against all environmental risks.

In connection with the acquisition of Goldking, the Company inherited an environmental contingency, which after conducting its due diligence and subsequent testing, the Company believes is the responsibility of a third party. However, federal and state regulators have determined Dune is the responsible party for cleanup of this area. Dune has maintained a passive maintenance of this site since it was first discovered after Hurricane Katrina. Cost to date of approximately $2,100,000 has been incurred by the Company minus insurance proceeds of $1,000,000. The Company still believes another party has the primary responsibility for this occurrence but is committed to working with the various state and federal authorities on resolution of this issue. Plans for testing and analysis of various containment products and remediation procedures by third party consultants are being reviewed and will be presented to the federal and state authorities for consideration in 2013. The possible cost of an acceptable containment product, assuming potential remediation programs are viable and acceptable to all involved parties, may be as much as $2,500,000 to $3,000,000 over a several year time frame. At this time, it is not known if the Company’s insurance will continue to cover the cleanup costs or if the Company can be successful in proving another party should be primarily responsible for the cost of remediation.

Subsequent to the end of the second quarter ended June 30, 2013 and during the drilling of the Leeville SL 20783 well, mechanical problems were encountered above the 19,000 feet drilling depth. A hole was discovered in the casing at around 7,400 feet that required well-control attention. Drilling was halted and the situation is currently in the process of being resolved. Dune’s share of the drilling of the well to date is approximately $5.2 million. The well bore is insured with the exception of a $100,000 deductible. We are currently involved in discussions with our insurance providers with respect to the alternatives available to continue with the drilling and completion of the well. At this time, management cannot predict which option will be selected.

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

The following discussion will assist in the understanding of our financial position and results of operations. The information below should be read in conjunction with the consolidated financial statements, the related notes to consolidated financial statements and our Annual Report on Form 10-K for the year ended December 31, 2012. Our discussion contains both historical and forward-looking information. We assess the risks and uncertainties about our business, long-term strategy and financial condition before we make any forward-looking statements but we cannot guarantee that our assessment is accurate or that our goals and projections can or will be met. Statements concerning results of future exploration, exploitation, development and acquisition expenditures as well as revenue, expense and reserve levels are forward-looking statements. We make assumptions about commodity prices, drilling results, production costs, administrative expenses and interest costs that we believe are reasonable based on currently available information.

Our primary focus will continue to be the development and exploration efforts in our Gulf Coast properties. We believe that our acreage position will allow us to grow organically through low risk drilling in the near term. This position continues to present attractive opportunities to expand our reserve base through field extensions and high risk/high reward exploratory drilling opportunities. In addition, we will constantly review, rationalize and “high-grade” our properties in order to optimize our existing asset base.

We expect to maintain and utilize our technical and operations teams’ knowledge of salt-dome structures and multiple stacked producing zones common in the Gulf Coast to enhance our growth prospects and reserve potential. We expect to employ technical advancements, including 3-D seismic data, pre-stack depth migration and directional drilling, to identify and exploit new opportunities in our asset base.We also plan to employ the latest drilling and completion technology in all of our wells to enhance recoverability and accelerate cash flows associated with these wells.

We continually review opportunities to acquire producing properties, leasehold acreage and drilling prospects that are in core operating areas. We are seeking to acquire operational control of properties that we believe have a solid proved reserve base coupled with significant exploitation and exploration potential.

Liquidity and Capital Resources

During the first six months of 2013 compared to the first six months of 2012, net cash flow provided by operations reflected a decrease of $2.4 million to $10.9 million. This decrease is primarily attributable to the fluctuation in accounts payable and accrued liabilities between periods.

Our current assets were $26.3 million on June 30, 2013. Cash on hand comprised approximately $16.2 million of this amount. This compared to $22.8 million in cash at the end of calendar year 2012 and $8.9 million at the end of the second quarter of 2012. Accounts payable have increased from $7.0 million at year end 2012 to $10.4 million at June 30, 2013. Accounts payable were $12.5 million at June 30, 2012. This increase in payables and decreases in cash on hand from the calendar year 2012 reflects the impact of additional capital spending in the first two quarters of 2013.

Our capital investments and exploration costs year-to-date reflect our ongoing drilling and facilities upgrade program which amounted to $29.0 million during the first six months of 2013, up from $19.2 million spent during the same period of 2012. The increased spending reflected continued drilling activity at Garden Island Bay and Leeville fields. We expect to spend approximately $24 million (including dry-hole costs) during the final six months of 2013 on continuing development, exploitation and exploration associated with high potential opportunities within our asset base. Based on this plan, the capital investments and exploration costs for the year would total approximately $53 million. This would represent a $26 million increase over our $27 million of capital investment and exploration costs in 2012. However, this anticipated capital investment may be reduced or increased depending on available cash flow. Because we operate the majority of our properties, we can control to some extent the timing of expenditures.

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On December 21, 2012, the Company issued 18,749,997 shares of its common stock to the Company’s major stockholders (the “Investors”), pursuant to a Stock Purchase Agreement (collectively the “Stock Purchase Agreements” and such transaction the “Financing”) between the Company and each such stockholder, resulting in gross proceeds to the Company of $30,000,000. Upon our election, and subject to our meeting certain performance objectives, we could conduct two additional closings with the Investors prior to December 31, 2013 (each a “Subsequent Closing”). In each Subsequent Closing, we would issue up to 6,250,000 shares of our common stock at a purchase price of $1.60 per share or a total purchase price of up to $10,000,000. The Investors could also elect to require us to conduct a closing in which we will issue the remaining shares to be issued in the Financing, upon the occurrence of certain events specified in the Stock Purchase Agreements. In the Financing, each of the Investors received a “Preemptive Right” to purchase such investor’s pro rata percentage of new stock or new debt financings (excluding certain reserve based revolver financings) undertaken by Dune, on substantially the same terms as offered to any outside investor.

On May 8, 2013, pursuant to the terms of the Stock Purchase Agreements, the Company conducted a Subsequent Closing with the Investors in which the Company issued 6,249,996 shares of its common stock, resulting in gross proceeds to the Company of $10,000,000.

On June 28, 2013, pursuant to the terms of the Stock Purchase Agreements, the Company conducted the final Subsequent Closing with the Investors in which the Company issued 6,249,996 shares of its common stock, resulting in gross proceeds to the Company of $10,000,000.

Our primary sources of liquidity are cash provided by operating activities, debt financing, sales of non-core properties and access to capital markets. The total Debt to EBITDAX covenant in our current revolving credit agreement controls access to the “undrawn” amount of borrowing availability from quarter to quarter and is based on the trailing 12 month total. As a result, any given month within the 12 month calculation period, such as that experienced during the first two months of 2013, will have a lingering impact on future quarterly EBITDAX determinations until those months are no longer included. For the second quarter of 2013, the EBITDAX covenant stipulates that the ratio of total Debt to EBITDAX be less than 4.5 to 1.0; for the prior three quarters the requirement was 5.0 to 1.0. By the end of the third quarter of 2013, this covenant benchmark is set at less than 4.0 to 1.0. Current indications suggest that the Company should remain in compliance with this covenant for the remainder of the year. However, any operational delays or failures that impact expected production volumes or timing may have an adverse effect on our ability to meet this calculation. We monitor our financial progress very carefully and attempt to adjust our available projects in order to meet all of the covenants of the credit agreement.

The exact amount of capital spending for 2013 will depend upon individual well performance results; cash flow; availability and scheduling of drilling operations; and partner agreement on timing and planning of joint drilling obligations. Currently, we expect that a significant portion of our 4th quarter 2013 budget will be dedicated to our Garden Island Bay field. However, this will be subject to the intentions of our majority partners in the Leeville field. Should our partners decide to pursue a drilling schedule that is more aggressive than currently presumed, the resulting AFE’s for our share of the expenditures may force us to either forfeit our interest in this program or delay our drilling activity at Garden Island Bay. As Leeville has been a successful venture thus far, delaying Garden Island Bay projects would likely occur. In the meantime, we are targeting a total capital budget of approximately $50 to $55 million in calendar 2013, which is below our prior forecast of $73 million with an original budget of $64 million. The less ambitious target is set so as to ensure that the Company stays within the covenant restrictions of our credit agreement. Near term drilling will occur in our Chocolate Bayou and Live Oak fields, where we have opportunities to significantly increase production volumes for relatively low overall investments. Investments later in the third quarter and through the fourth quarter will focus on the Garden Island Bay field and possibly the Leeville field should our partners be so inclined. As always, gains in production volumes will significantly drive EBITDAX increases, which should then provide for increased borrowing availability under our revolver.

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Results of Operations

Year-over-year production decreased from 2,757 Mmcfe for the first six months of 2012 to 2,396 Mmcfe for the same six month period of 2013. This decrease was caused by normal reservoir declines which were not offset by increased production.

The following table reflects the decrease in oil and gas sales revenue due to the changes in prices and volumes:

	Three Months Ended June 30,								Six Months Ended June 30,
	2013			% Change			2012		2013			% Change			2012
Oil production volume (Mbbls)		135			29	%		105		232			13	%		205
Oil sales revenue ($000)	$	14,075			27	%	$	11,090	$	24,749			12	%	$	22,053
Price per Bbl	$	104.26			-1	%	$	105.62	$	106.68			-1	%	$	107.58
Increase (decrease) in oil sales revenue due to:
Change in production volume	$	3,169							$	2,905
Change in prices		(184	)							(209	)
Total increase in oil sales revenue	$	2,985							$	2,696
Gas production volume (Mmcf)		616			-18	%		750		1,006			-34	%		1,529
Gas sales revenue ($000)	$	2,709			34	%	$	2,017	$	4,156			-7	%	$	4,449
Price per Mcf	$	4.40			64	%	$	2.69	$	4.13			42	%	$	2.91
Increase (decrease) in gas sales revenue due to:
Change in production volume	$	(360	)						$	(1,522	)
Change in prices		1,052								1,229
Total increase (decrease) in gas sales revenue	$	692							$	(293	)
Total production volume (Mmcfe)		1,424			3	%		1,382		2,396			-13	%		2,757
Total revenue ($000)	$	16,784			28	%	$	13,107	$	28,905			9	%	$	26,502
Price per Mcfe	$	11.79			24	%	$	9.48	$	12.06			25	%	$	9.61
Increase (decrease) in total revenue due to:
Change in production volume	$	398							$	(3,469	)
Change in prices		3,279								5,872
Total increase in total revenue	$	3,677							$	2,403

We recorded a net loss for the six months ended June 30, 2013 of ($4.6 million) or ($0.07) loss per share compared to net loss of ($2.7 million) or ($0.07) loss per share for the same period of 2012. The increase in loss of $1.9 million is primarily attributable to the reduction of gains on derivative instruments.

Revenues

Oil and Gas Revenues

Revenues from the quarter ended June 30, 2013 totaled $16.8 million compared to $13.1 million for the quarter ended June 30, 2012 representing a $3.7 million increase. Production volumes for 2013 were 135 Mbbls of oil and 0.62 Bcf of natural gas or 1.42 Bcfe. This compares to 105 Mbbls of oil and 0.75 Bcf of natural gas or 1.38 Bcfe representing a 3% increase in production volumes. In 2013, the average sales price per barrel of oil was $104.26 and $4.40 per Mcf of natural gas as compared to $105.62 per barrel and $2.69 per Mcf, respectively for 2012. These results indicate the increase in revenue is attributable to a 29% increase in oil production and a 64% increase in gas prices.

Revenues for the six months ended June 30, 2013 totaled $28.9 million compared to $26.5 million for the six months ended June 30, 2012 representing a $2.4 million increase. Production volumes for 2013 were

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232 Mbbls of oil and 1.01 Bcf of natural gas or 2.40 Bcfe. This compares to 205 Mbbls of oil and 1.53 Bcf of natural gas or 2.76 Bcfe representing a 13% decline in production volumes. In 2013, the average sales price per barrel of oil was $106.68 and $4.13 per Mcf of natural gas as compared to $107.58 per barrel and $2.91 per Mcf, respectively for 2012. These results indicate that the increase in revenue is attributable to a 25% increase in commodity prices which were partially reduced by a 13% decrease in production.

Other revenues

During the six months of 2013, the Company sold volatile organic compound emission credits to a purchaser for $1.0 million. There were no sales of these credits in 2012.

Operating expenses

Lease operating expense and production taxes

The following table presents the major components of Dune’s lease operating expense (in thousands) for the three and six months ended June 30, 2013 and 2012 on a Mcfe basis:

	Three months ended June 30,								Six months ended June 30,
	2013				2012				2013				2012
	Total		Per Mcfe		Total		Per Mcfe		Total		Per Mcfe		Total		Per Mcfe
Direct operating expense	$	5,540	$	3.89	$	4,973	$	3.60	$	10,645	$	4.44	$	9,325	$	3.38
Production taxes		1,733		1.22		1,116		0.81		2,930		1.22		2,170		0.79
Ad valorem taxes		197		0.14		253		0.18		433		0.18		527		0.19
Transportation		299		0.21		330		0.24		594		0.25		685		0.25
Workovers		79		0.06		28		0.02		107		0.04		152		0.06
	$	7,848	$	5.52	$	6,700	$	4.85	$	14,709	$	6.13	$	12,859	$	4.67

Lease operating expense for the quarter ended June 30, 2013 totaled $7.8 million versus $6.7 million for the same period of 2012. This translated to a 14% increase quarter-over-quarter on a sales volume basis from $4.85/Mcfe to $5.52/Mcfe.

Lease operating expense for the six months ended June 30, 2013 totaled $14.7 million versus $12.9 million for the same period of 2012. This translated into an increase of $1.46/Mcfe on a volume basis.

Accretion of asset retirement obligation

Accretion expense for asset retirement obligations increased by $0.04 million for the quarter ended June 30, 2013 compared to the same period in 2012. Similarly, accretion expense for the six month period ended June 30, 2013 reflected a $0.07 million increase from the comparable period of 2012. This small increase is the result of reevaluating abandonment costs at year end.

Depletion, depreciation and amortization (DD&A)

For the quarter ended June 30, 2013, the Company recorded DD&A expense of $4.8 million ($3.37/Mcfe) compared to $5.0 million ($3.62/Mcfe) for the quarter ended June 30, 2012 representing a decrease of $0.2 million ($0.25/Mcfe). Additionally, for the six months ended June 30, 2013, the Company recorded DD&A expense of $8.0 million ($3.34/Mcfe) compared to $9.3 million ($3.37/Mcfe) for the six months ended June 30, 2012 representing a decrease of $1.3 million ($0.03/Mcfe). This six month decrease reflects the impact of the reduction in production volumes that directly impacts the DD&A calculation.

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General and administrative expense (G&A expense)

G&A expense for the current quarter ended 2013 increased $0.8 million (35%) from the comparable 2012 quarter to $3.1 million. Cash G&A expense for 2013 increased $0.5 million (27%) from 2012 to $2.5 million. This increase resulted principally from additional stock-based compensation.

For the six months ended June 30, 2013 and 2012, G&A expense increased $0.3 million (6%) to $5.7 million. Cash G&A expense for the first half of 2013 did not fluctuate and remained at $4.4 million.

Gain (loss) on settlement of asset retirement obligation liability

A loss on the settlement of asset retirement obligations of $0.5 million was incurred in second quarter of 2012. Additionally, a loss of $0.9 million was incurred in the six months ended June 30, 2012. These amounts result from the acceleration of plugging and abandonment costs that were projected to occur in a future period. There were limited plugging and abandonment projects in 2013 which did not yield a gain or loss.

Other income (expense)

Other income

Other income which includes interest income, is minimal as a result of using the Company’s cash balances to support working capital.

Interest expense

Interest expense remained constant at $2.4 million for the quarter ended June 30, 2013 compared to the same quarter ended June 30, 2012. Similarly, interest expense did not fluctuate for the first six months of 2013 compared to 2012 amounting to just under $5.0 million. Although interest expense increased on the Senior Secured Notes as a result of the accretion of the principal, this increase was offset by a reduction of interest expense on the revolving credit loan due to a reduction in the outstanding balance to $20 million at June 30, 2013.

Gain (loss) on derivative instruments

For the quarters ended June 30, 2013 and June 30, 2012, the Company incurred a gain on derivatives of $0.5 million and $5.0 million composed of an unrealized gain of $0.5 million and $4.5 million due to the change in the mark-to-market valuation and a realized gain of $-0- and $0.5 million for cash settlements, respectively.

For the six months ended June 30, 2013 and June 30, 2012, the Company incurred a gain (loss) on derivatives of ($0.3 million) and $4.7 million composed of an unrealized gain (loss) of ($0.3 million) and $4.0 million due to the change in mark-to-market valuation and a realized gain of $-0- and $0.7 million for cash settlements, respectively.

Net income (loss)

For the quarter ended June 30, 2013, net income (loss) decreased ($2.2 million) from the comparable quarter of 2012. This decrease reflects the impact of a ($4.5) reduction in gain on derivative instruments, a ($1.1 million) increase in lease operating expense and production taxes and a ($0.8 million) increase in G&A expense partially offset by a $3.7 million increase in revenues.

For the six months ended June 30, 2013, net income (loss) decreased ($1.9 million) from the comparable 2012 period. This decrease reflects the impact of a ($5.0 million) reduction in gain on derivative instruments, a ($1.8 million) increase in lease operating expense partially offset by a $3.4 million increase in revenues and a $1.3 million reduction in DD&A expense.

15

Item 4. Controls and Procedures.

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Exchange Act reports is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure based closely on the definition of “disclosure controls and procedures” in Rule 13a-15(e). In designing and evaluating the disclosure controls and procedures, management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

At the end of the period covered by this quarterly report, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon the foregoing, our Chief Executive Officer and Chief Financial Officer concluded that, as of June 30, 2013, our disclosure controls and procedures are effective.

During the quarter ended June 30, 2013, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II

OTHER INFORMATION

Item 6. Exhibits

(a) Exhibits

Exhibit Nos.	Description
3.1	Amended and Restated Certificate of Incorporation (1)
3.1.1	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated May 7, 2003 (2)
3.1.2	Certificate of Amendment of Certificate of Incorporation, dated May 5, 2004 (3)
3.1.3	Certificate of Amendment of Certificate of Incorporation, dated June 12, 2007 (4)
3.1.4	Certificate of Amendment of Certificate of Incorporation, dated December 14, 2007 (5)
3.1.5	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated December 1, 2009 (6)
3.1.6	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated December 22, 2011 (7)
3.2	Amended and Restated By-Laws of Dune Energy, Inc. (8)
10.1	Form of Indemnification Agreement (9)
10.2	Second Amendment to Amended and Restated Credit Agreement among the Company, certain of the lenders party to the Amended and Restated Credit Agreement dated as of December 22, 2011, and Bank of Montreal as administrative agent for the lenders (10)
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 pursuant to 18 U.S.C. 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by Chief Executive Officer.
32.2*	Certification pursuant to 18 U.S.C. 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by Chief Financial Officer.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

* Filed herewith

(1) Incorporated by reference to Exhibit 3.1 to the Registrant’s Form 10-KSB (File No. 001-32497) for the year ended December 31, 2002

(2) Incorporated by reference to Exhibit 3.1.1 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

17

(3) Incorporated by reference to Exhibit No. 3.1 to the Registrant’s Form 10-Q (File No. 001-32497) for the quarterly period ended March 31, 2007.

(4) Incorporated by reference to Exhibit 3.1.3 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

(5) Incorporated by reference to Exhibit 3.1.4 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

(6) Incorporated by reference to Exhibit No. 3.1.2 to the Registrant’s Form 8-K (File No. 001-32497) filed on December 1, 2009.

(7) Incorporated by reference to Exhibit 3.2 to the Registrant’s Form 8-K (File No. 001-32497) filed on December 27, 2011.

(8) Incorporated by reference to Exhibit No. 3.1 to the Registrant’s Form 8-K (File No. 001-32497) filed on July 12, 2010.

(9) Incorporated by reference to Exhibit 10.1 to the Registrant’s Form 8-K (File No. 000-27897) filed on April 29, 2013.

(10) Incorporated by reference to Exhibit 10.2 to the Registrant’s Form 8-K (File No. 000-27897) filed on May 3, 2013.

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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.

	DUNE ENERGY, INC.
Date: August 7, 2013	By:	/S/    JAMES A. WATT
	Name:	James A. Watt
	Title:	President and Chief Executive Officer
Date: August 7, 2013	By:	/S/    FRANK T. SMITH, JR.
	Name:	Frank T. Smith, Jr.
	Title:	Chief Financial Officer

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INDEX TO EXHIBITS

Exhibit Nos.	Description
3.1	Amended and Restated Certificate of Incorporation (1)
3.1.1	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated May 7, 2003 (2)
3.1.2	Certificate of Amendment of Certificate of Incorporation, dated May 5, 2004 (3)
3.1.3	Certificate of Amendment of Certificate of Incorporation, dated June 12, 2007 (4)
3.1.4	Certificate of Amendment of Certificate of Incorporation, dated December 14, 2007 (5)
3.1.5	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated December 1, 2009 (6)
3.1.6	Certificate of Amendment of Amended and Restated Certificate of Incorporation, dated December 22, 2011 (7)
3.2	Amended and Restated By-Laws of Dune Energy, Inc. (8)
10.1	Form of Indemnification Agreement (9)
10.2	Second Amendment to Amended and Restated Credit Agreement among the Company, certain of the lenders party to the Amended and Restated Credit Agreement dated as of December 22, 2011, and Bank of Montreal as administrative agent for the lenders (10)
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 pursuant to 18 U.S.C. 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by Chief Executive Officer.
32.2*	Certification pursuant to 18 U.S.C. 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, by Chief Financial Officer.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

* Filed herewith

(1) Incorporated by reference to Exhibit 3.1 to the Registrant’s Form 10-KSB (File No. 001-32497) for the year ended December 31, 2002

(2) Incorporated by reference to Exhibit 3.1.1 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

(3) Incorporated by reference to Exhibit No. 3.1 to the Registrant’s Form 10-Q (File No. 001-32497) for the quarterly period ended March 31, 2007.

20

(4) Incorporated by reference to Exhibit 3.1.3 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

(5) Incorporated by reference to Exhibit 3.1.4 to the Registrant’s Form 10-K (File No. 001-32497) for the year ended December 31, 2010.

(6) Incorporated by reference to Exhibit No. 3.1.2 to the Registrant’s Form 8-K (File No. 001-32497) filed on December 1, 2009.

(7) Incorporated by reference to Exhibit 3.2 to the Registrant’s Form 8-K (File No. 001-32497) filed on December 27, 2011.

(8) Incorporated by reference to Exhibit No. 3.1 to the Registrant’s Form 8-K (File No. 001-32497) filed on July 12, 2010.

(9) Incorporated by reference to Exhibit 10.1 to the Registrant’s Form 8-K (File No. 000-27897) filed on April 29, 2013.

(10) Incorporated by reference to Exhibit 10.2 to the Registrant’s Form 8-K (File No. 000-27897) filed on May 3, 2013.

21