EX-99.1 2 v092336_ex99-1.htm Unassociated Document
NEWS RELEASE
FOR IMMEDIATE RELEASE

 
AUSTIN, Texas, Nov. 6 /PRNewswire-FirstCall/ -- Brigham Exploration Company (Nasdaq: BEXP) today announced its financial results for the third quarter and nine months ended September 30, 2007.
 
THIRD QUARTER 2007 RESULTS
 
Our net daily production volumes for the third quarter 2007 were 43.4 MMcfe per day, an increase of 20% when compared to the third quarter 2006. Third quarter 2007 revenues from the sale of oil and natural gas including derivative hedging settlements but excluding unrealized derivative hedging gains and losses were up 22% to $31.5 million when compared to the third quarter last year. Increased production volumes and increased oil and natural gas prices increased revenue by $4.0 and $1.0 million, respectively. Higher derivative hedging settlements increased oil and natural gas revenue by $0.6 million.
 
Our average realized price for natural gas during the third quarter 2007 was $7.31 per Mcf, which included a $0.60 per Mcf gain due to the settlement of our natural gas derivative contracts. This compares to an average realized price in the third quarter 2006 of $6.99, which included a $0.51 per Mcf gain due to the settlement of our natural gas derivative contracts. During the third quarter 2007, our average realized price for oil was $73.43 per barrel, which included a $0.22 per barrel loss due to the settlement of our oil derivative contracts. This compares to an average realized price in the third quarter 2006 of $72.36, which included a $0.50 per barrel gain due to the settlement of our oil derivative contracts.
 
Our per unit production costs, which include costs for operating and maintaining (O&M expense) our wells, expensed workovers, ad valorem taxes and production taxes, were down $0.31 per Mcfe, or 26%, when compared to the third quarter last year. Our per unit O&M expense decreased by $0.16 per Mcfe, or 25%, from the corresponding period last year because of a decrease in salt water disposal, chemical treating, and compressor and equipment rental. The September 1, 2007 sale of our Anadarko Basin Granite Wash properties largely drove the decrease in salt water disposal costs. Production tax expense decreased $0.15 per Mcfe, or 38%, from the third quarter 2006. The decrease was due to a $0.2 million increase in tax credits associated with high cost gas production tax abatements. The increase in tax credits is partially attributable to the fact that we are recording credits immediately upon commencing production from our Vicksburg and Mills Ranch wells given our 100% success rate in applying for credits rather than deferring recognition until receiving approval from relevant government authority. In addition, our ad valorem taxes decreased $0.03 per Mcfe, or 21%, due to a decrease in estimated property valuations for our oil and natural gas properties during 2007. These decreases were offset by an increase in expensed workovers of $0.03 per Mcfe, or 75%, largely attributable
to work performed in our Providence Field.
 
Per unit general and administrative (G&A) expense for the third quarter 2007 increased 5% to $0.64 per Mcfe from the third quarter 2006 as higher compensation and travel costs offset higher production volumes. Roughly 87% of the increase in compensation expense was attributable to an increase in non-cash share-based compensation expense under FAS 123(R). Our depletion expense for the third quarter 2007 was $14.8 million ($3.78 per Mcfe) compared to $11.9 million ($3.67 per Mcfe) in the third quarter last year. Our increased production volumes accounted for 85% of the increase in third quarter 2007 depletion expense, while our increased depletion rate accounted for the remaining 15% of the increase in depletion expense. The increase in our depletion rate was a result of an increase in the cost of reserve additions.
 
Our operating income for the third quarter 2007 increased by 27% to $10.1 million from the third quarter 2006.
 
Our net interest expense for the third quarter 2007 increased by $1.3 million, or 49%, from last year. The increase was associated with our higher weighted average debt outstanding and a higher weighted average cost of debt attributable to our $35 million senior notes add-on, which was completed in April 2007. Our weighted average debt outstanding for the third quarter 2007 was $186.6 million compared to $135.1 million in the third quarter last year.
 

Page 2
 
We recorded deferred income tax expense of $2.3 million in the third quarter of this year, compared to deferred income tax expense of $3.1 million in the third quarter last year. Lower taxes were attributable to both a decrease in income before taxes and the adjustment of our 2006 income tax accrual.
 
Our reported net income for the third quarter 2007 was $4.2 million ($0.09 per diluted share) compared to net income of $5.2 million ($0.12 per diluted share) in the third quarter last year. Our after-tax earnings in the third quarter 2007, excluding the impact of our unrealized derivative losses, were $4.4 million ($0.10 per diluted share) and our after-tax earnings in the third quarter 2006, excluding both unrealized derivative gains and non-cash gains associated with the ineffective portion of our cash flow hedges, were $3.7 million ($0.08 per diluted share). After-tax earnings excluding the above items is a non-GAAP measure and a reconciliation of GAAP net income to after-tax earnings excluding the effect of the above items is included in our accompanying financial tables found later in this release.
 
At September 30, 2007, we had $10.5 million in cash and $528.5 million of total assets. After repaying the outstanding balance under our senior credit facility with the $35.4 million in proceeds from our Anadarko Basin Granite Wash asset sale, we had a debt to book capitalization ratio of 38% at the end of the third quarter 2007.
 
The table below lists our oil and gas capital expenditures.
 
   
Three months ended September 30,
  
   
2007
  
2006
  
   
(in thousands)
  
           
Drilling
  
$
18,841
  
$
39,314
  
Net land and G&G
    
4,545
    
12,690
  
Capitalized costs
    
2,901
    
2,492
  
Capitalized FAS 143 ARO
    
97
    
37
  
Total oil and gas capital expenditures (a)
  
$
26,384
  
$
54,533
  

(a)  
Excludes the impact of our September 1, 2007 Anadarko Basin Granite Wash asset sale.

FIRST NINE MONTHS 2007 RESULTS 
 
Average daily production volumes for the first nine months 2007 were 43.6 MMcfe per day, an increase of 21% when compared to the first nine months of last year. First nine months 2007 revenues from the sale of oil and natural gas including derivative hedging settlements but excluding unrealized derivative gains and losses were up 23% to $95.7 million when compared to the corresponding period last year. Increased production volumes and 7% increase in our natural gas sales price increased revenue by $12.8 and $4.4 million, respectively. Oil and natural gas derivative hedging settlements increased revenue by $0.8 million.
 
Our average realized price for natural gas during the first nine months of 2007 was $7.56 per Mcf, which included a $0.33 per Mcf gain associated with the settlement of our natural gas derivative contracts. This compares to an average realized price of $7.12 per Mcf for the first nine months of last year, which included a $0.34 per Mcf gain due to the settlement of our natural gas derivative contracts. Our average realized price for oil for the first nine months of 2007 was $67.26 per barrel, which included a $0.31 per barrel gain due to the settlement of our oil derivative contracts. This compares to an average realized price in the first nine months of 2006 of $67.22, which was not impacted by the settlement of our oil derivative contracts.
 
Our per unit production costs for the first nine months 2007 were down $0.31 per Mcfe, or 27%, when compared to that in the same period last year. Production taxes decreased $0.22 per Mcfe, or 63%, because of a $2.4 million increase in the aforementioned production tax credits. O&M expense decreased $0.07 per Mcfe, or 11%, because of decreases in salt water disposal and chemical treating expense. Ad valorem taxes decreased $0.03 per Mcfe, or 21%, because of a decrease in property valuations for our oil and natural gas properties.
 
Increased production volumes more than offset higher stock compensation and payroll costs and resulted in our per unit G&A expense decreasing by 3% to $0.59 per Mcfe in the first nine months 2007. Roughly 62% of the increase in compensation expense was attributable to an increase in non-cash share-based compensation expense under FAS 123(R).
 

Page 3
 
Our depletion expense for the first nine months 2007 was $45.3 million ($3.85 per Mcfe) compared to $33.3 million ($3.41 per Mcfe) in the first nine months of last year. Increased production volumes accounted for 57% of the increase, while an increase in our depletion rate accounted for the remaining 43% of the increase. The increase in our depletion rate was primarily a result of an increase in the cost of reserve additions.
 
In the second quarter 2007, we recorded a $6.5 million non-cash ceiling test impairment charge ($4.1 million after-tax) on our oil and gas properties, which impacted our first nine months 2007 results. A ceiling test impairment is recorded when the capitalized cost of our oil and gas properties exceeds the present value (10% per annum discount rate) of estimated future net cash flows based on commodity prices at the end of the reporting period plus certain unevaluated property costs. Commodity spot prices at the end of June 2007 for Henry Hub natural gas and West Texas intermediate crude oil were $6.80 per Mcf and $70.47 per barrel.
 
Our operating income, impacted by the ceiling test impairment charge, declined to $23.1 million in the first nine months 2007 from $26.2 million in the first nine months 2006.
 
Our net interest expense for the first nine months 2007 increased by $4.2 million from the comparable period last year. This increase was primarily due to our higher weighted average debt outstanding and our higher weighted average interest cost associated with our senior notes that were issued in April 2006 and April 2007. Our weighted average debt outstanding for the first nine months of this year was $183.2 million versus $114.1 million for the comparable period last year.
 
We recorded deferred income tax expense of $5.2 million in the first nine months of this year compared to deferred income tax expense of $10.0 million in the first nine month of last year. Lower taxes were attributable to both a decrease in income before taxes and the adjustment of our 2006 income tax accrual.
 
Our reported net income for the first nine months 2007 was $8.4 million ($0.18 per diluted share) versus net income of $14.8 million ($0.33 per diluted share) for the same period last year. Our after-tax earnings in the first nine months 2007 without the effect of our unrealized derivative losses and ceiling test impairment charge were $14.3 million ($0.31 per diluted share) and our after-tax earnings in the first nine months 2006 excluding both unrealized derivative losses and non-cash gains associated with the ineffective portion of our cash flow hedges were $13.0 million ($0.29 per diluted share). After-tax earnings excluding the above items is a non-GAAP measure and a reconciliation of GAAP net income to after-tax earnings excluding the above items is included in our accompanying financial tables found later in this release.
 
The table below lists our oil and gas capital expenditures.
 
   
Nine months ended June 30,
  
   
2007
  
2006
  
   
(in thousands)
  
           
Drilling
  
$
71,068
  
$
106,931
  
Net land and G&G
    
9,969
    
24,244
  
Capitalized costs
    
8,849
    
7,273
  
Capitalized FAS 143 ARO
    
325
    
395
  
Total oil and gas capital expenditures (a)
  
$
90,211
  
$
138,843
  

(a)  
Excludes the impact of our September 1, 2007 Anadarko Basin Granite Wash asset sale.

FOURTH QUARTER 2007 FORECASTS

The following forecasts and estimates of our fourth quarter 2007 production volumes are forward looking statements subject to the risks and uncertainties identified in the "Forward Looking Statements Disclosure" at the end of this release. We currently expect our fourth quarter 2007 production volumes to average between 33 MMcfe per day and 37 MMcfe per day.
 

Page 4 
 
For the fourth quarter 2007, lease operating expenses are projected to be $0.89 per Mcfe based on the mid-point of our production guidance, production taxes are projected to be 3.25% to 3.5% of pre-hedge oil and natural gas revenues, and general and administrative expenses are projected to be $2.4 million ($0.80 to $0.71 per Mcfe).
 
MANAGEMENT COMMENTS
 
Gene Shepherd, Brigham's Chief Financial Officer commented, "Overall, we are pleased with our third quarter 2007 results, which were positively impacted by 20% higher production volumes and reductions in both lease operating and production tax expense. Furthermore, the recently completed Anadarko Basin Granite Wash asset sale significantly enhances the company's liquidity as we begin to lay out a capital expenditure plan for 2008. Unfortunately, our fourth quarter production guidance reflects the impact of our Anadarko Basin Granite Wash asset sale, the pause in our Vicksburg rig line and the natural decline in our Bayou Postillion Southern Louisiana wells. Our first quarter 2008 production volumes should be positively impacted by the late year resumption of our Vicksburg rig line, and the results from both our fourth quarter Mountrail County Bakken wells and our two high impact Southern Louisiana exploration wells."
 
"At the present time, we are formulating our 2008 capital expenditure budget and expect that our 2008 budget will likely increase relative to 2007, subject to commodity prices. Consistent with recent budgets, the continuation of what is largely development drilling in the Vicksburg will constitute a significant portion of the 2008 budget. In addition, we anticipate that Mountrail county Bakken drilling will also comprise a significant portion of our 2008 budget."
 
CONFERENCE CALL INFORMATION

Our management will host a conference call to discuss our operational and financial results for the third quarter 2007 with investors, analysts and other interested parties on Wednesday, November 7, 2007, at 10:00 a.m. eastern time. To participate in the call, participants within the U.S. please dial 866-314-9013 and participants outside the U.S. please dial 617-213-8053. The participant passcode for the call is 66867057. A telephone recording of the conference call will be available to interested parties approximately two hours after the call is completed through 12:00 p.m. eastern time on Friday, December 7, 2007. To access the recording, domestic callers dial 888-286-8010 and international callers dial 617-801-6888. The passcode for the conference call playback is 63514168. In addition, a live and archived web cast of the conference call will be available over the Internet at either http://www.bexp3d.com or http://www.streetevents.com.
 
A copy of this press release and other financial and statistical information about the periods covered by this press release and by the conference call that will take place on November 7, 2007, will be available on our website. To access the press release: go to http://www.bexp3d.com and click on News Releases. The file with a copy of the press release is named Brigham Exploration Reports Third Quarter 2007 Results and Provides Fourth Quarter 2007 Forecasts and is dated November 6, 2007. To access the other financial and statistical information that will be covered by the conference call that will take place on November 7, 2007, go to http://www.bexp3d.com and click on Event Calendar. The file with the other financial and statistical information is named Financial and Statistical Information for the Third Quarter 2007 Conference Call and is dated November 7, 2007.
 
ABOUT BRIGHAM EXPLORATION
 
Brigham Exploration Company is an independent exploration and production company that applies 3-D seismic imaging and other advanced technologies to systematically explore and develop onshore domestic natural gas and oil provinces. For more information about Brigham Exploration, please visit our website at http://www.bexp3d.com or contact Investor Relations at 512-427-3444.
 
FORWARD LOOKING STATEMENTS DISCLOSURE
 
Except for the historical information contained herein, the matters discussed in this news release are forward looking statements within the meaning of the federal securities laws. Important factors that could cause our actual results to differ materially from those contained in the forward looking statements include our growth strategies, our ability to successfully and economically explore for and develop oil and gas resources, anticipated trends in our business‚ our liquidity and ability to finance our exploration and development activities‚ market conditions in the oil and gas industry‚ our ability to make and integrate acquisitions and the impact of governmental regulation and other risks more fully described in the company's filings with the Securities and Exchange Commission. Forward looking statements are typically identified by use of terms such as "may," "will," "expect," "anticipate," "estimate" and similar words, although some forward-looking statements may be expressed differently. All forward looking statements contained in this release, including any forecasts and estimates, are based on management's outlook only as of the date of this release, and we undertake no obligation to update or revise these forward looking statements, whether as a result of subsequent developments or otherwise.
 
Contact:     
Rob Roosa, Finance Manager
(512) 427-3300
 

Page 5

BRIGHAM EXPLORATION COMPANY
SUMMARY CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per share data) (unaudited)
 
   
Three months ended
  
Nine months ended
  
   
September 30,
  
September 30,
  
   
2007
  
2006
  
2007
  
2006
  
                   
Revenues:
                  
Oil and natural gas sales 
  
$
29,481
  
$
24,487
  
$
92,250
  
$
74,977
  
Hedging settlements 
    
1,975
    
1,380
    
3,405
    
2,621
  
     
31,456
    
25,867
    
95,655
    
77,598
  
Unrealized hedging gains/ losses 
    
(327
)
  
99
    
(2,985
)
  
(288
)
     
31,129
    
25,966
    
92,670
    
77,310
  
Other revenue 
    
17
    
57
    
73
    
87
  
Total revenue
    
31,146
    
26,023
    
92,743
    
77,397
  
                           
Costs and expenses:
                          
Lease operating 
    
2,564
    
2,672
    
8,458
    
7,938
  
Production taxes 
    
951
    
1,259
    
1,573
    
3,455
  
General and administrative 
    
2,514
    
1,985
    
6,973
    
5,936
  
Depletion of oil and natural gas properties 
    
14,776
    
11,910
    
45,347
    
33,272
  
Impairment of oil and natural gas properties 
    
—
    
—
    
6,505
    
—
  
Depreciation and amortization 
    
147
    
140
    
468
    
376
  
Accretion of discount on asset retirement obligations 
    
87
    
80
    
298
    
229
  
     
21,039
    
18,046
    
69,622
    
51,206
  
Operating income
    
10,107
    
7,977
    
23,121
    
26,191
  
                           
Other income (expense):
                          
Interest expense, net 
    
(3,976
)
  
(2,669
)
  
(11,071
)
  
(6,899
)
Interest income 
    
271
    
518
    
536
    
1,072
  
Other income (expense) 
    
105
    
2,507
    
1,007
    
4,394
  
     
(3,600
)
  
356
    
(9,528
)
  
(1,433
)
Income before income taxes  
    
6,507
    
8,333
    
13,593
    
24,758
  
Income tax expense:
                          
Current 
    
—
    
—
    
—
    
—
  
Deferred 
    
(2,324
)
  
(3,087
)
  
(5,227
)
  
(9,971
)
     
(2,324
)
  
(3,087
)
  
(5,227
)
  
(9,971
)
Net income 
  
$
4,183
  
$
5,246
  
$
8,366
  
$
14,787
  
                           
Net income per share available to common stockholders:
                          
Basic 
  
$
0.09
  
$
0.12
  
$
0.19
  
$
0.33
  
Diluted 
  
$
0.09
  
$
0.12
  
$
0.18
  
$
0.33
  
                           
Weighted average shares outstanding:
                          
Basic 
    
45,123
    
45,027
    
45,085
    
45,005
  
Diluted 
    
45,477
    
45,294
    
45,490
    
45,451
  


Page 6
 
BRIGHAM EXPLORATION COMPANY
PRODUCTION, SALES PRICES AND OTHER FINANCIAL DATA
(unaudited)

   
Three months ended September 30,
  
Nine months ended September 30,
  
   
2007
  
2006
  
2007
  
2006
  
Average net daily production:
                  
Natural gas (MMcf)
    
37.0
    
29.1
    
37.0
    
28.8
  
Oil (Bbls)
    
1,078
    
1,166
    
1,104
    
1,220
  
Equivalent natural gas (MMcfe) (6:1)
    
43.4
    
36.1
    
43.6
    
36.2
  
                           
Total net production:
                          
Natural gas (MMcf)
    
3,327
    
2,616
    
9,997
    
7,789
  
Oil (MBbls)
    
97
    
105
    
298
    
330
  
Equivalent natural gas (MMcfe) (6:1)
    
3,909
    
3,245
    
11,784
    
9,766
  
% Natural gas
    
85
%
  
81
%
  
85
%
  
80
%
                           
Sales price:
                          
Natural gas ($/Mcf)
  
$
6.71
  
$
6.48
  
$
7.23
  
$
6.78
  
Oil ($/Bbl)
    
73.65
    
71.86
    
66.95
    
67.22
  
Equivalent natural gas ($/Mcfe) (6:1)
    
7.54
    
7.55
    
7.83
    
7.68
  
                           
Sales price including derivative settlement gains (losses):
                          
Natural gas ($/Mcf)
 
$
7.31
  
$
6.99
  
$
7.56
  
$
7.12
  
Oil ($/Bbl)
    
73.43
    
72.36
    
67.26
    
67.22
  
Equivalent natural gas ($/Mcfe) (6:1)
    
8.05
    
7.97
    
8.12
    
7.95
  
                           
Sales price including derivative settlement gains (losses) and unrealized gains (losses):
                          
Natural gas ($/Mcf)
 
$
7.31
    
NA
  
$
7.34
    
NA
  
Oil ($/Bbl)
    
70.35
    
NA
    
64.60
    
NA
  
Equivalent natural gas ($/Mcfe) (6:1)
   
7.96
    
NA
    
7.86
    
NA
  

SUMMARY CONSOLIDATED BALANCE SHEETS
(in thousands)

   
September 30, 2007
  
December 31, 2006
  
Assets:
  
(unaudited)
      
Current assets
  
$
34,062
  
$
31,218
  
Oil and natural gas properties, net (full cost method)
    
487,832
    
485,525
 
Other property and equipment, net
    
1,072
    
936
  
Other non-current assets
    
5,504
    
4,908
  
Total assets
  
$
528,470
  
$
522,587
  
               
Liabilities and stockholders' equity:
              
Current liabilities
  
$
38,085
  
$
57,453
  
Senior notes
    
158,432
    
123,434
  
Senior credit facility
   
—
    
25,900
  
Mandatorily redeemable preferred stock, Series A
    
10,101
    
10,101
  
Deferred income tax liability
    
38,394
    
34,609
  
Other taxes payable
    
2,159
    
—
  
Other non-current liabilities
    
5,034
    
5,075
  
Total liabilities
  
$
252,205
  
$
256,572
  
Stockholders' equity
    
276,265
    
266,015
  
Total liabilities and stockholders' equity
  
$
528,470
  
$
522,587
  


Page 7

BRIGHAM EXPLORATION COMPANY
SUMMARY CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands) (unaudited)

   
Three months ended September 30,
  
Nine months ended September 30,
  
   
2007
  
2006
  
2007
  
2006
  
               
Cash flows from operating activities:
                  
Net income
  
$
4,183
  
$
5,246
  
$
8,366
  
$
14,787
  
Depletion, depreciation and amortization
    
14,923
    
12,050
    
45,815
    
33,648
  
Impairment of oil and gas properties
    
—
    
—
    
6,505
    
—
  
Accretion of discount on ARO
    
87
    
80
    
298
    
229
  
Amortization of deferred loan fees and debt issuance costs
    
252
    
205
    
713
    
1,473
  
Non-cash stock compensation
    
617
    
291
    
1,455
    
1,134
  
Market value adjustments for derivatives instruments
    
327
    
(2,436
)
  
2,985
    
(2,926
)
Deferred income tax expense
    
2,324
    
3,087
    
5,227
    
9,971
  
Other noncash items
    
(4
)
  
—
    
(4
)
  
64
  
Changes in operating assets and liabilities
   
3,367
    
(3,682
)
  
1,992
    
15,915
  
Cash flows provided by operating activities
  
$
26,076
  
$
14,841
  
$
73,352
  
$
74,295
  
                           
Cash flows used by investing activities
    
(1,673
)
  
(13,272
)
  
(75,163
)
  
(126,139
)
Cash flows (used) provided by financing activities
    
(26,190
)
  
(3
)
  
8,007
    
57,483
  
Net increase (decrease) in cash and cash equivalents
  
$
(1,787
)
$
1,566
  
$
6,196
  
$
5,639
  
 
SUMMARY PER MCFE DATA
(unaudited)

   
Three months ended September 30,
  
Nine months ended September 30,
  
   
2007
  
2006
  
2007
  
2006
  
Revenues:
                  
Oil and natural gas sales
  
$
7.54
  
$
7.55
  
$
7.83
  
$
7.68
  
Hedge settlements
    
0.51
    
0.43
    
0.29
    
0.27
  
Unrealized hedge gains (losses)
    
(0.08
)
  
0.03
    
(0.25
)
  
(0.03
)
Other revenue
    
0.00
    
0.02
    
0.01
    
0.01
  
   
$
7.97
  
$
8.03
  
$
7.88
  
$
7.93
  
Costs and expenses:
                          
Lease operating
    
0.66
    
0.82
    
0.72
    
0.81
  
Production taxes
    
0.24
    
0.39
    
0.13
    
0.35
  
General and administrative
    
0.64
    
0.61
    
0.59
    
0.61
  
Depletion of oil and natural gas properties
    
3.78
    
3.67
    
3.85
    
3.41
  
Impairment of oil and natural gas properties
    
0.00
    
0.00
    
0.55
    
0.00
  
Depreciation and amortization
    
0.04
    
0.04
    
0.04
    
0.04
  
Accretion of discount on ARO
    
0.02
    
0.02
    
0.03
    
0.02
  
   
$
5.38
  
$
5.55
  
$
5.91
  
$
5.24
  
Operating income
  
$
2.59
  
$
2.48
  
$
1.97
  
$
2.69
  
                           
Interest expense, net of interest income (a)
    
(0.95
)
  
(0.66
)
  
(0.89
)
  
(0.60
)
Other income (expense) (b)
    
0.03
    
0.05
    
0.09
    
0.12
  
Adjusted income
  
$
1.67
  
$
1.87
  
$
1.17
  
$
2.21
  
 
(a) Calculated as interest expense minus interest income divided by production for period.
(b) Excludes non-cash gains/(losses) arising from hedge accounting for certain of our oil and natural gas hedges.


Page 8

BRIGHAM EXPLORATION COMPANY
RECONCILIATION OF GAAP NET INCOME TO AFTER-TAX EARNINGS
EXCLUDING THE EFFECT OF CERTAIN ITEMS
(in thousands)

   
Three months ended September 30,
  
Nine months ended September 30,
  
   
2007
  
2006
  
2007
  
2006
  
                   
Net income (loss) as reported
  
$
4,183
  
$
5,246
  
$
8,366
  
$
14,787
  
Unrealized derivative (gains) losses
    
327
    
(99
)
  
2,985
    
288
  
Unrealized derivative (gains) losses on ineffective hedges
    
—
    
(2,336
)
  
—
    
(3,213
)
Impairment of oil and natural gas properties
    
—
    
—
    
6,505
    
—
  
Tax impact
    
(117
)
  
902
    
(3,541
)
  
1,178
  
Earnings excluding the effect of certain items
  
$
4,393
  
$
3,713
  
$
14,315
  
$
13,040
  

Earnings without the effect of certain items represents net income excluding the following: unrealized gains and losses on derivative contracts; unrealized gains and losses related to ineffectiveness on our derivatives that were previously classified as cash flow hedges; and our non-cash impairment charge on our oil and gas properties. Management believes that exclusion of these items enhances comparability of operating results between periods.

SUMMARY OF COMMODITY PRICE HEDGES OUTSTANDING AS OF NOVEMBER 5, 2007
(unaudited)

       
Hedge
  
2007
  
2008
  
2009
  
       
Strategy
  
Q4
  
Q1
  
Q2
  
Q3
  
Q4
  
Q1
  
Q2
  
                                       
Natural Gas Collars:
                                  
Daily volumes
   MMBtu/d          
16,739
    
12,857
    
8,242
    
7,826
    
543
    
—
    
—
  
Floor
 
$/MMBtu
   Cash flow  
$
7.698
  
$
8.203
  
$
6.980
  
$
6.948
  
$
7.250
  
$
—
  
$
—
  
Cap
  
$/MMBtu
   Cash flow  
$
12.242
  
$
13.574
  
$
9.735
  
$
9.843
  
$
10.400
  
$
—
  
$
—
  
                                                         
Natural Gas Three Way Costless Collars:
                                    
Daily volumes
   MMBtu/d          
—
    
—
    
—
    
—
    
1,630
    
1,667
    
—
  
Floor
 
$/MMBtu
   Cash flow  
$
—
  
$
—
  
$
—
  
$
—
  
$
8.00
  
$
8.00
  
$
—
  
Cap
 
$/MMBtu
   Cash flow  
$
—
  
$
—
  
$
—
  
$
—
  
$
5.50
  
$
5.50
  
$
—
  
Written put
  
$/MMBtu
   Undesignated  
$
—
  
$
—
  
$
—
  
$
—
  
$
10.35
  
$
10.35
  
$
—
  
                                                         
Oil Collars:
                                                        
Daily volumes
   Bbls/d          
603
    
478
    
385
    
272
    
228
    
100
    
99
  
Floor
  
$/Bbl
   Cash flow  
$
59.83
  
$
60.61
  
$
61.55
  
$
61.65
  
$
59.96
  
$
62.00
  
$
62.00
  
Cap
  
$/Bbl
   Cash flow  
$
83.87
  
$
84.15
  
$
81.45
  
$
81.66
  
$
79.50
  
$
81.75
  
$
81.75
  
 
Hedged volumes and prices reflected in this table represent average contract amounts for the quarterly periods presented; natural gas hedge prices and crude oil hedge contract prices are based on NYMEX pricing.
 
SOURCE Brigham Exploration Company
-0-
 11/06/2007
/CONTACT:
 Rob Roosa, Finance Manager of Brigham Exploration Company, +1-512-427-3300/
/First Call Analyst: /
/FCMN Contact: /
/Web site: http://www.bexp3d.com /
(BEXP)
 
CO: Brigham Exploration Company
ST: Texas
IN: OIL
SU: ERN ERP CCA