-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, A8Q9q3DxMDrbmu7yzosQXMVStPNzkiypL376q7+AXJiXAJRb5KEMDFWlBDfIyozJ lTLtis4gaFJMNFJKWy3Zmg== 0001275287-05-000820.txt : 20050303 0001275287-05-000820.hdr.sgml : 20050303 20050303075323 ACCESSION NUMBER: 0001275287-05-000820 CONFORMED SUBMISSION TYPE: 8-K PUBLIC DOCUMENT COUNT: 3 CONFORMED PERIOD OF REPORT: 20050302 ITEM INFORMATION: Results of Operations and Financial Condition ITEM INFORMATION: Regulation FD Disclosure ITEM INFORMATION: Financial Statements and Exhibits FILED AS OF DATE: 20050303 DATE AS OF CHANGE: 20050303 FILER: COMPANY DATA: COMPANY CONFORMED NAME: BRIGHAM EXPLORATION CO CENTRAL INDEX KEY: 0001034755 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 752692967 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 8-K SEC ACT: 1934 Act SEC FILE NUMBER: 000-22433 FILM NUMBER: 05656052 BUSINESS ADDRESS: STREET 1: 6300 BRIDGE POINT PARKWAY STREET 2: BLDG 2 SUITE 500 CITY: AUSTIN STATE: TX ZIP: 78730 BUSINESS PHONE: 5124273300 MAIL ADDRESS: STREET 1: 6300 BRIDGE POINT PARKWAY STREET 2: BLDG 2 SUITE 500 CITY: AUSTIN STATE: TX ZIP: 78730 8-K 1 be2208.txt ================================================================================ UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 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): March 2, 2005 BRIGHAM EXPLORATION COMPANY (Exact name of registrant as specified in its charter) Delaware 000-22433 75-2692967 (State or other jurisdiction (Commission (IRS Employer of incorporation) File Number) Identification No.) 6300 Bridgepoint Parkway Building Two, Suite 500 Austin, Texas 78730 (Address, including zip code, of principal executive offices) Registrant's telephone number, including area code: (512) 427-3300 -------------------------------------------------------------- (Former name or former address, if changed since last report.) 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: [ ] 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 240.14d-2(b)) [ ] Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13a-4(c)) ================================================================================ ITEM 2.02 RESULTS OF OPERATION AND FINANCIAL CONDITION. Registrant is furnishing its press release dated March 3, 2005, which announces its financial results for the quarter and year ended December 31, 2004 and its proved reserve volumes at December 31, 2004. It also includes our forecast for full year 2005 production volumes and our forecast for the first quarter 2005. The text of that press release is attached to this Report as Exhibit 99.1. is incorporated by reference herein. With the filing of this report on Form 8-K and the issuance of the attached press release, we are also updating our corporate presentation, which can be found on our website at WWW.BEXP3D.COM. We caution you that the information provided in our corporate presentation is given as of March 3, 2005 based on currently available information, and that we are not undertaking any obligation to update our estimates as conditions change or other information becomes available. ITEM 7.01 REGULATION FD DISCLOSURE. Registrant is furnishing its press release dated March 2, 2005, which announces its capital expenditure budget for 2005. The text of the press release is furnished as attached hereto as Exhibit 99.2. ITEM 9.01 FINANCIAL STATEMENTS AND EXHIBITS. (c) Exhibit 99.1 Press release dated March 3, 2005. Exhibit 99.2 Press release dated March 2, 2005. 2 SIGNATURE Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. BRIGHAM EXPLORATION COMPANY Date: March 3, 2005 By: /s/ Eugene B. Shepherd, Jr -------------------------- Eugene B. Shepherd, Jr. Executive Vice President & Chief Financial Officer 3 INDEX TO EXHIBITS Item Number Exhibit ----------- --------------------------------- 99.1* Press Release dated March 3, 2005 99.2* Press Release dated March 2, 2005 4 EX-99.1 2 be2208ex991.txt Exhibit 99.1 BRIGHAM EXPLORATION REPORTS YEAR END RESULTS INCLUDING RECORD 2004 FINANCIAL RESULTS AUSTIN, Texas, March 3 /PRNewswire-FirstCall/ -- Brigham Exploration Company (Nasdaq: BEXP) today announced its financial results for the fiscal year and quarter ended December 31, 2004 and its year-end reserve numbers. Highlights from our performance for 2004 include: -- 15% growth in 2004 production over production in 2003; -- 40% growth in revenue to $72.2 million over revenue in 2003 of $51.7 million; and -- 28% growth in operating income to $27.9 million over operating income in 2003 of $21.8 million. YEAR-END 2004 RESULTS Average net daily production volumes for 2004 were 34.1 MMcfe per day compared to 29.7 MMcfe per day in 2003. Revenues from the sale of oil and natural gas, net of hedging, grew 39% to $71.7 million in 2004 compared to $51.5 million last year. Higher production volumes for 2004 resulted in an increase in revenue of approximately $9.6 million while a 14% increase in our average equivalent sales price combined with a decrease in hedging losses increased revenues by $10.6 million. Our average realized prices for 2004 were $5.84 per Mcf for natural gas and $35.17 per barrel for oil, compared to $4.92 per Mcf and $28.17 per barrel in 2003. Our average realized price for 2004 includes losses from the cash settlement of hedging transactions of $0.21 per Mcf for natural gas and $4.96 per barrel for oil compared to $0.76 per Mcf for natural gas and $2.62 per barrel for oil in 2003. Production cost, which includes lease operating expenses and production taxes, were up 21% in 2004 and up 4% on a unit basis. An increase in costs for compressor rental and maintenance and saltwater disposal and an increase in production taxes due to an increase in the sales price we received from the sale of oil and natural gas were the primary reasons for the increase in our unit production costs. General and administrative expenses for 2004 were up 20% when compared to 2003. General and administrative expenses for 2004 included approximately $399,000 paid to outside consultants and our independent public accountants for the implementation of Section 404 of Sarbanes-Oxley and $181,813 related to the settlement of a legal dispute over the ownership of a well. Additional items that led to higher general and administrative expenses for the fourth quarter were increases in employee payroll and benefit expenses and fees paid to our external reserve engineers. Due to these higher costs, general and administrative expenses on a unit basis increased 5% in 2004 to $0.44 per Mcfe. Depletion of oil and natural gas properties for 2004 was $28.8 million ($2.35 per Mcfe) compared to $17 million ($1.59 per Mcfe) in 2003. An increase in production volumes accounted for 21% of the increase, while an increase in our depletion rate accounted for the remaining 79%. The increase in our depletion rate was due to a 15 Bcfe revision to our proved reserves at year-end 2004, an increase in finding and development costs in 2004 and an increase in future development costs associated with our year-end 2004 reserves. Interest expenses for 2004 were $3.1 million. The 35% decrease in interest expenses was primarily due to a decrease in our weighted average debt outstanding for 2004 combined with a lower interest rate that we paid on those outstanding borrowings. We recorded deferred income tax expenses of $9.1 million in 2004 compared to an income tax benefit of $1.6 million in 2003. Net income available to common stockholders for 2004 was $16.4 million ($0.39 diluted earnings per share) compared to net income of $14.8 million ($0.53 diluted earnings per share) in 2003. Our capital expenditures for oil and natural gas activities in 2004 and 2003 were: (in millions) 2004 2003 -------- -------- Drilling $ 68.2 $ 35.1 Land and G&G 12.9 5.9 Capitalized Cost 5.7 6.1 Net capital expenditures $ 86.8 $ 47.1 FOURTH QUARTER 2004 RESULTS Net daily production volumes for the fourth quarter 2004 were 34.1 MMcfe per day and were 16% higher when compared with production volumes in last year's fourth quarter. Higher production volumes, combined with higher commodity prices and a decrease in losses due to the settlement of hedging contracts led to a 70% increase in revenue from the sale of oil and natural gas. Production cost for the fourth quarter 2004 were $2.5 million ($0.81 per Mcfe) and 85% higher than production costs in the fourth quarter last year. On a unit basis, lease operating expenses for the fourth quarter 2004 were $0.59 compared to $0.44 in last year's fourth quarter. The primary reasons for the increase in lease operating expense were due to higher costs for salt-water disposal, compressor rental and maintenance, well service and repair and an increase in ad valorem taxes. Production taxes for the fourth quarter 2004 were $673,000 compared to $180,000 in the fourth quarter last year. On a unit basis, production taxes for the fourth quarter 2004 were $0.22 compared to $0.07 in last year's fourth quarter. Production taxes in the fourth quarter of 2003 included a reclassification of a credit that we received from the settlement of a gas imbalance liability with one of our participants. This reclassification resulted in a decrease in our total production taxes and production taxes on a unit basis in the fourth quarter of 2003. The credit, which based on preliminary settlement information was booked in the third quarter 2003 as additional revenue, was reclassified out of revenue as a reduction to production taxes in the fourth quarter. Due to the reclassification from revenue to production taxes both our production taxes and our production taxes on a per unit basis for the fourth quarter 2003 appear low. General and administrative expenses for the fourth quarter 2004 were up 55% when compared to general and administrative expenses in the fourth quarter of last year. General and administrative expenses for the fourth quarter 2004 included approximately $261,000 paid to outside consultants and our independent public accountants for the implementation of Section 404 of Sarbanes-Oxley and approximately $181,813 related to the settlement of a legal dispute over the ownership of a well. Additional items that contributed to the increase in general and administrative expenses were increases in financial reporting expenses and fees paid to our external reserve engineers. Due to these higher costs, general and administrative expenses on a unit basis increased 32% in the fourth quarter 2004 to $0.54 per Mcfe. Depletion expense for the fourth quarter 2004 was $12.5 million ($4.06 per Mcfe) compared to $5.1 million ($1.93 per Mcfe) in the fourth quarter last year. Higher production volumes in the fourth quarter represented 11% of this change, while an increase in our depletion rate represented 89% of the increase in our depletion expense. A decrease in our weighted average subordinated notes outstanding combined with a decrease in the interest rate that we paid on those notes and an increase in the amount of interest that we capitalized in the fourth quarter of 2004 were the primary reasons for the decrease in our reported interest expense for the fourth quarter 2004. Interest expenses for the fourth quarter 2004 were $636,000, compared to $1 million in 2003. We recorded deferred income tax expenses of $1.9 million in the fourth quarter of this year, compared to an income tax benefit of $1.6 million in the fourth quarter 2003. We reported net income available to common stockholders of $1.8 million ($0.04 per diluted share) for the fourth quarter 2004 versus net income of $3.6 million ($0.10 per diluted share) for the prior year period. Our capital expenditures during the fourth quarter of 2004 and 2003 were: ($'s in millions) Three Months Ended December 31, 2004 2003 --------- -------- Drilling $ 19.5 $ 14.5 Land and G&G 2.2 2.6 Capitalized Cost 1.1 1.5 Net capital expenditures $ 22.8 $ 18.6 FULL YEAR 2005 AND FIRST QUARTER 2005 FORECAST The following forecasts and estimates of our full year 2005 production volumes and first quarter 2005 results are forward looking statements subject to the risks and uncertainties identified in the "Forward Looking Statements Disclosure" at the end of this release. In addition to providing guidance for the first quarter 2005, we have elected to provide full year production guidance for 2005. We currently expect to grow production volumes in 2005 by 10% to 15% relative to our 2004 production. This would result in average daily production of between 37.5 and 39.2 MMcfe per day (78% natural gas) for 2005. We currently expect first quarter 2005 production volumes to average between 28 and 32 MMcfe per day (75% natural gas). For the first quarter 2005, lease operating expenses are projected to be $0.67 per Mcfe, production taxes are projected to be approximately 5.5% of pre-hedge oil and gas revenues, and general and administrative expenses are projected to be $1.3 million ($0.52 to $0.45 per Mcfe). Based on these production and cost estimates, assumed average NYMEX prices of $6.32 per MMBtu for natural gas and $47.45 per barrel for oil, and taking into account our current outstanding hedging contracts, we forecast that our first quarter revenue will be between $16.3 and $18.7 million and operating income will be between $6.2 and $7.6 million. Gene Shepherd, Brigham's Chief Financial Officer, commented, "2004 was obviously a disappointing year for the company in terms of our drilling results. However, 2004 was an outstanding year for the company from the standpoint of our financial performance. A combination of strong commodity prices, production growth and our ability to hold our costs relatively flat all contributed to record revenue and operating income. Furthermore, we exited 2004 with one of the strongest balance sheets that we have had in the company's history. The company's strong underlying financial performance and it's strong balance sheet should allow it to continue to benefit from Brigham's large and growing inventory of exploration and development prospects in this outstanding commodity price environment." 2004 PROVED RESERVES Our estimated net proved reserves volumes at December 31, 2004 totaled 121.3 Bcfe. Our estimated net proved developed reserves at December 31, 2004 totaled 60.2 Bcfe and our net proved undeveloped reserves totaled 61.1 Bcfe. During 2004, we added approximately 14.4 Bcfe in total proved reserves in our Texas Gulf Coast, Anadarko Basin and West Texas 3-D seismic projects. Our 2004 drilling program generated proved reserve additions that replaced 117% of our 12.3 Bcfe of reserve volumes produced during the year. However, reserve revisions at year-end 2004 totaled 15 Bcfe. These revisions resulted in large part from proved undeveloped wells drilled during 2004 at our Mills Ranch and Floyd fields. In addition, our late 2003 Floyd South discovery well, and its development well drilled in early 2004, both underperformed. In total, these revisions accounted for 83% of the total revisions. Approximately 84% of our year-end 2004 reserve volumes are natural gas and 50% are proved developed. At year-end 2004, the pre-tax present value ("Pre-tax PV10% Value") of our estimated proved reserves was $294 million. Our Pre-tax PV10% Value at year-end 2003 was $344 million. Our Pre-tax PV10% Value for 2004 was calculated using a Henry Hub natural gas price of $6.185 per MMBtu and a West Texas Intermediate Sweet price of $43.46 per barrel versus a Henry Hub natural gas price of $5.825 per MMBtu and a West Texas Intermediate Sweet price of $32.55 per barrel that were used for the 2003 year-end. Bud Brigham, the Chairman and CEO stated, "While we had a number of accomplishments during 2004, it was a very disappointing and we believe anomalous year in terms of reserves and finding costs. During most of the year we failed to achieve the drilling successes, both developmental and exploratory, that we have historically delivered. That changed late in the year, particularly with regard to our Sartwelle #3 Appling Deep Field discovery, which has the potential to become the largest field discovery in our history. However, this discovery occurred too late in the year to materially impact our 2004 reserves, though we expect it to have a very positive impact on our 2005 results. "Thus, for the first time in our fourteen-year history, our reserves at year-end were actually lower than that of the prior year. There are a number of contributing factors. First, we aggressively drilled our PUD's, with approximately 50% of our capital spent developing reserves already in our 2003 year-end reserve report. Unfortunately, several of our large proved undeveloped wells generated surprising results, despite being direct offsets to very strong producers, negatively impacting our year-end reserves. "Second, in prior years we drilled significant discoveries that elevated our overall results. In 2004 these came late in the year with our Sullivan C #30 well in our Triple Crown North joint venture, and with the Sartwelle #3 Appling Deep Field discovery. However, because these wells came in so late in the year their impact was limited. In the case of the Sartwelle #3 discovery, only 1.9 net Bcfe made our 2004 reserve report, thus we expect this field discovery to have a positive impact on our 2005 performance. "Since our first third party reserve report in 1992, inclusive of 2004, we've averaged a total proved all-sources finding cost of $1.79. The last disappointing year we had for finding costs was 1998. Subsequent to 1998, we generated five consecutive years of attractive finding costs and reserve growth. Since then, inclusive of 2004, our all sources total proved finding costs has averaged $1.98 per Mcfe. As was the case in 1998, we believe that many of the factors that negatively impacted 2004, position us for a very strong rebound in both reserves and finding costs in 2005." Equivalent Reserves (Bcfe) ------------------- 2004 Beginning Reserves 134,182 Discoveries & Extensions 14,369 Revisions of Previous Estimates (14,996) Production (12,265) 2004 Ending Reserves 121,290 CONFERENCE CALL INFORMATION Brigham management will host a conference call to discuss its operational and financial results for the fourth quarter and FY 2004 with investors, analysts and other interested parties on Thursday, March 3rd, at 9:00 a.m. Central time. To participate in the call, participants within the U.S. please dial 800-299-7089 and participants outside the U.S. please dial 617-801-9714. The participant passcode for the call is 31524905. A telephone recording of the conference call will be available to interested parties approximately two hours after the call is completed through 11:59 p.m. Central time on Thursday, March 17th. 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 61118666. 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 March 3, 2005, 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 Year End Results Including Record 2004 Financial Results and is dated March 2, 2005. To access the other financial and statistical information that will be covered by the conference call that will take place on March 3, 2005, 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 Fourth Quarter 2004 Conference Call and is dated March 2, 2005. 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 Private Securities Litigation Reform Act of 1995 that are based upon current expectations. Important factors that could cause actual results to differ materially from those in the forward looking statements include risks inherent in exploratory drilling activities, the timing and extent of changes in commodity prices, unforeseen engineering and mechanical or technological difficulties in drilling wells, availability of drilling rigs, land issues, federal and state regulatory developments and other risks more fully described in the company's filings with the Securities and Exchange Commission. 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: John Turner, Manager - Finance & Investor Relations (512) 427-3300 / investor@bexp3d.com BRIGHAM EXPLORATION COMPANY SUMMARY CONSOLIDATED STATEMENTS OF OPERATIONS (in thousands, except per share data)
Three Months Ended Year Ended December 31, December 31, ------------------------ ------------------------ 2004 2003 2004 2003 ---------- ---------- ---------- ---------- (unaudited) Revenues: Oil and natural gas sales $ 19,738 $ 11,598 $ 71,713 $ 51,545 Other 446 19 515 132 $ 20,184 $ 11,617 $ 72,228 $ 51,677 Costs and expenses: Lease operating 1,811 1,163 6,173 5,200 Production taxes 673 180 3,107 2,477 General and administrative 1,669 1,080 5,392 4,500 Depletion of natural gas and oil properties 12,450 5,119 28,824 16,972 Depreciation and amortization 178 180 722 629 Accretion of discount on ARO 42 32 159 142 $ 16,823 $ 7,754 $ 44,377 $ 29,920 Operating income $ 3,361 $ 3,863 $ 27,851 $ 21,757 Interest expense, net (636) (1,038) (3,144) (4,815) Interest income 29 9 84 45 Other income (expense) (a) 901 (351) 742 (601) Income before income taxes & cumulative effect of adoption of accounting principle $ 3,655 $ 2,483 $ 25,533 $ 16,386 Income tax benefit (1,866) 1,636 (9,120) 1,636 Cumulative effect of adoption of accounting principle - - - 268 Net income $ 1,769 $ 4,119 $ 16,413 $ 18,290 Preferred stock dividends & accretion - 521 - 3,448 Net income (loss) to common $ 1,769 $ 3,598 $ 16,413 $ 14,842 Net income (loss) to common per share: Basic $ 0.04 $ 0.11 $ 0.41 $ 0.64 Diluted $ 0.04 $ 0.10 $ 0.39 $ 0.53 Wt. Avg. common shares outstanding: Basic 42,005 32,346 40,445 23,363 Diluted 43,151 38,457 41,616 34,354 (a) Includes non-cash gains/(losses) related to our derivative contracts: $ 852 $ (419) $ 625 $ (669)
BRIGHAM EXPLORATION COMPANY PRODUCTION, SALES PRICES AND OTHER FINANCIAL DATA
Three Months Ended Year Ended December 31, December 31, ------------------------ ------------------------ 2004 2003 2004 2003 ---------- ---------- ---------- ---------- (unaudited) Avg. net daily production: Natural gas (MMcf) 25.8 19.0 24.5 17.7 Oil (Bbls) 1,375 1,754 1,590 1,999 Equivalent natural gas (MMcfe) (6:1) 34.1 29.5 34.1 29.7 Total net production: Natural gas (MMcf) 2,325 1,708 8,830 6,356 Oil (MBbls) 124 158 573 720 Equivalent natural gas (MMcfe) (6:1) 3,067 2,655 12,265 10,674 % Natural gas 76% 64% 72% 60% Sales prices (Before hedging): Natural gas ($/Mcf) $ 6.56 $ 4.36 $ 6.05 $ 5.68 Oil ($/Bbl) 47.84 29.76 40.13 30.79 Equivalent natural gas ($/Mcfe) (6:1) 6.90 4.58 6.23 5.46 Realized prices (Post hedging): Natural gas ($/Mcf) (a) $ 6.30 $ 4.23 $ 5.84 $ 4.92 Oil ($/Bbl) (a) 41.19 27.67 35.17 28.17 Equivalent natural gas ($/Mcfe) (6:1) (a) 6.44 4.37 5.85 4.83 (a) Includes the effects of hedging gains (losses) of: Natural gas ($/Mcf) $ (0.26) $ (0.13) $ (0.21) $ (0.76) Oil ($/Bbl) (6.65) (2.09) (4.96) (2.62)
SUMMARY CONSOLIDATED BALANCE SHEETS (in thousands)
December 31, December 31, 2004 2003 ------------ ------------ Assets: Current assets $ 20,994 $ 20,835 Natural gas and oil properties, net (full cost method) 255,820 197,311 Other property and equipment, net 1,209 1,219 Other non-current assets 2,125 4,851 Total assets $ 280,148 $ 224,216 Liabilities and stockholders' equity: Current liabilities $ 40,494 $ 35,579 Notes payable 21,000 19,000 Senior subordinated notes 20,000 20,000 Redeemable preferred stock, Series A 9,520 8,794 Deferred income tax liability 6,875 - Other non-current liabilities 2,986 2,498 Total liabilities $ 100,875 $ 85,871 Stockholders' equity 179,273 138,345 Total liabilities and stockholders' equity $ 280,148 $ 224,216
BRIGHAM EXPLORATION COMPANY SUMMARY CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands)
Three Months Ended Year Ended December 31, December 31, ------------------------ ------------------------ 2004 2003 2004 2003 ---------- ---------- ---------- ---------- (unaudited) Cash flows from operating activities: Net income $ 1,769 $ 4,119 $ 16,413 $ 18,290 Depletion, depreciation and amortization 12,628 5,299 29,546 17,601 Accretion of discount on ARO 42 32 159 142 Interest paid through issuance of add'l senior sub. notes - 308 - 1,196 Interest paid through issuance of add'l redeemable preferred stock 188 179 726 340 Amortization of deferred loan fees 192 244 766 1,053 Mkt value adjustments for derivatives instruments (852) 419 (625) 669 Cumulative effect of adoption of change in acctg prin - - - (268) Tax benefit for the exercise of stock options 577 - 577 - Deferred income tax expense (benefit) 1,309 (1,636) 8,543 (1,636) Changes in working capital and other items 3,023 302 276 4,304 Cash flows provided by operating activities $ 18,876 $ 9,266 $ 56,381 $ 41,691 Cash flows used by investing activities (23,162) (16,687) (84,645) (46,089) Cash flows (used) provided by financing activities (2,384) 2,184 24,766 (5,141) Net increase (decrease) in cash and cash equivalents $ (6,670) $ (5,237) $ (3,498) $ (9,539)
SUMMARY PER MCFE DATA (unaudited)
Three Months Ended Year Ended December 31, December 31, ------------------------ ------------------------ 2004 2003 2004 2003 ---------- ---------- ---------- ---------- Revenues: Natural gas and oil sales $ 6.44 $ 4.37 $ 5.85 $ 4.83 Other revenue 0.15 0.01 0.04 0.01 $ 6.59 $ 4.38 $ 5.89 $ 4.84 Costs and expenses: Lease operating 0.59 0.44 0.50 0.49 Production taxes 0.22 0.07 0.25 0.23 General and administrative 0.54 0.41 0.44 0.42 Depletion of natural gas and oil properties 4.06 1.93 2.35 1.59 Depreciation and amortization 0.06 0.07 0.06 0.06 Accretion of discount on ARO 0.01 0.01 0.01 0.01 $ 5.48 $ 2.93 $ 3.61 $ 2.80 Operating income $ 1.11 $ 1.45 $ 2.28 $ 2.04 Interest expense, net (a) (0.20) (0.45) (0.25) (0.45) Other income (expense) (b) 0.02 0.03 0.01 0.01 Adjusted income before dividends & accretion $ 0.93 $ 1.03 $ 2.04 $ 1.60
(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 BRIGHAM EXPLORATION COMPANY SUMMARY OF COMMODITY PRICE HEDGES OUTSTANDING AS OF MARCH 2, 2005 (unaudited)
FY 2005 FY 2006 Hedge ------------------- ------------------- Strategy Q1 Q2 Q3 Q4 Q1 ------------ -------- -------- -------- -------- -------- Natural Gas Collars: Daily MMBtu/d 5,750 6,978 1,957 652 -- volumes Floor $/MMBtu Cash flow $ 4.663 $ 4.931 $ 5.450 $ 5.450 -- (Purchased put) Cap $/MMBtu Cash flow $ 7.100 $ 7.077 $ 8.000 $ 8.000 -- (Written call) Natural Gas Three Way Costless Collars: Daily MMBtu/d 2,333 -- 3,261 2,174 1,667 volumes Floor $/MMBtu Cash flow $ 6.400 -- $ 6.000 $ 6.380 $ 6.750 (Purchased put) Cap $/MMBtu Cash flow $ 7.640 -- $ 7.200 $ 8.000 $ 8.800 (Written call) Written $/MMBtu Undesignated $ 5.500 -- $ 5.000 $ 5.250 $ 5.500 put Crude Oil Collars: Daily Bbls/d 305 205 -- -- -- volumes Floor $/Bbl Cash flow $ 25.56 $ 26.80 -- -- -- (Purchased put) Cap $/Bbl Cash flow $ 30.18 $ 32.51 -- -- -- (Written call) Crude Oil Three Way Costless Collars: Daily Bbls/d -- -- 163 163 -- volumes Floor $/Bbl Cash flow -- -- $ 40.00 $ 40.00 -- (Purchased put) Cap $/Bbl Cash flow -- -- $ 53.00 $ 53.00 -- (Written call) Written $/Bbl Undesignated -- -- $ 30.00 $ 30.00 -- put
Note: 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- 03/03/2005 /CONTACT: John Turner, Manager - Finance & Investor Relations of Brigham Exploration Company, +1-512-427-3300, or investor@bexp3d.com / /Web site: http://www.bexp3d.com / EX-99.2 3 be2208ex992.txt Exhibit 99.2 BRIGHAM EXPLORATION ANNOUNCES FY 2005 CAPITAL SPENDING PLAN AUSTIN, Texas, March 2 /PRNewswire-FirstCall/ -- Brigham Exploration Company (Nasdaq: BEXP) announced today the approval by its board of directors of a capital expenditure plan for 2005. Brigham plans to spend approximately $90.2 million on capital expenditures, an increase of approximately 4% relative to 2004. FY 2005 CAPITAL SPENDING PLAN We currently plan to spud 37 new wells in 2005 with an average working interest of 55%. Our total capital budget for 2005 represents an approximate increase of 4% over the amount we spent in 2004. Approximately 78% or $70.3 million of the 2005 capital budget will fund drilling expenditures, representing a 3% increase over 2004 drilling expenditures. Of the budgeted 2005 drilling expenditures, approximately 49% are allocated to drilling exploration wells and 51% is allocated to development drilling activities. In 2004 we spent approximately 30% of our total drilling expenditures on exploration wells and 70% on development drilling activities. Additionally, we estimate that during 2005 we will spend approximately $26.5 million in drilling expenditures to develop our proved undeveloped reserves at December 31, 2004, compared to approximately $34.7 spent in 2004. Our budgeted capital expenditure program for 2005 is as follows: (In Thousands) ------------- Drilling $ 70,308 Net land and G&G 13,065 Capitalized interest and G&A 6,184 Other non-oil & gas 615 Total $ 90,172 The amount and allocation of actual capital expenditures will depend upon a number of factors, including the impact of oil and gas prices, variances in drilling and service costs, the timing of our drilling wells and variances in forecasted production. ONSHORE GULF COAST We currently plan to spend approximately $43.8 million, or 63% of our total budgeted drilling expenditures for 2005 in our onshore Gulf Coast province. This drilling capital will be allocated to the drilling of 17 wells with an average working interest of 65%, to the drilling and completion of wells that were drilling at December 31, 2004 and other various development activities. Approximately 61% of the drilling capital budgeted for our onshore Texas Gulf Coast province is allocated to various development activities which includes the drilling of 10 (average net working interest of 65%) development wells. This capital is focused primarily on developing our Home Run and Triple Crown Vicksburg field discoveries, as well as the recent Appling Deep Frio field discovery. The remaining 39% of our drilling capital budgeted to our onshore Texas Gulf Coast province will be allocated to the drilling of seven (average net working interest of 64%) exploration wells in our onshore Gulf Coast province. For 2005, six of the eight higher potential and higher risk exploration tests that we plan to drill are located in our onshore Gulf Coast province. We will retain an average working interest of 67% in these tests, two of which are currently drilling. We also plan to spend approximately $9 million on land and seismic activities in our onshore Texas Gulf Coast province during 2005. ANADARKO BASIN We currently plan to spend approximately $23.5 million, or 33% of our total budgeted drilling expenditures for 2005 in our Anadarko Basin province. This drilling capital will be allocated to the drilling of 17 wells with an average working interest of 40%, to the drilling and completion of wells that were drilling at December 31, 2004 and other various development activities. Approximately 37% of the drilling capital budgeted for our Anadarko Basin province is allocated to various development activities which includes the drilling of 10 (37% net working interest) development wells. Our development drilling activities will include the drilling of six Granite Wash wells in Hemphill County Texas. We will operate four of these wells with an average working interest of 52% and will participate in the drilling of the other two Granite Wash wells with an average working interest of 3.2%. We also plan to drill three Springer Bar wells with an average working interest of 24% and one Springer Channel well with a working interest of 80%. The remaining 63% of our drilling capital budgeted for our Anadarko Basin province will be allocated to the drilling of six (average net working interest of 53%) exploration wells and the continued drilling and completion of a high potential exploration well that was drilling at December 31, 2004. Two of these wells, one new well and one well that was drilling at December 31, 2004, are among the eight higher potential and higher risk exploration tests referred to above. The first of these two higher potential tests is the Mills Ranch #2-98, which commenced drilling in 2004 and was drilling at December 31, 2004. We own a 100% working interest in the Mills Ranch #2-98, which is targeting the Arbuckle formation and various other shallower formations. The second high reserve potential test currently planned for 2005 is the Mountain Front #1. We will operate the Mountain Front #1 with a 100% working interest. The Mountain Front #1 is a reentry of an existing well, which will be directionally drilled to the Hunton and Arbuckle formations. The remaining five new exploration wells that we plan to drill in our Anadarko Basin province in 2005 will be Springer Channel wells where we will retain an average working interest of 43%. We also plan to spend approximately $3.5 million on land and seismic activities in our Anadarko Basin province during 2005. WEST TEXAS We currently plan to spend approximately $3 million, or 4% of our 2005 budgeted drilling expenditures in our West Texas province. This drilling capital will be allocated to the drilling of three exploration wells with an average working interest of 82% and to various development activities. We also plan to spend approximately $600,000 on land and seismic activities in our West Texas province during 2005. Bud Brigham, the Chairman and CEO stated, "In 2004 we were very intently focused on our development drilling, with approximately 70% of our capital going to development drilling. In addition, just over 50% of our drilling capital was invested in drilling proved undeveloped locations. In 2005, we will continue to aggressively drill in our deep developmental inventory, with just over 50% of our capital directed towards development drilling. However, we believe our 2005 program provides better balance between development and exploration. Importantly, 38% of our drilling capital is directed to proved undeveloped locations, thus 62% is directed towards the discovery of new reserves. Further, in 2005 relative to 2004, we are much more focused on our high potential exploration program, which has historically generated our field discoveries and subsequent surges in production and reserves. This year, approximately 37% of our drilling capital will go to the drilling of eight high potential wells, exposing us to an unrisked reserve potential of approximately 376 Bcfe." About Brigham Exploration Brigham Exploration Company is a leading 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 Statement Disclosure Except for the historical information contained herein, the matters discussed in this news release are forward looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are based upon current expectations. Important factors that could cause actual results to differ materially from those in the forward looking statements include risks inherent in exploratory drilling activities, the timing and extent of changes in commodity prices, unforeseen engineering and mechanical or technological difficulties in drilling wells, availability of drilling rigs, land issues, federal and state regulatory developments and other risks more fully described in the company's filings with the Securities and Exchange Commission. 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: John Turner, Manager of Finance & Investor Relations (512) 427-3300 SOURCE Brigham Exploration Company -0- 03/02/2005 /CONTACT: John Turner, Manager of Finance & Investor Relations of Brigham Exploration Company, +1-512-427-3300/ /First Call Analyst: / /FCMN Contact: jturner@bexp3d.com / /Web site: http://www.bexp3d.com/ -----END PRIVACY-ENHANCED MESSAGE-----