UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549




FORM 8–K

CURRENT REPORT

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


Date of Report (Date of Earliest Event Reported):  August 8, 2013 (August 7, 2013)

CRIMSON EXPLORATION INC.
(Exact Name of Registrant as Specified in Charter)


Delaware
(State or Other Jurisdiction of Incorporation)
001-12108
(Commission File Number)
20-3037840
(IRS Employer Identification No.)


717 Texas Ave., Suite 2900, Houston Texas 77002
(Address of Principal Executive Offices)

(713) 236-7400
(Registrant’s telephone number, including area code)

_____________________________________________________________________________
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):


[]  Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
[]  Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
[]  Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 14d-2(b))
[]  Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))



 

 
 

 

Item 2.02Results of Operations and Financial Condition.
 
On August 7, 2013, Crimson Exploration Inc. issued a press release announcing financial results for the second quarter ended June 30, 2013.  The press release is included in this report as Exhibit 99.1.
 
As provided in General Instruction B.2. of Form 8-K, the information furnished pursuant to Item 2.02 in this report on Form 8-K (including the press release attached as Exhibit 99.1 incorporated by reference in this report) shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section, nor shall such information be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.
 
Item 9.01Financial Statements and Exhibits.
 
(d)  
Exhibits


Exhibit Number
Description
99.1
Press Release dated August 7, 2013

 
2

 


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 hereunto duly authorized.

   
CRIMSON EXPLORATION INC.
     
Date:
August 8, 2013
/s/ E. Joseph Grady
   
E. Joseph Grady
   
Senior Vice President and Chief Financial Officer

 
3

 

Exhibit Index

Exhibit Number
Description
99.1
Press Release dated August 7, 2013


 
4

 

EXHIBIT 99.1
Crimson Exploration Announces Second Quarter 2013 Financial Results and Provides Operational Update
HOUSTON, August 7, 2013 (BUSINESS WIRE) -- Crimson Exploration Inc. (NasdaqGM:CXPO) today announced financial results for the second quarter and first six months of 2013 and provides operational update.

Highlights

·  
Revenue of $36.8 million and net income of $0.5 million for the quarter
 
·  
Increased oil and liquids production to 3,974 barrels per day, a 29% volume increase over the prior year quarter, 52.4% more than the previous quarter and 54% of total production
 
·  
Successfully completed the Grace Hall C #1 and the Payne B #1, both targeting the Woodbine formation, at gross IP rates of 989 Boepd and 1,195 Boepd, respectively
 
·  
Successfully completed the Beeler #2H well, our first in the Buda formation in Dimmit County, TX with a gross IP rate of 859 Boepd (89% oil)
 
·  
Committed to a rig for a continuous drilling program in the Buda for the remainder of 2013
 
·  
Entered into a stock for stock merger agreement with Contango Oil & Gas that is conditioned on shareholder approval by both parties

Management Commentary

Allan D. Keel, President and Chief Executive Officer, commented, “In April, Crimson entered into the previously announced proposed stock for stock merger with Contango Oil & Gas, a transaction that we believe will afford Crimson shareholders the opportunity to participate in the value to be created from our asset base by accelerating the drilling and development of our extensive set of oil and liquids rich resource plays.  While we continue to work hard at closing the merger, we were also successful in establishing the Buda formation as another area of meaningful oil rich drilling opportunities.  At a minimum, we intend to keep a rig active for the remainder of the year in each of the Woodbine and Buda plays, and may add another rig to test the Eagle Ford in Madison County, Texas or the James Lime in San Augustine County.”

Merger Status Update

On April 29, 2013, Crimson entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Contango Oil & Gas Company, a Delaware corporation (“Contango”), and Contango Acquisition, Inc., a Delaware corporation and a direct, wholly-owned subsidiary of Contango (“Merger Sub”), providing for a strategic business combination of Crimson and Contango.  Upon the terms and conditions set forth in the Merger Agreement, Merger Sub will be merged with and into Crimson (the “Merger”), with Crimson continuing as a wholly-owned subsidiary of Contango.  The Merger Agreement was approved by each of the board of directors of Crimson and Contango on April 29, 2013.

Subject to the terms and conditions of the Merger Agreement, at the effective time of the Merger (the “Effective Time”), each share of Crimson common stock, par value $0.001 per share, issued and outstanding will be converted into the right to receive 0.08288 shares of common stock, par value $0.04 per share, of Contango (“Contango Common Stock”) or, in the case of fractional shares, cash (without interest) in an amount equal to the product of (i) such fractional part of a share of Contango Common Stock multiplied by (ii) the closing price for a share of Contango Common Stock as reported on the New York Stock Exchange on the first trading day following the date on which the Effective Time occurs (the “Merger Consideration”).

The closing of the Merger is subject to the satisfaction or waiver of certain customary conditions, including, among others, (i) the adoption of the Merger Agreement by Crimson’s stockholders; (ii) the approval by Contango’s stockholders of the issuance of Contango Common Stock in the Merger to Crimson’s stockholders (the “Share Issuance”); (iii) the registration statement on Form S-4 used to register the Contango Common Stock to be issued in the Merger being declared effective by the Securities and Exchange Commission (the “SEC”); (iv) the approval for listing on the New York Stock Exchange of the Contango Common Stock to be issued in the Merger; (v) subject to specified materiality standards, the accuracy of the representations and warranties of, and the performance of all covenants by, the parties; (vi) the absence of a material adverse effect with respect to each of Crimson and Contango; and (vii) the delivery of tax opinions that the Merger will be treated as a “reorganization” within the meaning of Section 368(a) of the Internal Revenue Code.

 
5

 

The Merger Agreement contains certain termination rights for both Crimson and Contango, including, among others, if (i) the Merger is not consummated on or before October 31, 2013; (ii) the requisite approval of the stockholders of either Crimson or Contango is not obtained; and (iii) the other party breaches a representation, warranty or covenant, and such breach results in the failure of closing conditions to be satisfied.  The Merger Agreement further provides that for the payment of a termination fee upon the termination of the Merger Agreement under specified circumstances, including termination by Contango or Crimson as a result of (1) an adverse change in the recommendation of the other party’s board of directors or (2) a third-party’s “superior proposal.”  The termination fee is $7.0 million (if payable by Crimson) and $28.0 million (if payable by Contango).  The Merger Agreement also provides that Crimson or Contango may be required to pay the other party $4.5 million for expense reimbursement if such party’s stockholder approval is not obtained.

Contango and Crimson currently expect the closing of the Merger to occur in September or October of 2013.  However, as the Merger is subject to the satisfaction or waiver of other conditions described in the Merger Agreement, it is possible that factors outside the control of Contango and Crimson could result in the Merger being completed at an earlier time, a later time or not at all.

Summary Financial Results

The Company reported net income of $0.5 million, or $0.01 per basic share, for the second quarter of 2013 compared to net income of $3.9 million, or $0.09 per basic share, for the second quarter of 2012.  Both quarters included special non-recurring items that impact that comparison.  The 2013 quarter includes $1.1 million in special charges to G&A expense related to the merger, a $2.6 million non-cash gain related to the mark-to-market valuation requirement on our commodity price hedges and a $0.8 million leasehold impairment charge. Special items impacting the 2012 quarter were a $4.0 million refund for a portion of 2007-2011 severance taxes received from the State of Texas for certain marketing cost deductions, an unrealized pre-tax gain of $3.0 million related to the mark-to-market valuation requirement on our commodity price hedges and a $0.8 million leasehold impairment charge. Exclusive of these special cash and non-cash items, net income for the 2013 quarter was $0.1 million, compared to a net loss for the second quarter of 2012 of $0.1 million.  Adjusted EBITDAX, as defined below, was $24.9 million in the second quarter of 2013, a 2% decrease over adjusted EBITDAX for the prior year quarter of $25.5 million.  Exclusive of the merger-related charges in 2013 and the severance tax refund in 2012, adjusted EBITDAX for the 2013 quarter would have been $26.0 million compared to $21.4 million for the 2012 quarter.

Revenues for the second quarter of 2013 were $36.8 million compared to revenues of $30.5 million in the second quarter of 2012. Revenue for the quarter benefited from higher production, a higher percentage of oil and liquids production and higher natural gas prices, offset in part by lower natural gas liquids prices.

Production for the second quarter of 2013 was approximately 4.0 Bcfe, or 44.2 Mmcfe per day, compared to production of approximately 3.7 Bcfe, or 40.4 Mmcfe per day, in the second quarter of 2012. Crude oil and natural gas liquids production averaged 3,974 barrels per day for the second quarter, up 29% over the average in the second quarter of 2012. The increase in total production, as well as in crude and liquids production, was a direct result of our continued success in the Woodbine in Madison and Grimes counties, and initial production from our first Buda well in South Texas.

The weighted average field sales price in the second quarter of 2013 (before the effects of realized gains/losses on our commodity price hedges) was $9.01 per Mcfe compared to an average sales price of $7.60 for the second quarter of 2012.  The weighted average realized sales price in the second quarter (including the effects of realized gains/losses on our commodity price hedges) was $9.14 per Mcfe compared to a weighted average realized sales price of $8.30 per Mcfe for the prior year quarter, an increase resulting from the increase in oil and liquids as a percentage of total production and a 31% increase in natural gas prices, offset in part by a 4% decrease in realized oil prices and a 21% decline in natural gas liquids prices.

Direct lease operating expenses for the second quarter of 2013 were $3.3 million, or $0.82 per Mcfe, compared to $3.6 million, or $0.98 per Mcfe, in the second quarter of 2012. Lease operating expenses increased slightly due to the addition of new producing properties, with the improvement in the per unit rate resulting from the addition of those same more cost efficient new properties.

Production and ad valorem tax expenses for the second quarter of 2013 were $2.4 million, or $0.59 per mcfe, compared to a credit of $2.5 million, or ($0.68) per Mcfe in the prior year quarter. The credit in 2012 was due to a $4.0 million refund received from the State of Texas related to allowed marketing cost deductions on certain 2007-2011 severance taxes.

 
6

 

Depreciation, depletion and amortization (“DD&A”) expense for the second quarter of 2013 was $18.6 million, or $4.62 per Mcfe, compared to $14.7 million, or $3.99 per Mcfe, for the second quarter of 2012, with the increase in expense due to higher production and the slightly higher rate resulting from our transition to drilling only higher-margin crude oil wells.

General and administrative expense in the second quarter of 2013 was $6.8 million, or $1.70 per Mcfe, compared to $4.5 million, or $1.23 per Mcfe, in the prior year quarter. Cash general and administrative expenses for the second quarter of 2013, i.e. exclusive of non-cash stock option expense, was $6.1 million, or $1.53 per Mcfe, compared to $3.9 million, or $1.06 per Mcfe, for the second quarter of 2012.  Expenses in the second quarter of 2013 increased primarily due to higher personnel costs and merger-related professional fees.

Capital expenditures for the second quarter of 2013 were $19.3 million, consisting of approximately $15.4 million in Southeast Texas targeting the Woodbine formation and $1.9 million in South Texas targeting the Buda formation. Year to date, Crimson has invested approximately $30.4 million in its capital program, with $24.7 million invested in the Woodbine and $1.9 million in the Buda.

Hedging Activity

Crimson continues to mitigate commodity price risk through the use of derivative contracts in an effort to achieve a more predictable cash flow. Consistent with this strategy, in July the following derivative contracts were added to further mitigate crude oil and natural gas liquid price risk for the remainder of 2013:

Natural Gas
     
Volume/Month
 
Price/Unit
Henry Hub
           
July 2013-Dec 2013
 
Swap
 
40,000 Bbls
 
$99.00 (WTI)

Drilling Update

Woodbine formation
 
In Madison County, Texas, the Grace Hall C (Allocation) Unit #1H (62.6% WI) well, targeting the Woodbine formation, was successfully completed at a total measured depth of 15,215 feet, including a 6,165 foot lateral, with 22 stages of fracture stimulation, and commenced production in June at an initial rate of 989 boepd (87.7% oil).

Additionally in Madison County, the Payne B #1H (84.1% WI) well, targeting the Woodbine formation, was successfully completed at a total measured depth of 15,900 feet, including a 6,668 foot lateral, with 24 stages of fracture stimulation, and commenced production in May at an initial rate of 1,195 Boepd (87% oil).

Upon completion of drilling operations on the Grace Hall, the rig moved approximately 9 miles southeast to begin drilling the Stuckey-Upchurch #1H (72% WI) well in Crimson’s Iola-Grimes Area, another Woodbine target.  The Stuckey well was drilled to a total measured depth of 14,963 feet with a 5,100 foot lateral.  Completion operations are scheduled to begin in early August, and are planned to include 19 stages of fracture stimulation.

After completion of the drilling phase on the Stuckey-Upchurch well, the rig was moved back to the Force Area in Madison County to commence the drilling of the Crow A-1 (74.2% WI) well, also targeting the Woodbine.  The well is currently drilling at a depth of 9,140 feet, with drilling and completion operations expected to be completed by mid-September.  Crimson expects this rig to stay active in the Madison and Grimes area for the remainder of the year.

 
7

 


Buda formation

As previously disclosed in June, Crimson successfully drilled the Beeler #2H (50% WI), its first well targeting the Buda formation in Dimmit County, Texas.  The well was drilled to a total measured depth of 11,013 feet, including an approximate 3,700 foot lateral, was completed naturally without fracture stimulation, and commenced production at an initial rate of 859 boepd (89% oil).  The well averaged a gross rate of 693 Boepd for its first 83 days of production.

Crimson has spud its second well in the area, the Beeler #3H (50% WI), and is currently drilling at a depth of 3,245 feet with drilling and completion operations expected to be completed in early September.  Crimson expects this rig to remain active in the area for the rest of the year.

Crimson is very encouraged about the Buda potential, and views this area as another opportunity for oil and liquids growth. The Beeler #2H is located in Crimson’s Booth-Tortuga Area where the Company currently has approximately 10,140 gross acres.

 
8

 


Selected Financial and Operating Data

The following table reflects certain comparative financial and operating data for the three and six month periods ended June 30, 2013 and 2012:

   
Three Months Ended
   
Six Months Ended
 
   
June 30,
   
June 30,
 
Total Volumes Sold:
 
2013
   
2012
   
%
   
2013
   
2012
   
%
 
Crude oil (barrels)
    253,457       197,185       29 %       406,499       355,818       14 %  
Natural gas liquids (barrels)
    108,182       82,520       31 %       189,905       145,056       31 %  
Natural gas (Mcf)
    1,855,336       2,001,086       -7 %       3,679,888       4,165,211       -12 %  
Natural gas equivalents (Mcfe)
    4,025,170       3,679,316       9 %       7,258,312       7,170,455       1 %  
                                                 
Daily Sales Volumes:
                                               
Crude oil (barrels)
    2,785       2,167       29 %       2,246       1,955       15 %  
Natural gas liquids (barrels)
    1,189       907       31 %       1,049       797       32 %  
Natural gas (Mcf)
    20,388       21,990       -7 %       20,331       22,886       -11 %  
Natural gas equivalents (Mcfe)
    44,233       40,432       9 %       40,101       39,398       2 %  
                                                 
Average sales prices (before hedging):
                                               
Oil
  $ 101.84     $ 106.09       -4 %     $ 103.60     $ 106.72       -3 %  
NGLs
    28.25       35.95       -21 %       26.62       39.24       -32 %  
Gas
    3.99       2.03       97 %       3.61       2.30       57 %  
Mcfe
  $ 9.01     $ 7.60       19 %       8.33     $ 7.43       12 %  
                                                 
Average sales price (after hedging):
                                               
Oil
  $ 104.22     $ 109.06       -4 %     $ 104.57     $ 107.92       -3 %  
NGLs
    28.25       35.95       -21 %       26.62       39.24       -32 %  
Gas
    3.95       3.02       31 %       3.62       3.15       15 %  
Mcfe
  $ 9.14     $ 8.30       10 %     $ 8.39     $ 7.98       5 %  
                                                 
Selected Costs ($ per Mcfe):
                                               
Lease operating expenses
  $ 0.82     $ 0.98       -16 %     $ 0.90     $ 1.15       -22 %  
Production and ad valorem taxes
  $ 0.59     $ (0.68 )  
na
    $ 0.56     $ (0.15 )  
na
 
Depreciation and depletion expense
  $ 4.62     $ 3.99       16 %     $ 4.33     $ 4.06       7 %  
General and administrative expense - Total
  $ 1.70     $ 1.23       38 %     $ 1.54     $ 1.30       19 %  
General and administrative expense - Cash
  $ 1.53     $ 1.06       44 %     $ 1.35     $ 1.13       20 %  
Interest
  $ 1.57     $ 1.69       -7 %     $ 1.74     $ 1.74       0 %  
                                                 
Adjusted EBITDAX (1)
  $ 24,910,809     $ 25,480,011       -2 %     $ 40,411,612     $ 41,775,064       -3 %  
                                                 
Capital expenditures
                                               
Leasehold acquisitions
    1,431,327       3,233,538               2,199,693       3,991,213          
Exploratory
    (1,176 )     (183,474 )             65,569       9,749,336          
Development
    17,851,195       24,543,078               28,183,498       46,528,191          
Other
    0       19,717               0       19,717          
    $ 19,281,346     $ 27,612,859             $ 30,448,760     $ 60,288,457          
                                                 
Weighted Average Shares Outstanding
                                               
Basic
    44,681,434       44,134,330               44,536,281       44,055,639          
Diluted
    44,995,267       44,992,883               44,536,281       44,484,917          

 
(1) Adjusted EBITDAX is a non-GAAP financial measure. See below for a reconciliation to net income (loss).
 


 
9

 



CRIMSON EXPLORATION INC.
CONDENSED CONSOLIDATED BALANCE SHEETS

 
   
June 30,
   
December 31,
 
   
2013
   
2012
 
ASSETS
           
Accounts receivable
  $ 13,924,071     $ 11,726,078  
Current mark to market value of derivatives
    2,084,643       1,892,744  
Other current assets
    791,323       844,495  
Deferred tax asset (current and non-current)
    54,418,105       52,171,316  
Net property and equipment
    298,445,132       300,827,480  
Other non-current assets
    1,534,715       1,158,276  
                 
TOTAL ASSETS
  $ 371,197,989     $ 368,620,389  
                 
LIABILITIES AND STOCKHOLDERS' EQUITY
               
Current mark to market value of derivatives
  $     $  
Other current liabilities
    54,198,373       38,685,288  
Long-term debt, net of current portion
    229,926,282       239,368,865  
Other non-current liabilities
    10,302,362       10,724,119  
Total stockholders’ equity
    76,770,972       79,842,117  
                 
TOTAL LIABILITIES & STOCKHOLDERS’ EQUITY
  $ 371,197,989     $ 368,620,389  




 
10

 


CRIMSON EXPLORATION INC.
 CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)


   
Three Months Ended June 30,
   
Six Months Ended June 30,
 
   
2013
   
2012
   
2013
   
2012
 
                         
OPERATING REVENUES
                       
Crude oil sales
  $ 26,415,041     $ 21,505,766     $ 42,508,437     $ 38,398,380  
Natural gas sales
    7,326,514       6,051,551       13,329,189       13,120,665  
Natural gas liquids sales
    3,056,063       2,966,694       5,054,926       5,691,545  
Total operating revenues
    36,797,618       30,524,011       60,892,552       57,210,590  
                                 
OPERATING EXPENSES
                               
Lease operating expenses
    3,294,735       3,603,046       6,556,862       8,240,431  
Production and ad valorem taxes
    2,362,788       (2,488,997 )     4,051,530       (1,080,256 )
Exploration expenses
    185,649       48,895       303,130       349,591  
Depreciation, depletion and amortization
    18,612,302       14,675,882       31,452,022       29,137,944  
Impairment of oil and gas properties
    827,677       806,067       1,645,415       1,482,541  
General and administrative
    6,849,167       4,525,720       11,163,501       9,297,177  
Gain on sale of assets
    (4,975 )           (11,359 )     (8,900 )
Total operating expenses
    32,127,343       21,170,613       55,161,101       47,418,528  
                                 
INCOME FROM OPERATIONS
    4,670,275       9,353,398       5,731,451       9,792,062  
                                 
OTHER INCOME (EXPENSE)
                               
Interest expense
    (6,325,864 )     (6,212,806 )     (12,609,601 )     (12,457,988 )
Other income and financing cost
    (131,814 )     (103,544 )     (251,216 )     (346,287 )
Unrealized gain on derivative instruments
    2,643,221       3,037,733       760,231       2,512,100  
Total other income (expense)
    (3,814,457 )     (3,278,617 )     (12,100,586 )     (10,292,175 )
                                 
INCOME (LOSS) BEFORE INCOME TAXES
    855,818       6,074,781       (6,369,135 )     (500,113 )
                                 
Income tax (expense) benefit
    (317,499 )     (2,163,962 )     2,176,055       11,847  
                                 
NET INCOME (LOSS)
  $ 538,319     $ 3,910,819     $ (4,193,080 )   $ (488,266 )


 
11

 

Non-GAAP Financial Measures

EBITDAX represents net income (loss) before interest expense, taxes, and depreciation, amortization and exploration expenses.  Adjusted EBITDAX represents EBITDAX as further adjusted to reflect the items set forth in the table below, all of which will be required in determining our compliance with financial covenants under the credit agreements representing our senior credit facility and our second lien credit facility.

We have included EBITDAX and Adjusted EBITDAX in this release to provide investors with a supplemental measure of our operating performance and information about the calculation of some of the financial covenants that are contained in our credit agreements.  We believe EBITDAX is an important supplemental measure of operating performance because it eliminates items that have less bearing on our operating performance and so highlights trends in our core business that may not otherwise be apparent when relying solely on GAAP financial measures.  We also believe that securities analysts, investors and other interested parties frequently use EBITDAX in the evaluation of companies, many of which present EBITDAX when reporting their results.  Adjusted EBITDAX is a material component of the covenants that are imposed on us by our credit agreements.  We are subject to financial covenant ratios that are calculated by reference to Adjusted EBITDAX.  Non-compliance with the financial covenants contained in these credit agreements could result in a default, an acceleration in the repayment of amounts outstanding, and a termination of lending commitments.  Our management and external users of our financial statements, such as investors, commercial banks, research analysts and others, also use EBITDAX and Adjusted EBITDAX to assess:

·  
the financial performance of our assets without regard to financing methods, capital structure or historical cost basis;
·  
the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness;
·  
our operating performance and return on capital as compared to those of other companies in our industry, without regard to financing or capital structure; and
·  
 the feasibility of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities.

EBITDAX and Adjusted EBITDAX are not presentations made in accordance with generally accepted accounting principles, or GAAP.  As discussed above, we believe that the presentation of EBITDAX and Adjusted EBITDAX in this release is appropriate.  However, when evaluating our results, you should not consider EBITDAX and Adjusted EBITDAX in isolation of, or as a substitute for, measures of our financial performance as determined in accordance with GAAP, such as net income (loss).  EBITDAX and Adjusted EBITDAX have material limitations as performance measures because they exclude items that are necessary elements of our costs and operations.  Because other companies may calculate EBITDAX and Adjusted EBITDAX differently than we do, EBITDAX may not be, and Adjusted EBITDAX as presented in this release is not, comparable to similarly-titled measures reported by other companies.

 
12

 

The following table reconciles net income to EBITDAX and Adjusted EBITDAX for the periods presented:

 
   
Three Months Ended
   
Six Months Ended
 
   
June 30,
   
June 30,
 
   
2013
   
2012
   
2013
   
2012
 
                         
Net income (loss)
  $ 538,319     $ 3,910,819     $ (4,193,080 )   $ (488,266 )
Interest expense
    6,325,864       6,212,806       12,609,601       12,457,988  
Income tax expense (benefit)
    317,499       2,163,962       (2,176,055 )     (11,847 )
Depreciation & amortization
    18,612,302       14,675,882       31,452,022       29,137,944  
Exploration expenses
    185,649       48,895       303,130       349,591  
EBITDAX
    25,979,633       27,012,364       37,995,618       41,445,410  
                                 
Unrealized loss (gain) on derivative inst.
    (2,643,221 )     (3,037,733 )     (760,231 )     (2,512,100 )
Non-cash equity-based compensation charges
    687,731       639,710       1,350,276       1,172,021  
Impairment and abandonment of oil and gas properties
    827,677       806,067       1,645,415       1,482,541  
Amortization of deferred finance costs
    63,964       59,603       191,893       196,092  
(Gain) loss on sale of assets
    (4,975 )           (11,359 )     (8,900 )
Adjusted EBITDAX
    24,910,809       25,480,011       40,411,612       41,775,064  
                                 
Merger transaction costs
    1,069,976             1,069,976        
Severance tax refund
          (4,032,898 )           (4,032,898 )
Adjusted EBITDAX, exclusive of special items
  $ 25,980,785     $ 21,447,113     $ 41,481,588     $ 37,742,166  


Updated Guidance for Third Quarter 2013

The Company is providing the following updated guidance for the third calendar quarter of 2013.

Production volumes
40,000 – 42,000
   
Lease operating expenses ($M)
$3,600 - $4,000
   
Production and ad valorem taxes
7% of actual prices
   
Cash G&A ($M) (1)
$3,600 - $4,000
   
DD&A rate
$4.60 - $4.85 per mcfe

(1)  
Exclusive of merger related costs

Teleconference Call

Crimson management will hold a conference call to discuss the information described in this press release on Thursday, August 8, 2013 at 10:30am CDT.  Those interested in participating in the earnings conference call may do so by calling the following phone number: 800-723-6575, (International 785-830-1997) and entering the following participation code 7789867.  A replay of the call will be available from Thursday, August 8, 2013 at 1:30pm CDT through Thursday, August 15, 2013 at 1:30pm CDT by dialing toll free 888-203-1112, (International 719-457-0820) and asking for replay ID code 7789867.


Crimson Exploration is a Houston, TX-based independent energy company engaged in the exploitation, exploration, development and acquisition of crude oil and natural gas, primarily in the onshore Gulf Coast regions of the United States. The Company currently owns approximately 95,000 net acres onshore in Texas, Louisiana, Colorado and Mississippi. The Company refers to its four corporate areas as (i) Southeast Texas, focusing on the Woodbine, Eagle Ford and Georgetown formations, (ii) South Texas, focusing on the Eagle Ford and Buda formations, (iii) East Texas, focusing on the Haynesville, Mid-Bossier and James Lime formations, and (iv) Rockies and Other, focusing

 
13

 

on the Niobrara and D&J Sands formations. The Company’s strategy is to continue to increase crude oil and liquids-rich reserves and production from an extensive inventory of drilling prospects, de-risk unproved prospects in core operating areas, and opportunistically grow reserves through acquisitions complementary to its existing asset base.

Additional information on Crimson Exploration Inc. is available on the Company's website at http://crimsonexploration.com.

This press release includes “forward-looking statements” as defined by the Securities and Exchange Commission (“SEC”) and applicable securities laws. Such statements include those concerning Crimson’s strategic plans, expectations and objectives for future operations. All statements included in this press release that address activities, events or developments that Crimson expects, believes or anticipates will or may occur in the future are forward-looking statements. These statements are based on certain assumptions Crimson made based on its experience and perception of historical trends, current conditions, expected future developments and other factors it believes are appropriate under the circumstances. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond Crimson’s control. Statements regarding future production, revenue, cash flow operating results,  leverage, drilling rigs operating, drilling locations, funding, derivative transactions, pricing, operating costs and capital spending, tax rates, and descriptions of our development plans are subject to all of the risks and uncertainties normally incident to the exploration for and development and production of oil and gas. These risks include, but are not limited to, commodity price changes, inflation or lack of availability of goods and services, environmental risks, the proximity to and capacity of transportation facilities, the timing of planned capital expenditures, uncertainties in estimating reserves and forecasting production results, operating and drilling risks, regulatory changes and the potential lack of capital resources. All forward-looking statements are based on our forecasts for our existing operations and do not include the potential impact of any future acquisitions.  Investors are cautioned that any such statements are not guarantees of future performance and that actual results or developments may differ materially from those projected in the forward-looking statements. Please refer to our filings with the SEC, including our Form 10-K for the year ended December 31, 2012, and subsequent filings for a further discussion of these risks. Existing and prospective investors are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

Contact:
Crimson Exploration Inc.
E. Joseph Grady, 713-236-7400
Senior Vice President and Chief Financial Officer

14



The following information was filed by Crimson Exploration Inc. (CXPO) on Thursday, August 8, 2013 as an 8K 2.02 statement, which is an earnings press release pertaining to results of operations and financial condition. It may be helpful to assess the quality of management by comparing the information in the press release to the information in the accompanying 10-Q Quarterly Report statement of earnings and operation as management may choose to highlight particular information in the press release.

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