EX-99.1 2 d68544exv99w1.htm EX-99.1 exv99w1
Exhibit 99.1
(ENCORE LOGO)
Encore Acquisition Company Announces Second Quarter 2009 Results and
Provides Operations Update
FORT WORTH, Texas—(BUSINESS WIRE)—July 28, 2009
Encore Acquisition Company (NYSE: EAC) (“Encore” or the “Company”) today reported unaudited second quarter 2009 results.
The following table highlights certain reported amounts for the second quarter of 2009 as compared to the second quarter of 2008 ($ and shares outstanding in millions, except average price amounts):
                 
    Qtr Ended June 30,
    2009   2008
Average daily production volumes (BOE/D)
     41,407       38,214  
Oil as percentage of total production volumes
     64 %     71 %
Oil and natural gas revenues
   $ 163.2     $ 354.8  
Average realized combined price ($/BOE)
   $ 43.30     $ 102.03  
Oil and natural gas development and expl costs incurred
   $ 72.0     $ 142.4  
Unproved acreage costs incurred
   $ 0.9     $ 18.6  
Adjusted EBITDAX
   $ 112.5     $ 248.2  
Net loss
   $ (47.0 )   $ (35.7 )
Net income (loss) excluding certain items
   $ (2.2 )   $ 87.9  
Weighted average diluted shares outstanding
     51.8       52.3  
Average daily production volumes for the second quarter of 2009 were 41,407 BOE/D, beating the midpoint of the guidance by over 1,500 BOE/D. The higher than expected production occurred during a quarter with only $72.0 million of new capital invested, a 49 percent reduction compared to the same period in 2008, highlighting the Company’s resilient production base and efficient operating practices. Second quarter 2009 production was eight percent higher than the same quarter of 2008. Net profits interest reduced wellhead volumes by 2,065 BOE/D in the second quarter of 2009 as compared to 1,943 BOE/D in the second quarter of 2008.
Encore reported a net loss excluding certain items of $2.2 million ($0.04 per diluted share) for the second quarter of 2009 as compared to net income excluding certain items of $87.9 million ($1.64 per diluted share) for the second quarter of 2008, largely due to lower oil and natural gas prices. Encore reported a net loss of $47.0 million ($0.91 per diluted share) for the second quarter of 2009 as compared to $35.7 million ($0.68 per diluted share) for the second quarter of 2008. Net income (loss) excluding certain items is a non-GAAP financial measure, which is defined and reconciled to its most directly comparable GAAP measure in the attached financial schedules.

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Jon S. Brumley, Encore’s Chief Executive Officer and President, stated, “In December of 2008, we began implementing a strategy to position Encore to take advantage of low commodity prices and ready the company to profit from the downturn and the subsequent rebound in oil prices. We reduced our drilling budget to stay within cash flow, and we cashed out our 2009 oil hedges in February, at the low point in the oil cycle, for almost $200 million. In June, with the subsequent increase in oil prices, we were able to reinvest these proceeds into an excellent oil and gas acquisition in two of our core areas, ArkLaTex and Oklahoma. The acquisition, the monetization proceeds, and Encore’s flat production base will allow us to exit 2009 with more production, more liquidity, and an increased drilling inventory. As our competitors were drilling through their low rate-of-return inventory to maintain their production, we decided it was smarter to highlight our flat production base and invest in an acquisition that should generate a higher return on equity, enhance Encore’s drilling inventory, and increase discretionary cash flow per share by ten percent in 2010. With high quality properties, a long life acquisition, and the procurement of CO2, 2009 will be a great year for Encore, but 2010 will be even better. In the fourth quarter Encore expects to have one rig drilling in the Haynesville, one in the Bakken, and one or two in West Texas. We plan to increase our activity in the Bakken and Haynesville in 2010.”
Adjusted EBITDAX was $112.5 million for the second quarter of 2009 as compared to $248.2 million for the second quarter of 2008. Adjusted EBITDAX is a non-GAAP financial measure, which is defined and reconciled to its most directly comparable GAAP measures in the attached financial schedules.
Despite the Company’s higher reported production volumes, the Company’s oil and natural gas revenues fell to $163.2 million in the second quarter of 2009 as compared to $354.8 million in the second quarter of 2008, reflecting the current lower commodity price environment. The Company’s average oil differential tightened from $7.08 per Bbl in the second quarter of 2008 to $4.81 per Bbl in the second quarter of 2009. As a percentage of NYMEX, the Company’s differential of negative eight percent compares favorably to its previously released guidance of negative 12 percent. The Company’s average wellhead oil price, which represents the net price the Company receives for its oil production, fell to $55.02 per Bbl in the second quarter of 2009 from $117.22 per Bbl in the second quarter of 2008.
The Company’s realized natural gas price declined from $11.12 per Mcf in the second quarter of 2008 to $3.67 per Mcf in the second quarter of 2009. The second quarter 2009 average NYMEX price was $3.49 per Mcf versus $10.94 per Mcf in the second quarter of 2008. The Company realized a positive $0.18 per Mcf differential in both the second quarter of 2009 and the second quarter of 2008. As a percentage of NYMEX, the second quarter of 2009 positive differential of five percent compares favorably to previously released guidance of a negative 15 percent on a dry gas basis due to favorable NGL pricing compared to natural gas on an energy equivalent basis.
Lease operating expenses were $40.5 million for the second quarter of 2009 ($10.74 per BOE), below the low end of previously released guidance, versus $40.7 million for the second quarter of 2008 ($11.70 per BOE). The Company has increased its focus on cost reductions and has been able to realize cost savings in many of its areas of operations, resulting in the lower than expected expenses, which it expects to retain throughout the remainder of the year.
General and administrative (“G&A”) expenses for the second quarter of 2009 were $13.8 million ($3.66 per BOE) versus $11.6 million ($3.32 per BOE) for the second quarter of 2008.
Exploration expense for the second quarter of 2009 was $15.9 million as compared to $11.6 million for the second quarter of 2008. During the second quarter of 2009, the Company expensed three gross (2.9 net) exploratory dry holes totaling $9.5 million, while only expensing two gross (2.0 net) exploratory

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dry holes totaling $6.6 million in the second quarter of 2008. Of the three dry holes expensed in the second quarter of 2009, one was spud in the Almond area of the Bakken in the first quarter of 2009 and two were spud in the ArkLaTex region in the latter part of 2008.
Other operating expense increased from $3.2 million for the second quarter of 2008 to $14.8 million for the second quarter of 2009. This primarily resulted as the Company recorded $10.0 million of asset valuation adjustments in the second quarter of 2009, comprising a $5.7 million adjustment to the carrying value of pipe and other tubular inventory whose market value had declined below cost and a $4.3 million adjustment to the carrying value of certain receivables from ExxonMobil related to Encore’s West Texas joint venture.
Encore completed 27 gross wells (9.9 net) during the second quarter of 2009, 24 of which (7.0 net) were successful. In the second quarter of 2009, Encore successfully implemented its stated goal of containing capital costs within internally generated cash flows. The Company accomplished this through a combination of planned reductions in the number of capital projects that were implemented and aggressive cost reductions. The Company plans to continue to invest in development and exploratory projects within internally generated cash flows as it strengthens its balance sheet through the remainder of the year.
The following table summarizes costs incurred related to oil and natural gas properties for the periods indicated:
                 
    Qtr Ended June 30,  
    2009     2008  
    (in thousands)  
Acquisitions:
                
Proved properties
   $ 27,470     $ 5,687  
Unproved properties
     874       18,642  
Asset retirement obligations
     60       68  
 
            
Total acquisitions
     28,404       24,397  
 
            
 
                
Development:
                
Drilling and exploitation
     24,993       76,876  
Asset retirement obligations
     39       118  
 
            
Total development
     25,032       76,994  
 
            
 
                
Exploration:
                
Drilling
     46,269       64,619  
Geological and seismic
     525       455  
Delay rentals
     136       357  
 
            
Total exploration
     46,930       65,431  
 
            
 
                
Total costs incurred
   $ 100,366     $ 166,822  
 
            
Capital Budget Update
The Board of Directors has approved a revised capital budget of $340 million, an increase of $30 million from the Company’s previously announced capital budget. The Company plans to use the additional capital to add two drilling rigs, one drilling in the Bakken and the other in the Haynesville, as well as begin work on its recently announced CO2 tertiary recovery project in its Bell Creek Field.
Operations Update
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West Texas
In the Company’s West Texas joint venture with ExxonMobil, three horizontal wells were brought online in the second quarter of 2009. The Pyote Gas Unit 2-3H was drilled in the Block 16 Field of the Delaware Basin. The well was completed in the Montoya Formation at a rate of 9.0 MMcf and 150 Bbls per day.  In the Wilshire Field of the Midland Basin, two wells were brought online during the second quarter of 2009. The McElroy Ranch 63H and the McElroy Ranch 60H were drilled and completed in the Devonian Formation with initial production rates of 3.4 MMcf and 185 Bbls per day and 2.5 MMcf and 350 Bbls per day, respectively.  The Company has seen significant drilling and completions savings in West Texas. In the Wilshire Field, the Company has experienced a ten percent decrease in drilling and completion costs in 2009 as compared to wells drilled and completed in 2008. The cost savings are a result of decreased prices in drilling and completion services, as well as continued efficiencies in the drilling and completion process.
Bakken/Sanish
In the second quarter of 2009, Encore drilled and completed its best well to date in the Charlson area in the Three Forks Sanish formation. The Charlson 44X-33H had an initial production rate of 1,630 BOE/D at a flowing pressure of 1,500 psi. The Company drilled and completed two additional wells in the second quarter of 2009, the Shipton 44-21H in the Almond area and the Charlson 11-6H well. The Shipton 44-21H tested wet after fracture stimulation (expensed as a dry hole in the second quarter of 2009), and the Charlson 11-6H had an initial production rate of 260 BOE/D. Encore also successfully re-fraced two wells in the Charlson area in the second quarter of 2009, the Charlson 44-32H and the Charlson 44X-31H. The average initial incremental rate from the refracs was 252 BOE/D at an average cost of $300 thousand per refrac. One month after the re-stimulation, the wells still have incremental production of 177 BOE/D. Encore plans to refrac a total of 12 wells in 2009.
Haynesville
The Company has seen increased activity in its non-operated Haynesville acreage in Northwest Louisiana. In the Caspiana Field in Desoto Parish, two horizontal wells were recently brought on line.  The Hall 9-1H went to sales in April at a rate of 13.7 MMcf/D, and in early July, the Dalton 10-1H went to sales at a rate of 12.0 MMcf/D.  Encore’s working interest in the Caspiana Field ranges between 28 and 34 percent. The Company expects two more non-operated Haynesville wells to be brought on line in the third quarter of 2009.  In addition, the Company expects to complete its second operated well in the Greenwood-Waskom Field in Caddo Parish in the third quarter of 2009.
Acquisition
The Company recently announced that it entered into definitive agreements with EXCO Resources, Inc. (NYSE: XCO) and an affiliate, EXCO Operating Company, LP, to acquire oil and natural gas properties in the Mid-Continent and East Texas for $375 million in cash, subject to customary purchase price adjustments and closing conditions. The acquisitions are expected to close in the third quarter of 2009, and the Company will begin including the results of operations and related production in its results beginning in September 2009.

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Liquidity Update
At June 30, 2009, the Company’s long-term debt, net of discount, was $1.2 billion, including $150 million of 6.25% senior subordinated notes due April 15, 2014, $300 million of 6.0% senior subordinated notes due July 15, 2015, $225 million of 9.5% senior subordinated notes due May 1, 2016, $150 million of 7.25% senior subordinated notes due December 1, 2017, and $175 million and $195 million of outstanding borrowings under Encore’s and Encore Energy Partners LP’s (“ENP”) revolving credit facilities, respectively.
The amount outstanding on revolving credit facilities decreased $168 million during the second quarter of 2009. The following table details the changes in the Company’s revolving credit facilities from the end of the first quarter of 2009 to the end of the second quarter of 2009, as well as pro forma credit facility balances after taking into consideration the previously announced acquisitions and ENP’s common unit offering that closed subsequent to the end of the second quarter of 2009 (in thousands):
                         
    EAC     ENP     Total  
Credit Facility Balance 3/31/09
   $ 353,000     $ 185,000     $ 538,000  
Bond Offering - 9.5%
     (203,013 )     —       (203,013 )
ENP Vinegarone Acquisition
     —       27,538       27,538  
Sale of Assets from EAC to ENP
     (25,800 )     25,800       —  
ENP Common Unit Offering
     —       (41,152 )     (41,152 )
Acquisition Deposit
     37,500       —       37,500  
Working Capital (net)
     13,313       (2,186 )     11,127  
 
                  
 
                        
Credit Facility Balance 6/30/09
     175,000       195,000       370,000  
Acquisition
     337,500       —       337,500  
Sale of Assets from EAC to ENP
     (190,000 )     190,000       —  
ENP Common Unit Offering
     —       (129,105 )     (129,105 )
 
                  
 
                        
Pro Forma Balance 6/30/09
   $ 322,500     $ 255,895     $ 578,395  
 
                  
At June 30, 2009, the Company had $650 million of availability on its revolving credit facility and $45 million on ENP’s. Subsequent to the end of the second quarter, the lenders agreed to reaffirm Encore’s borrowing base at $825 million and to increase ENP’s borrowing base from $240 million to $375 million upon closing of the previously announced drop-down of properties from Encore. The following table details the Company’s pro forma availability under its revolving credit facilities after taking into consideration the previously announced acquisitions, ENP’s common unit offering, the drop-down of properties from Encore to ENP, and the expected increase in ENP’s borrowing base, all of which closed, or are scheduled to close, in the third quarter (in thousands):
                         
    EAC     ENP     Total  
Availability 6/30/09
   $ 650,000     $ 45,000     $ 695,000  
Redetermination
     —       135,000       135,000  
Acquisition
     (337,500 )     —       (337,500 )
ENP Common Unit Offering
     —       129,105       129,105  
Sale of Assets from EAC to ENP
     190,000       (190,000 )     —  
 
                  
Pro Forma Availability 6/30/09
   $ 502,500     $ 119,105     $ 621,605  
 
                  

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The Company believes its pro forma liquidity is sufficient to meet current cash requirements. In addition, as part of the normal borrowing base redetermination process in the fall of 2009, the Company expects the borrowing base on EAC’s revolving credit facility to increase as a result of the additional reserve volumes purchased with the Mid-Continent and East Texas acquisitions.
Third Quarter 2009 Outlook
The Company expects the following in the third quarter of 2009 (includes one month of acquisition related results):
     
Average daily wellhead production volumes
   43,300 to 45,000 BOE/D
Average daily net profits production volumes
   1,500 to 1,800 BOE/D
Average daily reported production volumes
   41,500 to 43,500 BOE/D
Oil and natural gas related development capital
   $55 to $65 million
Unproved capital for leasehold acreage
   $5 million
Lease operating expense
   $10.50 to $11.25 per BOE
G&A expenses
   $3.00 to $3.50 per BOE
Depletion, depreciation, and amortization
   $19.50 to $20.00 per BOE
Production, ad valorem, and severance taxes
   11% of wellhead revenues
Oil differential
   -15% of NYMEX oil price
Natural gas differential – dry gas
   -24% of NYMEX natural gas price
Income tax expense
   39% effective rate
Income tax expense — current
   $2 to $4 million
Conference Call Details
As announced today, the Company has procured a CO2 supply that will be used for a tertiary oil recovery project in its Bell Creek Field. In conjunction with the conference call to discuss second quarter financial and operating results, the Company will present its tertiary field development plan for its Bell Creek Field. Participants are encouraged to download presentation materials located on the Company’s website at www.encoreacq.com prior to the onset of the call.
Title: Encore Acquisition Company and Encore Energy Partners LP Conference Call
Date and Time: Wednesday, July 29, 2009 at 9:30 a.m. Central Time
Webcast: Listen to the live broadcast via http://www.encoreacq.com
Telephone: Dial 877-356-9552 ten minutes prior to the scheduled time and request the conference call by supplying the title specified above or ID 20407161.
A replay of the conference call will be archived and available via Encore’s website at the above web address or by dialing 800-642-1687 and entering conference ID 20407161. The replay will be available through August 12, 2009. International callers can dial 973-935-8270 for the live broadcast or 706-645-9291 for the replay.

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About the Company
Encore Acquisition Company is engaged in the acquisition and development of oil and natural gas reserves from onshore fields in the United States. Since 1998, Encore has acquired producing properties with proven reserves and leasehold acreage and grown the production and proven reserves by drilling, exploring, reengineering or expanding existing waterflood projects, and applying tertiary recovery techniques.
Cautionary Statement
This press release includes forward-looking statements, which give Encore’s current expectations or forecasts of future events based on currently available information. Forward-looking statements are statements that are not historical facts, such as expectations regarding the likelihood of the closing of acquisitions and dispositions and the benefits to be derived therefrom, drilling plans, reaffirmation of Encore’s borrowing base, changes in ENP’s borrowing base, the status of wells and expectations regarding completion, expected net profits interests, expected production volumes and decline rates, expected expenses (including, without limitation, expected reductions), expected taxes, expected capital expenditures, expected differentials, the results of CO2 floods, and projected debt balances. The assumptions of management and the future performance of Encore are subject to a wide range of business risks and uncertainties and there is no assurance that these statements and projections will be met. Factors that could affect Encore’s business include, but are not limited to: the risks associated with drilling of oil and natural gas wells; Encore’s ability to find, acquire, market, develop, and produce new reserves; the risk of drilling dry holes; oil and natural gas price volatility; derivative transactions (including the costs associated therewith and the abilities of counterparties to perform thereunder); uncertainties in the estimation of proved, probable, and possible reserves and in the projection of future rates of production and reserve growth; inaccuracies in Encore’s assumptions regarding items of income and expense and the level of capital expenditures; uncertainties in the timing of exploitation expenditures; operating hazards attendant to the oil and natural gas business; drilling and completion losses that are generally not recoverable from third parties or insurance; potential mechanical failure or underperformance of significant wells; pipeline construction difficulties; climatic conditions; availability and cost of material and equipment; the risks associated with operating in a limited number of geographic areas; actions or inactions of third-party operators of Encore’s properties; Encore’s ability to retain skilled personnel; diversion of management’s attention from existing operations while pursuing acquisitions or dispositions; availability of capital; the strength and financial resources of Encore’s competitors; regulatory developments; environmental risks; uncertainties in the capital markets; uncertainties with respect to asset sales; general economic and business conditions (including the effects of the worldwide economic recession); industry trends; and other factors detailed in Encore’s most recent Form 10-K and other filings with the Securities and Exchange Commission. If one or more of these risks or uncertainties materialize (or the consequences of such a development changes), or should underlying assumptions prove incorrect, actual outcomes may vary materially from those forecasted or expected. Encore undertakes no obligation to publicly update or revise any forward-looking statements.
Contacts
Encore Acquisition Company, Fort Worth, TX
     
Bob Reeves, Chief Financial Officer
  Kim Weimer, Investor Relations
817-339-0918 
  817-339-0886 
rcreeves@encoreacq.com
  kweimer@encoreacq.com

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Exhibit 99.1
Encore Acquisition Company
Condensed Consolidated Statements of Operations
(in thousands, except per share amounts)
(unaudited)
                                 
    Three Months Ended     Six Months Ended  
    June 30,     June 30,  
    2009     2008     2009     2008  
Revenues:
                                
Oil
   $ 133,677     $ 286,924     $ 221,966     $ 507,458  
Natural gas
     29,486       67,889       54,740       116,201  
Marketing
     315       2,521       1,121       6,577  
 
                        
Total revenues
     163,478       357,334       277,827       630,236  
 
                        
Expenses:
                                
Production:
                                
Lease operating
     40,451       40,697       84,676       81,047  
Production, ad valorem, and severance taxes
     17,033       35,043       28,852       62,495  
Depletion, depreciation, and amortization
     74,434       51,026       144,734       100,569  
Exploration
     15,934       11,593       27,133       17,081  
General and administrative
     13,779       11,559       27,473       21,246  
Marketing
     515       3,725       1,254       7,507  
Derivative fair value loss
     61,106       256,390       12,515       321,528  
Other operating
     14,835       3,226       21,178       5,732  
 
                        
Total operating expenses
     238,087       413,259       347,815       617,205  
 
                        
Operating income (loss)
     (74,609 )     (55,925 )     (69,988 )     13,031  
 
                        
Other income (expense):
                                
Interest
     (19,126 )     (16,785 )     (35,089 )     (36,545 )
Other
     657       686       1,211       1,537  
 
                        
Total other expense
     (18,469 )     (16,099 )     (33,878 )     (35,008 )
 
                        
Loss before income taxes
     (93,078 )     (72,024 )     (103,866 )     (21,977 )
Income tax benefit
     31,558       21,322       36,443       2,589  
 
                        
Consolidated net loss
     (61,520 )     (50,702 )     (67,423 )     (19,388 )
Less: net loss attributable to noncontrolling interest
     14,545       14,982       12,892       14,888  
 
                        
Net loss attributable to EAC
   $ (46,975 )   $ (35,720 )   $ (54,531 )   $ (4,500 )
 
                        
 
                                
Net loss per common share:
                                
Basic
   $ (0.91 )   $ (0.68 )   $ (1.05 )   $ (0.09 )
Diluted
   $ (0.91 )   $ (0.68 )   $ (1.05 )   $ (0.09 )
 
                                
Weighted average common shares outstanding:
                                
Basic
     51,849       52,344       51,769       52,571  
Diluted
     51,849       52,344       51,769       52,571  
 
Encore Acquisition Company
Condensed Statements of Operations
(in thousands)
(unaudited)
 
    Three Months Ended     Six Months Ended  
    June 30, 2009     June 30, 2009  
    EAC Standalone     ENP     EAC Standalone     ENP  
Revenues:
                                
Oil
   $ 110,495     $ 23,182     $ 183,051     $ 38,915  
Natural gas
     25,531       3,955       46,867       7,873  
Marketing
     206       109       842       279  
 
                        
Total revenues
     136,232       27,246       230,760       47,067  
 
                        
Expenses:
                                
Production:
                                
Lease operating
     33,502       6,949       69,845       14,831  
Production, ad valorem, and severance taxes
     13,971       3,062       23,450       5,402  
Depletion, depreciation, and amortization
     63,140       11,294       122,449       22,285  
Exploration
     15,916       18       27,093       40  
General and administrative
     10,972       2,807       22,477       4,996  
Marketing
     454       61       1,063       191  
Derivative fair value loss (gain)
     23,666       37,440       (14,018 )     26,533  
Other operating
     14,177       658       19,803       1,375  
 
                        
Total operating expenses
     175,798       62,289       272,162       75,653  
 
                        
Operating loss
   $ (39,566 )   $ (35,043 )   $ (41,402 )   $ (28,586 )
 
                        

 

 

Encore Acquisition Company
Condensed Consolidated Statements of Cash Flows
(in thousands)
(unaudited)
                 
    Six Months Ended  
    June 30,  
    2009     2008  
Net loss
   $ (67,423 )   $ (19,388 )
Adjustments to reconcile net loss to net cash provided by operating activities:
                
Non-cash and other items
     252,668       402,473  
Changes in operating assets and liabilities
     358,902       (30,770 )
 
            
Net cash provided by operating activities
     544,147       352,315  
 
            
 
                
 
            
Net cash used in investing activities
     (309,360 )     (306,403 )
 
            
 
                
Financing activities:
                
Net proceeds from (payments on) long-term debt, net of issuance costs
     (152,550 )     19,839  
Proceeds from ENP issuance of common units, net of offering costs
     40,724       —  
Payments of deferred commodity derivative contract premiums
     (69,536 )     (20,583 )
Repurchase of common stock
     —       (39,118 )
ENP cash distributions to noncontrolling interest
     (12,153 )     (11,168 )
Other
     (7,471 )     5,008  
 
            
Net cash used in financing activities
     (200,986 )     (46,022 )
 
            
 
                
Increase (decrease) in cash and cash equivalents
     33,801       (110 )
Cash and cash equivalents, beginning of period
     2,039       1,704  
 
            
Cash and cash equivalents, end of period
   $ 35,840     $ 1,594  
 
            
Encore Acquisition Company
Condensed Consolidated Balance Sheets
(in thousands)
                                 
    June 30,     December 31,  
    2009     2008  
    (unaudited)                  
Total assets
           $ 3,420,969             $ 3,633,195  
 
                            
 
                                
Liabilities (excluding long-term debt)
           $ 797,931             $ 830,136  
6 1/4% Notes — due April 15, 2014
   $ 150,000             $ 150,000          
6 % Notes — due July 15, 2015
     300,000               300,000          
9 1/2% Notes — due May 1, 2016
     225,000               —          
7 1/4% Notes — due December 1, 2017
     150,000               150,000          
Discount — Senior Subordinated Notes
     (22,088 )             (5,189 )        
Revolving Credit Facility — EAC
     175,000               575,000          
Revolving Credit Facility — ENP
     195,000               150,000          
 
                            
Long-term debt
             1,172,912               1,319,811  
Equity
             1,450,126               1,483,248  
 
                            
Total liabilities and equity
           $ 3,420,969             $ 3,633,195  
 
                            
 
                                
Working capital (a)
           $ (53,025 )           $ 188,678  
 
(a)   Working capital is defined as current assets minus current liabilities.

 

 

Encore Acquisition Company
Selected Operating Results
(unaudited)
                                 
    Three Months Ended   Six Months Ended
    June 30,   June 30,
    2009   2008   2009   2008
Total production volumes:
                                
Oil (MBbls)
     2,430       2,460       4,918       4,964  
Natural gas (MMcf)
     8,030       6,105       15,727       11,937  
Combined (MBOE)
     3,768       3,477       7,539       6,953  
 
                                
Average daily production volumes:
                                
Oil (Bbls/D)
     26,701       27,032       27,170       27,274  
Natural gas (Mcf/D)
     88,236       67,090       86,890       65,586  
Combined (BOE/D)
     41,407       38,214       41,652       38,205  
 
                                
Average realized prices:
                                
Oil (per Bbl)
   $ 55.02     $ 116.64     $ 45.14     $ 102.23  
Natural gas (per Mcf)
     3.67       11.12       3.48       9.73  
Combined (per BOE)
     43.30       102.03       36.70       89.69  
 
                                
Average expenses per BOE:
                                
Lease operating
   $ 10.74     $ 11.70     $ 11.23     $ 11.66  
Production, ad valorem, and severance taxes
     4.52       10.08       3.83       8.99  
Depletion, depreciation, and amortization
     19.75       14.67       19.20       14.46  
Exploration
     4.23       3.33       3.60       2.46  
General and administrative
     3.66       3.32       3.64       3.06  
Derivative fair value loss
     16.22       73.73       1.66       46.24  
Other operating
     3.94       0.93       2.81       0.82  
Marketing loss
     0.05       0.35       0.02       0.13  
 
    Three Months Ended   Six Months Ended
    June 30, 2009   June 30, 2009
    EAC Standalone   ENP   EAC Standalone   ENP
Total production volumes:
                                
Oil (MBbls)
     2,002       428       4,065       853  
Natural gas (MMcf)
     6,802       1,228       13,350       2,377  
Combined (MBOE)
     3,135       633       6,290       1,249  
 
                                
Average daily production volumes:
                                
Oil (Bbls/D)
     21,997       4,704       22,456       4,714  
Natural gas (Mcf/D)
     74,738       13,498       73,758       13,132  
Combined (BOE/D)
     34,454       6,953       34,749       6,903  
 
                                
Average realized prices:
                                
Oil (per Bbl)
   $ 55.20     $ 54.16     $ 45.04     $ 45.61  
Natural gas (per Mcf)
     3.75       3.22       3.51       3.31  
Combined (per BOE)
     43.39       42.89       36.55       37.45  
 
                                
Average expenses per BOE:
                                
Lease operating expense
   $ 10.69     $ 10.98     $ 11.10     $ 11.87  
Production, ad valorem, and severance taxes
     4.46       4.84       3.73       4.32  
Depletion, depreciation, and amortization
     20.14       17.85       19.47       17.84  
Exploration
     5.08       0.03       4.31       0.03  
General and administrative
     3.50       4.44       3.57       4.00  
Derivative fair value loss (gain)
     7.55       59.17       (2.23 )     21.24  
Other operating
     4.52       1.04       3.15       1.10  
Marketing loss (gain)
     0.08       (0.07 )     0.04       (0.07 )

 

 

Encore Acquisition Company
Derivative Summary as of July 28, 2009
(unaudited)
Oil Derivative Contracts (b)
                                                     
    Average   Weighted     Average   Weighted     Average   Weighted
    Daily   Average     Daily   Average     Daily   Average
    Floor   Floor     Cap   Cap     Swap   Swap
Period   Volume   Price     Volume   Price     Volume   Price
    (Bbls)   (per Bbl)     (Bbls)   (per Bbl)     (Bbls)   (per Bbl)
Aug. — Dec. 2009 (c)
                                                    
 
     3,130     $ 110.00         —     $ —         —     $ —  
 
     —       —         440       97.75         —       —  
 
     —       —         —       —         1,000       68.70  
 
                                                    
2010
    880       80.00         440       93.80         —       —  
 
     2,000       75.00         3,000       74.13         1,385       75.78  
 
     8,385       62.83         500       65.60         1,750       64.08  
 
     1,000       56.00         —       —         1,000       59.70  
 
                                                    
2011
                                                    
 
     1,880       80.00         1,440       95.41         325       80.00  
 
     2,500       70.00         —       —         1,060       78.42  
 
     4,385       65.00         —       —         250       69.65  
 
                                                    
2012
    —       —         500       82.05         835       81.19  
 
     750       70.00         250       79.25         1,300       76.54  
 
     2,135       65.00         —       —         —       —  
Natural Gas Derivative Contracts (b)
                                                     
    Average   Weighted     Average   Weighted     Average   Weighted
    Daily   Average     Daily   Average     Daily   Average
    Floor   Floor     Cap   Cap     Swap   Swap
Period   Volume   Price     Volume   Price     Volume   Price
    (Mcf)   (per Mcf)     (Mcf)   (per Mcf)     (Mcf)   (per Mcf)
Aug. — Dec. 2009
                                                    
 
     3,800     $ 8.20         3,800     $ 9.83         —     $ —  
 
     3,800       7.20         5,000       7.45         —       —  
 
     6,800       6.57         15,000       6.63         —       —  
 
     15,000       5.64         —       —         —       —  
 
                                                    
2010
                                                    
 
     3,800       8.20         3,800       9.58         —       —  
 
     4,698       7.26         —       —         25,452       6.46  
 
     —       —         —       —         550       5.86  
 
                                                    
2011
                                                    
 
     3,398       6.31         —       —         27,952       6.48  
 
     —       —         —       —         550       5.86  
 
                                                    
2012
    898       6.76         —       —         25,452       6.47  
 
     —       —         —       —         550       5.86  
Interest Rate Swaps
                     
    Notional   Fixed    
Period   Amount   Rate   Floating Rate
    (in thousands)            
Aug. 2009 — Jan. 2011
  $ 50,000       3.1610 %   1-month LIBOR
Aug. 2009 — Jan. 2011
    25,000       2.9650 %   1-month LIBOR
Aug. 2009 — Jan. 2011
    25,000       2.9613 %   1-month LIBOR
Aug. 2009 — Mar. 2012
    50,000       2.4200 %   1-month LIBOR
 
(b)   Oil prices represent NYMEX WTI monthly average prices. Natural gas contracts are written at various market indices which may differ substantially from equivalent NYMEX prices.
 
(c)   From time to time, EAC sells floors with a strike price below the strike price of the purchased floors in order to partially finance the premiums paid on the purchased floors, thereby entering into a floor spread. In the above table, the purchased floor component of these floor spreads are shown net and included with EAC’s other floor contracts. In addition to the floor contracts shown above for 2009, EAC has a floor contract for 1,000 Bbls/D at $63.00 per Bbl and a short floor contract for 1,000 Bbls/D at $65.00 per Bbl.

 

 

Encore Acquisition Company
Non-GAAP Financial Measures
(in thousands, except per share amounts)
(unaudited)
     This press release includes a discussion of “Adjusted EBITDAX,” which is a non-GAAP financial measure. The following tables provide reconciliations of “Adjusted EBITDAX” to net loss and net cash provided by operating activities, EAC’s most directly comparable financial performance and liquidity measures calculated and presented in accordance with GAAP.
                                 
    Three Months Ended June 30,     Six Months Ended June 30,  
    2009     2008     2009     2008  
Adjusted EBITDAX Including Hedge Monetization
                                
Net loss attributable to EAC
   $ (46,975 )   $ (35,720 )   $ (54,531 )   $ (4,500 )
Depletion, depreciation, and amortization
     74,434       51,026       144,734       100,569  
Non-cash equity-based compensation expense
     2,783       3,309       6,863       6,205  
Exploration
     15,934       11,593       27,133       17,081  
Asset valuation adjustments
     9,969       —       9,995       —  
Interest expense and other
     18,469       16,099       33,878       35,008  
Income taxes
     (31,558 )     (21,322 )     (36,443 )     (2,589 )
Net loss attributable to noncontrolling interest
     (14,545 )     (14,982 )     (12,892 )     (14,888 )
Payments of deferred commodity derivative contract premiums
     (910 )     —       (69,536 )     (20,583 )
Non-cash derivative fair value loss
     84,851       238,194       365,678       300,370  
 
                        
Adjusted EBITDAX including hedge monetization
     112,452       248,197       414,879       416,673  
Changes in operating assets and liabilities
     2,511       4,064       101,765       (28,904 )
Other non-cash expenses
     12,076       4,187       13,996       6,540  
Interest expense and other
     (18,469 )     (16,099 )     (33,878 )     (35,008 )
Current income taxes
     2,653       (20,057 )     (1,071 )     (24,167 )
Cash exploration expense
     (661 )     296       (869 )     (1,536 )
Asset valuation adjustments
     (9,969 )     —       (9,995 )     —  
Payments of deferred commodity derivative contract premiums
     910       —       69,536       20,583  
Purchased options
     (8,981 )     —       (10,216 )     (1,866 )
 
                        
Net cash provided by operating activities
   $ 92,522     $ 220,588     $ 544,147     $ 352,315  
 
                        
                                 
    Three Months Ended June 30,     Six Months Ended June 30,  
    2009     2008     2009     2008  
Adjusted EBITDAX Excluding Hedge Monetization
                                
Net loss attributable to EAC
   $ (46,975 )   $ (35,720 )   $ (54,531 )   $ (4,500 )
Depletion, depreciation, and amortization
     74,434       51,026       144,734       100,569  
Non-cash equity-based compensation expense
     2,783       3,309       6,863       6,205  
Exploration
     15,934       11,593       27,133       17,081  
Asset valuation adjustments
     9,969       —       9,995       —  
Interest expense and other
     18,469       16,099       33,878       35,008  
Income taxes
     (31,558 )     (21,322 )     (36,443 )     (2,589 )
Net loss attributable to noncontrolling interest
     (14,545 )     (14,982 )     (12,892 )     (14,888 )
Payments of deferred commodity derivative contract premiums
     (910 )     —       (20,626 )     (20,583 )
Non-cash derivative fair value loss
     84,851       238,194       148,305       300,370  
 
                        
Adjusted EBITDAX excluding hedge monetization
     112,452       248,197       246,416       416,673  
Changes in operating assets and liabilities
     2,511       4,064       319,138       (28,904 )
Other non-cash expenses
     12,076       4,187       13,996       6,540  
Interest expense and other
     (18,469 )     (16,099 )     (33,878 )     (35,008 )
Current income taxes
     2,653       (20,057 )     (1,071 )     (24,167 )
Cash exploration expense
     (661 )     296       (869 )     (1,536 )
Asset valuation adjustments
     (9,969 )     —       (9,995 )     —  
Payments of deferred commodity derivative contract premiums
     910       —       20,626       20,583  
Purchased options
     (8,981 )     —       (10,216 )     (1,866 )
 
                        
Net cash provided by operating activities
   $ 92,522     $ 220,588     $ 544,147     $ 352,315  
 
                        
     “Adjusted EBITDAX” is used as a supplemental financial measure by EAC’s management and by external users of EAC’s financial statements, such as investors, commercial banks, research analysts, and others, to assess: (1) the financial performance of EAC’s assets without regard to financing methods, capital structure, or historical cost basis; (2) the ability of EAC’s assets to generate cash sufficient to pay interest costs and support its indebtedness; (3) EAC’s operating performance and return on capital as compared to those of other entities in our industry, without regard to financing or capital structure; and (4) the viability of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities.
     “Adjusted EBITDAX” should not be considered an alternative to net loss, operating income (loss), net cash provided by operating activities, or any other measure of financial performance presented in accordance with GAAP. EAC’s definition of “Adjusted EBITDAX” may not be comparable to similarly titled measures of another entity because all entities may not calculate “Adjusted EBITDAX” in the same manner.

 

 

Encore Acquisition Company
Non-GAAP Financial Measures (continued)
(in thousands, except per share amounts)
(unaudited)
     This press release also includes a discussion of “net income (loss) excluding certain items,” which is a non-GAAP financial measure. The following tables provide a reconciliation of “net income (loss) excluding certain items” to net loss, EAC’s most directly comparable financial measure calculated and presented in accordance with GAAP.
                                 
    Three Months Ended June 30,  
    2009     2008  
    Total     Per Diluted
Share		     Total     Per Diluted
Share		  
Net loss attributable to EAC
   $ (46,975 )   $ (0.91 )   $ (35,720 )   $ (0.68 )
Add: change in fair value in excess of premiums and OCI amortization
     58,755       1.14       197,051       3.69  
Add: asset valuation adjustments
     9,969       0.19       —       —  
Less: tax effect of above items
     (23,957 )     (0.46 )     (73,441 )     (1.37 )
 
                        
Net income (loss) excluding certain items
   $ (2,208 )   $ (0.04 )   $ 87,890     $ 1.64  
 
                        
Net Income Excluding Certain Items Including Hedge Monetization
                                 
    Six Months Ended June 30,  
    2009     2008  
    Total     Per Diluted
Share		     Total     Per Diluted
Share		  
Net loss attributable to EAC
   $ (54,531 )   $ (1.05 )   $ (4,500 )   $ (0.09 )
Add: change in fair value in excess of premiums and OCI amortization
     258,952       4.93       239,101       4.47  
Add: asset valuation adjustments
     9,995       0.19       —       —  
Less: tax effect of above items
     (99,435 )     (1.89 )     (89,111 )     (1.66 )
 
                        
Net income excluding certain items including hedge monetization
   $ 114,981     $ 2.18     $ 145,490     $ 2.72  
 
                        
Net Income Excluding Certain Items Excluding Hedge Monetization
                                 
    Six Months Ended June 30,  
    2009     2008  
    Total     Per Diluted
Share		     Total     Per Diluted
Share		  
Net loss attributable to EAC
   $ (54,531 )   $ (1.05 )   $ (4,500 )   $ (0.09 )
Add: change in fair value in excess of premiums and OCI amortization
     90,489       1.73       239,101       4.47  
Add: asset valuation adjustments
     9,995       0.19       —       —  
Less: tax effect of above items
     (35,943 )     (0.68 )     (89,111 )     (1.66 )
 
                        
Net income excluding certain items excluding hedge monetization
   $ 10,010     $ 0.19     $ 145,490     $ 2.72  
 
                        
     EAC believes that the exclusion of these items enables it to evaluate operations more effectively period-over-period and to identify operating trends that could otherwise be masked by the excluded items.
     “Net income (loss) excluding certain items” should not be considered an alternative to net loss, operating income (loss), net cash provided by operating activities, or any other measure of financial performance presented in accordance with GAAP. EAC’s definition of “net income (loss) excluding certain items” may not be comparable to similarly titled measures of another entity because all entities may not calculate “net income (loss) excluding certain items” in the same manner.