8-K

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): May 6, 2008

Brigham Exploration Company

(Exact name of registrant as specified in its charter)

Delaware	000-22433	75-2692967
(State or other jurisdiction of incorporation)	(Commission File Number)	(IRS Employer 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.

We are furnishing our press release dated May 6, 2008, which announced our financial results for the first quarter and three months ended March 31, 2008 and provided second quarter 2008 forecasts.  The text of that press release is attached to this Report as Exhibit 99.1 and is incorporated by reference herein.

In addition to 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 May 6, 2008 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.

We are also furnishing our press release dated May 6, 2008, which provided an operational update.  The text of the press release is furnished as attached hereto as Exhibit 99.2.

Item 9.01  Financial Statements and Exhibits.

(d) Exhibit 99.1Press Release dated May 6, 2008.

Exhibit 99.2Press Release dated May 6, 2008.

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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:May 7, 2008

By:	/s/ Eugene B. Shepherd, Jr.
	Eugene B. Shepherd, Jr.
	Executive Vice President &
	Chief Financial Officer

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INDEX TO EXHIBITS

Item Number	Exhibit
99.1	Press Release dated May 6, 2008.
99.2	Press Release dated May 6, 2008.

EX-99.1

Exhibit 99.1

NEWS RELEASE FOR IMMEDIATE RELEASE

BRIGHAM EXPLORATION REPORTS FIRST QUARTER 2008 RESULTS

Austin, TX – May 6, 2008 -- Brigham Exploration Company (NASDAQ:BEXP) today announced financial results for the quarter ended March 31, 2008.

FIRST QUARTER 2008 RESULTS

Revenues from the sale of oil and natural gas including hedge settlements but excluding unrealized mark-to-market hedging gains and losses for the first quarter 2008 were up 2% to $30.4 million when compared to the first quarter 2007.  Higher realized prices increased revenues by $8.1 million, while lower production volumes and lower hedging gains decreased revenues by $6.0 million and $1.5 million, respectively.  Our average net daily production volumes for the first quarter 2008 were 32.2 MMcfe per day, down 22% when compared to the first quarter 2007.

Our average realized price for natural gas in the first quarter 2008 was $9.07 per Mcf, which included a $0.24 per Mcf gain associated with the settlement of our natural gas derivative contracts.  This compares to an average realized price in the first quarter 2007 of $7.76 which included a $0.44 per Mcf gain due to the settlement of our natural gas derivative contracts.  During the first quarter 2008, our average realized price for oil was $90.48 per barrel, which included a $5.02 per barrel loss due to the settlement of our oil derivative contracts.  This compares to an average realized price in the first quarter 2007 of $55.68, which included a $0.93 per barrel gain due to the settlement of our oil derivative contracts.

Our first quarter production costs, which include costs for operating and maintaining (O&M expense) our producing wells, expensed workovers, ad valorem taxes and production taxes, were $1.47 per Mcfe compare to $0.71 per Mcfe in the first quarter 2007.  This increase partially resulted from a $0.42 per Mcfe increase in production taxes related to a $1.3 million reduction in production tax abatements received in the first quarter 2008 versus that in the first quarter 2007.  Production costs also increased because of a $0.32 per Mcfe increase in expensed workovers.  Unanticipated workovers of two of our existing wells accounted for the bulk of the higher expensed workover costs.

Per unit general and administrative (G&A) expense for the first quarter 2008 was $0.90 per Mcfe compared to $0.59 per Mcfe in the first quarter 2007.  Lower production volumes and higher compensation costs accounted for the bulk of the increase in per unit G&A expense.

Our depletion expense for the first quarter 2008 was $12.4 million ($4.30 per Mcfe) compared to $14.0 million ($3.76 per Mcfe) in the first quarter 2007.  Our higher depletion rate increased depletion expense by $1.6 million while our lower production volumes decreased depletion expense by $3.1 million.  The increase in our depletion rate was a result of an increase in the cost of reserve additions.

Our net interest expense for the first quarter 2008 was essentially flat with that in the first quarter 2007.  Our weighted average debt outstanding for the first quarter 2008 was $182.8 million as compared to $171.7 million for the comparable period last year.

We recorded deferred income tax expense of $1.0 million in the first quarter of this year compared to deferred income tax expense of $1.0 million in the first quarter last year.

Our reported net income for the first quarter 2008 was $1.5 million ($0.03 per diluted share) versus net income of $1.9 million ($0.04 per diluted share) for the same period last year.  Our after-tax earnings in the first quarter 2008 excluding the effect of our unrealized mark-to-market hedging losses were $4.8 million ($0.11 per diluted share) and our after-tax earnings in the first quarter 2007 excluding unrealized mark-to-market hedging losses were $5.1 million ($0.11 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.

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SECOND QUARTER 2008 FORECASTS

The following forecasts and estimates of our second quarter 2008 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.  Heavy rainfalls have resulted in flooding conditions in Southern Louisiana, including the Atchafalaya Basin where our Bayou Postillion project is located.  These unfavorable conditions have necessitated shutting in two wells that we were previously forecasting would have averaged net production of approximately 5 MMcfe per day in the second quarter.  We are currently estimating that from the date these two wells went off line until production is reestablished that we will lose 36 days of second quarter production volumes.  Including this impact, we currently expect our second quarter 2008 production volumes to average between 30 MMcfe per day and 34 MMcfe per day.

For the second quarter 2008, lease operating expenses are projected to be $0.95 per Mcfe based on the mid-point of our production guidance, production taxes are projected to be approximately 3.85% to 3.95% of pre-hedge oil and natural gas revenues, and general and administrative expenses are projected to be $2.5 million ($0.93 to $0.82 per Mcfe).

MANAGEMENT COMMENTS

Gene Shepherd, Brigham’s Chief Financial Officer, commented, “With our continuous rig line in the Bakken, combined with up to two new Vicksburg wells and one new southern Louisiana well impacting our second quarter volumes, we believe we have the opportunity to resume sequential quarterly production growth in the second quarter of 2008, despite the temporary shut in of some of our Southern Louisiana production.  Furthermore, the second quarter of 2008 will be our first opportunity to see the benefits from both our unconventional Williston Basin activities and our conventional Gulf Coast activities enhancing and complementing one another.

CONFERENCE CALL INFORMATION

Our management will host a conference call to discuss operational and financial results for the first quarter 2008 with investors, analysts and other interested parties on Wednesday, May 7, at 10:00 a.m. Eastern Time.  To participate in the call, participants within the U.S. please dial 888-713-4215 and participants outside the U.S. please dial 617-213-4867.  The participant passcode for the call is 12965380.  Participants may pre-register for the call at https://www.theconferencingservice.com/prereg/key.process?key=P8FVW9W8F.  Pre-registrants will be issued a pin number to use when dialing into the live call which will provide quick access to the conference by bypassing the operator upon connection.  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 Saturday, June 7, 2008.  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 74228745.  In addition, a live and archived web cast of the conference call will be available over the Internet at either www.bexp3d.com or 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 Wednesday, May 7, 2008, will be available on our website.  To access the press release: go to www.bexp3d.com and click on News Releases.  The file with a copy of the press release is named Brigham Exploration Reports First Quarter 2008 Results and is dated Tuesday, May 6, 2008.  To access the other financial and statistical information that will be covered by the conference call that will take place on Wednesday, May 7, 2008, go to 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 First Quarter 2008 Conference Call and is dated Tuesday, May 6, 2008.

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 www.bexp3d.com or contact Investor Relations at 512-427-3444.

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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, 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

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BRIGHAM EXPLORATION COMPANY

SUMMARY CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data) (unaudited)

	Three Months Ended
	March 31,
	2008			2007
Revenues:
Oil and natural gas sales	$	30,510		$	28,486
Hedging settlements		(62	)		1,424
		30,448			29,910
Unrealized hedging gains(losses)		(5,394	)		(4,916	)
		25,054			24,994
Other revenue		17			27
Total Revenue		25,071			25,021
Costs and expenses:
Lease operating		2,986			2,569
Production taxes		1,283			71
General and administrative		2,593			2,178
Depletion of oil and natural gas properties		12,443			13,959
Depreciation and amortization		147			163
Accretion of discount on asset retirement obligations		91			117
		19,543			19,057
Operating income		5,528			5,964
Other income (expense):
Interest expense, net		(3,419	)		(3,417	)
Interest income		75			131
Other income (expense)		307			190
		(3,037	)		(3,096	)
Income before income taxes	$	2,491		$	2,868
Income tax expense:
Current		—			—
Deferred		(964	)		(995	)
		(964	)		(995	)
Net income	$	1,527		$	1,873
Net income per share available to common stockholders:
Basic	$	0.03		$	0.04
Diluted	$	0.03		$	0.04
Weighted average shares outstanding:
Basic		45,261			45,051
Diluted		45,770			45,430

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BRIGHAM EXPLORATION COMPANY

PRODUCTION, SALES PRICES AND OTHER FINANCIAL DATA

(unaudited)

	Three Months Ended March 31,
	2008			2007
Average net daily production:
Natural gas (MMcf)		24.4			33.1
Oil (Bbls)		1,298			1,352
Equivalent natural gas (MMcfe) (6:1)		32.2			41.2
Total net production:
Natural gas (MMcf)		2,193			2,982
Oil (MBbls)		117			122
Equivalent natural gas (MMcfe) (6:1)		2,894			3,712
% Natural gas		76	%		80	%
Sales price:
Natural gas ($/Mcf)	$	8.83		$	7.32
Oil ($/Bbl)		95.50			54.75
Equivalent natural gas ($/Mcfe) (6:1)		10.54			7.67
Sales price including derivative settlement gains (losses):
Natural gas ($/Mcf)	$	9.07		$	7.76
Oil ($/Bbl)		90.48			55.68
Equivalent natural gas ($/Mcfe) (6:1)		10.52			8.05
Sales price including derivative settlement gains (losses) and unrealized gains (losses):
Natural gas ($/Mcf)	$	6.71		$	6.23
Oil ($/Bbl)		88.45			52.78
Equivalent natural gas ($/Mcfe) (6:1)		8.66			6.73

SUMMARY CONSOLIDATED BALANCE SHEETS

(in thousands)

	March 31, 2008		December 31, 2007
Assets:
Current assets	$	29,562	$	32,505
Oil and natural gas properties, net (full cost method)		543,267		510,207
Other property and equipment, net		1,072		1,034
Other non-current assets		5,038		4,682
Total assets	$	578,939	$	548,428
Liabilities and stockholders' equity:
Current liabilities	$	59,657	$	41,718
Senior notes		158,551		158,492
Senior credit facility		19,000		10,000
Mandatorily redeemable preferred stock, Series A		10,101		10,101
Deferred income tax liability		42,609		41,625
Other non-current liabilities		7,806		7,465
Total liabilities	$	297,724	$	269,401
Stockholders' equity		281,215		279,027
Total liabilities and stockholders' equity	$	578,939	$	548,428

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BRIGHAM EXPLORATION COMPANY

SUMMARY CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands) (unaudited)

	Three Months Ended March 31,
	2008			2007
Cash flows from operating activities:
Net income	$	1,527		$	1,873
Depletion, depreciation and amortization		12,590			14,122
Accretion of discount on ARO		91			117
Amortization of deferred loan fees and debt issuance costs		255			214
Non-cash stock compensation		414			421
Market value adjustments for derivatives instruments		5,394			4,916
Deferred income tax expense		964			995
Other noncash items		(28	)		—
Changes in operating assets and liabilities		7,128			(7,074	)
Cash flows provided by operating activities	$	28,335		$	15,584
Cash flows used by investing activities		(45,034	)		(48,222	)
Cash flows (used) provided by financing activities		9,002			35,489
Net increase (decrease) in cash and cash equivalents	$	(7,697	)	$	2,851

SUMMARY PER MCFE DATA

(unaudited)

	Three Months Ended March 31,
	2008			2007
Revenues:
Oil and natural gas sales	$	10.54		$	7.67
Hedging Settlements		(0.02	)		0.38
Unrealized Hedging Gains / (Losses)		(1.86	)		(1.32	)
Other revenue		0.00			0.01
	$	8.66		$	6.74
Costs and expenses:
Lease operating		1.03			0.69
Production taxes		0.44			0.02
General and administrative		0.90			0.59
Depletion of natural gas and oil properties		4.30			3.76
Depreciation and amortization		0.05			0.04
Accretion of discount on ARO		0.03			0.03
	$	6.75		$	5.13
Operating income	$	1.91		$	1.61
Interest expense, net of interest income (a)		(1.16	)		(0.89	)
Other income (expense) (b)		0.11			0.05
Adjusted income	$	0.86		$	0.77
(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.

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BRIGHAM EXPLORATION COMPANY

RECONCILIATION OF GAAP NET INCOME TO AFTER-TAX EARNINGS

EXCLUDING THE EFFECT OF CERTAIN ITEMS

(in thousands)

	Three months ended March 31,
	2008			2007
Net income (loss) as reported	$	1,527		$	1,873
Unrealized derivative (gains) losses		5,394			4,916
Tax impact		(2,087	)		(1,706	)
Earnings excluding the effect of certain items	$	4,834		$	5,083

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.

BRIGHAM EXPLORATION COMPANY

SUMMARY OF COMMODITY PRICE HEDGES OUTSTANDING AS OF MAY 6, 2008

(unaudited)

		2008						2009
			Q2		Q3		Q4		Q1		Q2		Q3
Natural Gas Costless Collars:
Daily volumes	MMBtu/d		15,055		12,283		7,391		6,778		4,615		4,565
Floor	$/MMBtu	$	7.135	$	7.418	$	8.507	$	8.750	$	7.536	$	7.536
Cap	$/MMBtu	$	9.536	$	9.952	$	10.810	$	11.092	$	10.225	$	10.225
Natural Gas Three Way Costless Collars:
Daily volumes	MMBtu/d		—		—		1,630		1,667		—		—
Floor	$/MMBtu	$	—	$	—	$	8.00	$	8.00	$	—	$	—
Written Put	$/MMBtu	$	—	$	—	$	5.50	$	5.50	$	—	$	—
Cap	$/MMBtu	$	—	$	—	$	10.35	$	10.35	$	—	$	—
Oil Costless Collars:
Daily volumes	Bbls/d		516		533		446		333		99		—
Floor	$/Bbl	$	68.18	$	74.92	$	73.44	$	79.15	$	62.00	$	—
Cap	$/Bbl	$	90.91	$	100.07	$	98.82	$	108.53	$	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.

EX-99.2

Exhibit 99.2

NEWS RELEASE FOR IMMEDIATE RELEASE

BRIGHAM EXPLORATION ACQUIRES RIGHTS TO APPROXIMATELY 48,000 ADDITIONAL NET ACRES IN THE WILLISTON BASIN BAKKEN PLAY AND PROVIDES AN OPERATIONAL UPDATE

Austin, TX – May 6, 2008 -- Brigham Exploration Company (NASDAQ: BEXP) announced the acquisition of approximately 48,000 additional net acres of leasehold west of the Nesson Anticline in the Williston Basin Bakken play, bringing its acreage holdings in the Basin to approximately 287,000 net acres.  The company also announced that completion operations are underway on its fifth Mountrail County horizontal Bakken well, and that it is currently drilling its first well in its North Stanley extensional area.  Brigham also announced the apparently successful drilling of its second 2008 Vicksburg well, with its third Vicksburg well currently drilling.

SIGNIFICANT WELLS RECENTLY COMPLETED, COMPLETING, DRILLING OR PREPARING TO DRILL

Resource Plays	Objective	WI%	NRI	Status / Comments
Manitou State 36 #1H	Bakken	100%	81%	Completing Mountrail Co. Bakken well ~1 mile northeast of Hynek 2 #1H, results late May
Johnson 33 #1H	Bakken	38%	30%	Currently drilling lateral section of North Stanley extensional area well, results expected in June
Carkuff 22 #1H	Bakken	67%	55%	Late May spud of western offset to Bakke 23 #1H
5th Ross Area Well	Bakken	25%	21%	July spud of southern offset to Bakke 23 #1H
Southern Ext. Well	Bakken	100%	85%	August spud in southern extensional area where Brigham controls over 36,000 net acres
Fidelity Farhart 11-11H	Bakken	3%	2.5%	North Stanley area well completing, flowing back fracture stimulation, results late May
Headington Nesson State 41 X 36H	Bakken	17%	14%	Completing Mountrail Co. consortium Bakken well, results expected in June
Headington Nesson State 42 X 36H	Bakken	17%	14%	Completed the drilling of Mountrail Co. Consortium Bakken monitoring well
Headington Nesson State 44 X 36H	Bakken	17%	14%	Completing third Mountrail Co. Consortium Bakken well, results expected in June
EOG Austin 25-35H	Bakken	25%	20%	Projected June spud of offset to EOG Austin 8-26 #1H which commenced at initial rate of 3,060 Bopd
EOG Wayzetta 13-01H	Bakken	25%	20%	Projected August spud of well proximal to Austin 8-26#1H
Mrachek 15-22 1H	Bakken	100%	79%	Horizontal sidetrack of McKenzie Co. ND Bakken well remediated after casing leak, frac scheduled for May, with results expected in late May or June
Krejci Fed. #1-32H	Mowry	50%	40%	Recently fracture stimulated with swell packers, currently testing

Conventional Wells	Objective	WI%	NRI	Status / Comments
Sullivan C-38	Vicksburg	100%	76%	Successfully completed and cleaning up at current rate of approximately 3.2 MMcfed
Sullivan C-39	Vicksburg	100%	76%	Currently completing Home Run Field development well after encountering 137’ of apparent pay
Sullivan F-35	Vicksburg	100%	76%	Dawson Sand development well in Triple Crown Field currently drilling @ 11,200’, results expected in late May
Palacios #1	Melbourne	28%	25%	Planned June spud of development well offsetting producer in Matagorda County
Richardson 30 #1	Red River	75%	60%	Currently drilling offset to Richardson 25 #1 at depth of ~2,130’
Cary Sr. Estate #1	Oligocene	40%	29%	Currently completing Southern Louisiana discovery
SL 18826 #1	Miocene	50%	39%	Planned May spud of 1st of 5 planned 2008 JV wells to test amplitude related prospects, total depth ~8,000’
SL 19312 #1	Miocene	50%	39%	Planned May spud of 2nd of 5 planned 2008 JV wells in Chandeleur Sound Blk 68, total depth ~9,700’
SL 19054 #1	Miocene	50%	38%	Planned June spud of 3rd of 5 planned 2008 JV wells testing amplitude attribute @ total depth ~8,000’
Cotten Land #5	Miocene	43%	33%	Planned July spud of acceleration well developing behind pipe pay in Cotten Land #3 producer

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Williston Basin

Acreage Growth to approximately 287,000 Net Acres - Brigham has acquired the rights to approximately 48,000 net acres of additional leasehold west of the Nesson Anticline.  Brigham purchased the leasehold from a private operator in the trend.  As a result, Brigham now controls approximately 199,000 net acres of leasehold west of the Nesson Anticline, in western North Dakota and Eastern Montana.  To the east, in Mountrail County, North Dakota and the surrounding area, Brigham controls over 88,000 net acres.  In total, Brigham now controls approximately 287,000 net acres in the Williston Basin, with additional leasing activity ongoing.

Bud Brigham, the Chairman, President and CEO, stated, “We’re very pleased to have acquired this substantial leasehold position as it provides very substantial potential option value for our shareholders.  We expect the improved drilling and completion techniques we’re utilizing east of the Nesson Anticline to positively impact the economics of our acreage in the western portions of the Basin.  Importantly, the 48,000 net acres provides us with the right to explore all potential producing objectives, including the shallower Madison and Mission Canyon, as well as the deeper Red River.  In addition to the currently completing Mrachek 15-22 1H, we believe it’s likely we will drill at least one additional horizontal Bakken well west of the Nesson Anticline during the second half of the year, with significant activity anticipated for 2009.”

Mountrail County and Extensional Area Operated Activity – Brigham successfully drilled and is currently completing its fifth operated Mountrail County horizontal Bakken well, the Manitou State 36 #1H.  The Manitou State 36 #1H is located approximately one mile northeast of the Brigham operated Hynek 2 #1H and approximately five miles northwest of the Brigham operated Bakke 23 #1H.  Results for the Manitou State 36 #1H are expected in late May.

Following the Manitou State 36 #1H, in April Brigham commenced the Johnson 33 #1H in the North Stanley area, which is approximately 16 miles north northwest of the Bakke 23 #1H, and where Brigham controls approximately 5,800 net acres.  The Johnson 33 #1H is bracketed to the west and northwest by Fidelity and St. Mary drilling rigs and permits, and to the east and north by the EOG Clearwater and Vanville permits.  The Johnson 33 #1H is currently drilling with good shows in the lateral section, with results expected in June.

In early June, Brigham plans to commence its fourth Ross Area well, the Carkuff 22 #1H, which will be followed by its fifth Ross Area well, a south offset to the Bakke 23 #1H.  Brigham controls over 27,000 net acres in the Ross Area.  Assuming full development on 640 acre spacing, the Ross Area could require over 100 gross, or 42 net wells for full development.

In August, Brigham plans to commence the first well in its south extensional area, where the company controls over 36,000 net acres.  Brigham currently plans to keep this operated rig running continuously to drill horizontal Bakken wells in North Dakota.

Parshall/Austin Area Non-Operated Bakken Drilling Activity – Brigham controls approximately 8,700 net acres in the Parshall/Austin area, which provides for drilling over 13 net wells assuming 640 acre spacing.  The company will retain significant working interests in three recently permitted Parshall/Austin area EOG wells proximal to recent high rate Bakken completions.  Brigham expects to retain a 25% working interest in the EOG Austin 25-35H in section 35 of 154N-90W, which is expected to spud in June.  This well is a south offset to EOG’s recently announced Austin 8-26H, which was reported to have commenced production at a rate of approximately 3,060 barrels per day.

One mile to the southeast, Brigham also expects to retain a 25% working interest in the recently permitted EOG operated Wayzetta 13-01H in section 1 of T153N-R90W.  The EOG Wayzetta 13-01H is reportedly expected to commence in August.

Approximately four miles to the west, EOG has permitted the Austin 22-31H in section 31 of 154N-90W, which is expected to commence in October.  Brigham expects to retain an approximate 25% working interest in this well, which is roughly one mile east of the Murex Jacob Daniel 25-36H in section 36 of 154N-91W.  The Jacob Daniel was reported to be producing approximately 750 barrels of oil per day after having already produced roughly 17,000 barrels, with a reported estimated ultimate recovery of over 1 million barrels of oil.

Brigham has additional ownership interests in five sections offsetting three of EOG’s discoveries drilled in sections 2, 3 and 9 of 154N-90W.  As reported by EOG, these discoveries apparently produced at initial rates of approximately 2,000 barrels of oil per day.  Brigham’s working interests in the five potential wells is expected to range between 1.6% and 12.5%.

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Bud Brigham stated, “Given continued drilling successes and accelerating activity by EOG and other operators in the Parshall/Austin area, we expect to participate in a significant number of non-operated wells during the second half of 2008 and into 2009.  In addition, our operated rig line is continuing with the Johnson 33 #1H well in our North Stanley area, which is an important test for us.  Subsequent to drilling the Johnson 33 #1H, we’ll drill two wells to further delineate and develop our Ross Area, where we could ultimately drill over 42 net wells on our approximate 27,000 net acres, assuming 640 acre spacing.  Given that operators have drilled approximately two laterals per section thus far in the Elm Coulee Bakken Field in Montana, we believe there is excellent potential for higher density development of our Ross and Parshall/Austin areas.”

Vicksburg Development Drilling – Brigham recently completed its first 2008 Vicksburg well, the Floyd Fault Block Sullivan C-38, at an initial rate of approximately 3.2 MMcfe per day.  Brigham is currently completing its second 2008 Vicksburg well, the Home Run Field Sullivan C-39, which encountered approximately 137 feet of apparent net pay.  Brigham is currently drilling its third 2008 Vicksburg well, the Triple Crown Field Sullivan F-35, with results expected by late May.

Bud Brigham stated, “After an eight month gap in Vicksburg completions to reprocess and reinterpret our 3-D seismic, we’re pleased to have kicked off our 2008 Vicksburg program with two apparently successful wells.  Although these wells will only partially impact our second quarter production volumes, all three wells should fully impact our third quarter volumes.”

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 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 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, 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