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): July 29, 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 of Principal Executive Offices)	(Zip Code)

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:

o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 2.02 Results of Operation and Financial Condition.

We are furnishing our press release dated July 29, 2008, which announced our financial results for the second quarter and six months ended June 30, 2008 and provided third and fourth 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 July 29, 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 July 29, 2008, which provides 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 99.1	Press Release dated July 29, 2008.
	Exhibit 99.2	Press Release dated July 29, 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: July 29, 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 July 29, 2008.
99.2	Press Release dated July 29, 2008.

EX-99.1

Exhibit 99.1

NEWS RELEASE
FOR IMMEDIATE RELEASE

BRIGHAM EXPLORATION REPORTS SECOND QUARTER 2008 RESULTS AND PROVIDES THIRD AND FOURTH QUARTER 2008 FORECASTS

Austin, TX — July 29, 2008 — Brigham Exploration Company (NASDAQ:BEXP) today announced its financial results for the second quarter and six months ended June 30, 2008.

SECOND 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 second quarter 2008 were up 4% to $35.5 million when compared to that in the second quarter 2007. Higher commodity prices increased revenues by $15.7 million, while lower production volumes and hedging losses decreased revenues by $11.1 million and $3.4 million, respectively. Our average net daily production for the second quarter 2008 was 30.2 MMcfe per day, which was within the previously provided production guidance range.

Our average realized price for natural gas in the second quarter 2008 was $11.03 per Mcf, which includes a $0.90 per Mcf loss associated with the settlement of our natural gas derivative contracts. This compares to an average realized price in the second quarter 2007 of $7.80 which includes an immaterial gain on the settlement of our natural gas derivative contracts. During the second quarter 2008, our average realized price for oil was $109.71 per barrel, which includes a $12.51 per barrel loss due to the settlement of our oil derivative contracts. This compares to an average realized price in the second quarter 2007 of $62.25, which includes a negligible effect from the settlement of our oil derivative contracts.

Our second quarter 2008 production costs, which include operating and maintenance (O&M) expenses, expensed workovers, ad valorem taxes and production taxes, were $1.47 per Mcfe compared to $0.93 per Mcfe in the second quarter 2007. This increase was primarily driven by a $0.40 per Mcfe increase in production taxes, which was a result of our recording production tax credits on our Vicksburg and Mills Ranch wells in the second quarter 2007 rather than deferring recording credits until receipt of regulatory approval. Our O&M expense also increased on a per unit basis due to the natural decline of production volumes from our wells.

Our second quarter 2008 general and administrative (G&A) expense was 14% higher than in the second quarter of last year. G&A costs increased primarily because of higher compensation expense and higher audit and tax fees.

Our depletion expense for the second quarter 2008 was $12.4 million, compared to $16.6 million in the second quarter 2007. Our lower production volumes decreased depletion expense by $5.8 million, while our higher depletion rate increased depletion expense by $1.6 million.

Our net interest expense for the second quarter 2008 was $0.2 million lower than in the second quarter 2007. This decrease was primarily due to our lower weighted average interest rate and higher amount of capitalized interest. Our weighted average debt outstanding for the second quarter 2008 was $205.5 million, compared to $201.2 million for the comparable period last year.

Our deferred income tax expense for the second quarter 2008 was $0.9 million, compared to $1.9 million in the second quarter of last year. This decrease was primarily due to lower income for the period.

Our reported net income for the second quarter 2008 was $1.5 million ($0.03 per diluted share), versus $2.3 million ($0.05 per diluted share) for the same period last year. Our after-tax earnings in the second quarter 2008 excluding the effect of our unrealized mark-to-market hedging losses were $8.1 million ($0.17 per diluted share), while our after-tax earnings in the second quarter 2007 excluding unrealized mark-to-market hedging gains and our ceiling test impairment 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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For the second quarter 2008, we spent $43.1 million on oil and gas capital expenditures, which represents an increase of 48% from that in the second quarter 2007 and a 5% decrease from that in the first quarter 2008. Oil and gas capital expenditures for the second quarter 2008 and 2007 were:

	Three months ended June 30,
	2008		2007
	(in thousands)
Drilling	$	31,489	$	23,550
Net land and G&G		8,196		2,488
Capitalized costs		3,389		3,140
Capitalized FAS 143 ARO		71		21
Total oil and gas capital expenditures	$	43,145	$	29,199

FIRST SIX MONTHS 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 six months of 2008 were up 3% to $66.0 million when compared to that in the corresponding period last year. Revenues increased $23.7 million due to a 55% increase in our average natural gas equivalent price compared to that in the first six months of 2007, while lower production volumes reduced revenues by $17.1 million. Oil and natural gas derivative hedging settlements decreased revenues by $4.8 million. Average daily production for the first six months 2008 was 31.2 MMcfe per day.

Our average realized price for natural gas during the first six months of 2008 was $9.99 per Mcf, which includes a $0.30 per Mcf loss associated with the settlement of our natural gas derivative contracts. This compares to an average realized price in the first six months of 2007 of $7.78 per Mcf, which includes a $0.20 per Mcf gain due to the settlement of our natural gas derivative contracts. Our average realized price for oil for the first half of 2008 was $100.53 per barrel, which includes an $8.93 per barrel loss due to the settlement of our oil derivative contracts. This compares to an average realized price in the first six months of 2007 of $58.91, which includes a $0.47 per barrel gain due to the settlement of our oil derivative contracts.

Our per unit production costs for the first six months of 2008 increased $0.65 per Mcfe when compared to that in the same period last year. Production taxes increased $0.41 per Mcfe due to a $2.3 million decrease in production tax abatements in the first six months of 2008 versus the first six months of 2007. Workover expense was $0.18 per Mcfe higher in the first six months 2008 as a result of two unexpected workovers during the first quarter 2008.

Our G&A expense for the first six months of 2008 was 16% higher than that in the first six months of last year. G&A costs increased primarily because of higher compensation expense and higher audit and tax fees.

Our depletion expense for the first six months of 2008 was $24.8 million compared to $30.6 million in the first six months of last year. Lower production volumes decreased depletion expense by $8.8 million, while our higher depletion rate increased depletion expense by $3.1 million.

Our net interest expense for the first six months of 2008 decreased by $0.2 million, or 3%, from the comparable period last year. This decrease was primarily due to our lower weighted average interest rate and higher amount of capitalized interest. Our weighted average debt outstanding for the first six months of 2008 was $194.2 million versus $191.5 million for the comparable period last year.

Our deferred income tax expense for the first six months of 2008 was $1.9 million, compared to $2.9 million in the first six months of last year. This decrease was primarily due to lower income for the period.

Our reported net income for the first six months of 2008 was $3.0 million ($0.07 per diluted share) versus net income of $4.2 million ($0.09 per diluted share) for the same period last year. Our after-tax earnings for the first six months of 2008 excluding the effect of our unrealized mark-to-market hedging losses, a non-GAAP financial measure, were $12.9 million ($0.28 per diluted share) and our aftertax earnings for the first six months of 2007 excluding unrealized mark-to-market hedging losses and our ceiling test impairment were $9.9 million ($0.22 per diluted share). A reconciliation of the first six months 2008 GAAP net income to earnings without the effect of the above items is included in our accompanying financial tables found later in this release.

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Through June 30, 2008, we spent $62.7 million on drilling capital expenditures and $88.6 million in total oil and gas capital expenditures. Oil and gas capital expenditures for the first six months of 2008 and 2007 were:

	Six months ended June 30,
	2008		2007
	(in thousands)
Drilling	$	62,689	$	52,227
Net land and G&G		19,029		5,424
Capitalized costs		6,799		5,948
Capitalized FAS 143 ARO		132		228
Total oil and gas capital expenditures	$	88,649	$	63,827

THIRD AND FOURTH QUARTER 2008 FORECASTS

The following forecasts and estimates of our third and fourth 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. We currently expect our third quarter 2008 production volumes to average between 30 MMcfe per day and 34 MMcfe per day. We expect our fourth quarter 2008 production volumes to average between 35 MMcfe per day and 44 MMcfe per day.

For the third quarter 2008, lease operating expenses are projected to be $1.01 per Mcfe based on the mid-point of our production guidance, production taxes are projected to be approximately 4.1% to 4.4% of pre-hedge oil and natural gas revenues, and general and administrative expenses are projected to be $2.6 million ($0.96 to $0.85 per Mcfe).

MANAGEMENT COMMENTS

Gene Shepherd, Brigham’s Chief Financial Officer, commented, “With the benefit of the very strong commodity prices that we experienced during the quarter, our pre-hedge revenue was near our all time record. Further, we are pleased that we have been able to keep our costs in check, with the combination of our second quarter LOE and G&A expense having declined by 8% sequentially and 8% versus that in the prior year’s quarter.”

Gene Shepherd continued, “Our fourth quarter production forecast is positively impacted by our four new Southern Louisiana wells, which have yet to impact our production volumes, and our growing number of Williston Basin oil completions. In addition to our Williston Basin acreage and drilling investments creating significant net asset value for our shareholders, they are generating a growing wedge of relatively shallow decline rate oil production. Our oil production, benefiting from the favorable crude oil pricing fundamentals, generated roughly 75% more revenue than a Mcf equivalent of our gas production during the second quarter 2008.”

CONFERENCE CALL INFORMATION

Our management will host a conference call to discuss operational and financial results for the second quarter 2008 with investors, analysts and other interested parties on Wednesday, July 30, at 10:00 a.m. Eastern Time. To participate in the call, participants within the U.S. please dial 888-713-4216 and participants outside the U.S. please dial 617-213-4868. The participant passcode for the call is 37619931. Participants may pre-register for the call at https://www.theconferencingservice.com/prereg/key.process?key=P38KY6HDG. Pre-registrants will be issued a pin number to use when dialing into the live call which will provide quick access to the conference. A telephone recording of the conference call will be available approximately two hours after the call is completed through 12:00 p.m. Eastern Time on Saturday, August 30, 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 74623551. 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.

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A copy of this press release and other financial and statistical information about the periods covered by this press release and conference call 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 Second Quarter 2008 Results and is dated Tuesday, July 29, 2008. To access the other financial and statistical information that will be covered by this conference call, 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 Second Quarter 2008 Conference Call and is dated Tuesday, July 29, 2008.

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 for and develop onshore domestic oil and natural gas reserves. For more information about Brigham Exploration, please visit our website at 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, 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						Six months ended
	June 30,						June 30,
	2008			2007			2008			2007
Revenues:
Oil and natural gas sales	$	38,871		$	34,283		$	69,381		$	62,769
Hedging settlements		(3,357	)		6			(3,419	)		1,430
		35,514			34,289			65,962			64,199
Unrealized hedging gains/ losses		(10,550	)		2,258			(15,944	)		(2,658	)
		24,964			36,547			50,018			61,541
Other revenue		62			29			79			56
Total revenue		25,026			36,576			50,097			61,597
Costs and expenses:
Lease operating		2,548			3,325			5,534			5,894
Production taxes		1,441			551			2,724			622
General and administrative		2,596			2,281			5,189			4,459
Depletion of oil and natural gas properties		12,405			16,612			24,848			30,571
Impairment of oil and gas properties		—			6,505			—			6,505
Depreciation and amortization		158			158			305			321
Accretion of discount on asset retirement obligations		89			94			180			211
		19,237			29,526			38,780			48,583
Operating income		5,789			7,050			11,317			13,014
Other income (expense):
Interest expense, net		(3,482	)		(3,678	)		(6,901	)		(7,095	)
Interest income		39			134			114			265
Other income (expense)		96			712			403			902
		(3,347	)		(2,832	)		(6,384	)		(5,928	)
Income before income taxes		2,442			4,218			4,933			7,086
Income tax expense:
Current		—			—			—			—
Deferred		(925	)		(1,908	)		(1,889	)		(2,903	)
		(925	)		(1,908	)		(1,889	)		(2,903	)
Net income	$	1,517		$	2,310		$	3,044		$	4,183
Net income per share available to common stockholders:
Basic	$	0.03		$	0.05		$	0.07		$	0.09
Diluted	$	0.03		$	0.05		$	0.07		$	0.09
Weighted average shares outstanding:
Basic		45,332			45,080			45,296			45,067
Diluted		46,444			45,455			46,171			45,478

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

	Three months ended June 30,						Six months ended June 30,
	2008			2007			2008			2007
Average net daily production:
Natural gas (MMcf)		21.6			38.4			23.0			35.8
Oil (Bbls)		1,422			1,308			1,360			1,330
Equivalent natural gas (MMcfe) (6:1)		30.2			46.3			31.2			43.8
Total net production:
Natural gas (MMcf)		1,947			3,457			4,139			6,439
Oil (MBbls)		128			118			245			239
Equivalent natural gas (MMcfe) (6:1)		2,715			4,163			5,609			7,875
% Natural gas		72	%		83	%		74	%		82	%
Sales price:
Natural gas ($/Mcf)	$	11.93		$	7.80		$	10.29		$	7.58
Oil ($/Bbl)		122.22			62.25			109.46			58.44
Equivalent natural gas ($/Mcfe) (6:1)		14.32			8.24			12.37			7.97
Sales price including derivative settlement gains (losses):
Natural gas ($/Mcf)	$	11.03		$	7.80		$	9.99		$	7.78
Oil ($/Bbl)		109.71			62.25			100.53			58.91
Equivalent natural gas ($/Mcfe) (6:1)		13.08			8.24			11.76			8.15
Sales price including derivative settlement gains (losses) and unrealized gains (losses):
Natural gas ($/Mcf)	$	7.61		$	8.49		$	7.14		$	7.44
Oil ($/Bbl)		79.25			61.05			83.64			56.85
Equivalent natural gas ($/Mcfe) (6:1)		9.19			8.78			8.92			7.81

SUMMARY CONSOLIDATED BALANCE SHEETS
(in thousands)

	June 30, 2008		December 31, 2007
	(unaudited)
Assets:
Current assets	$	40,688	$	32,505
Oil and natural gas properties, net (full cost method)		574,008		510,207
Other property and equipment, net		1,082		1,034
Other non-current assets		5,171		4,682
Total assets	$	620,949	$	548,428
Liabilities and stockholders’ equity:
Current liabilities	$	67,860	$	41,718
Senior notes		158,611		158,492
Senior credit facility		48,600		10,000
Mandatorily redeemable preferred stock, Series A		10,101		10,101
Deferred income tax liability		43,554		41,625
Other taxes payable		2,162		2,162
Other non-current liabilities		6,188		5,303
Total liabilities	$	337,076	$	269,401
Stockholders’ equity		283,873		279,027
Total liabilities and stockholders’ equity	$	620,949	$	548,428

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

	Three months ended June 30,						Six months ended June 30,
	2008			2007			2008			2007
Cash flows from operating activities:
Net income	$	1,517		$	2,310		$	3,044		$	4,183
Depletion, depreciation and amortization		12,563			16,770			25,153			30,892
Impairment of oil and gas properties		—			6,505			—			6,505
Accretion of discount on ARO		89			94			180			211
Amortization of deferred loan fees and debt issuance costs		273			247			528			461
Non-cash stock compensation		404			417			818			838
Market value adjustments for derivatives instruments		10,550			(2,258	)		15,944			2,658
Deferred income tax expense		925			1,908			1,889			2,903
Other noncash items		32			—			4			—
Changes in operating assets and liabilities		(11,648	)		5,699			(4,520	)		(1,375	)
Cash flows provided by operating activities	$	14,705		$	31,692		$	43,040		$	47,276
Cash flows used by investing activities		(39,678	)		(25,268	)		(84,712	)		(73,490	)
Cash flows (used) provided by financing activities		29,820			(1,292	)		38,822			34,197
Net increase (decrease) in cash and cash equivalents	$	4,847		$	5,132		$	(2,850	)	$	7,983

SUMMARY PER MCFE DATA
(unaudited)

	Three months ended June 30,						Six months ended June 30,
	2008			2007			2008			2007
Revenues:
Oil and natural gas sales	$	14.32		$	8.24		$	12.37		$	7.97
Hedge settlements		(1.24	)		0.00			(0.61	)		0.18
Unrealized hedge gains (losses)		(3.88	)		0.54			(2.84	)		(0.34	)
Other revenue		0.02			0.01			0.01			0.01
	$	9.22		$	8.79		$	8.93		$	7.82
Costs and expenses:
Lease operating		0.94			0.80			0.99			0.75
Production taxes		0.53			0.13			0.49			0.08
General and administrative		0.96			0.55			0.93			0.57
Depletion of natural gas and oil properties		4.57			3.99			4.43			3.88
Impairment of oil and gas properties		0.00			1.56			0.00			0.83
Depreciation and amortization		0.06			0.04			0.05			0.04
Accretion of discount on ARO		0.03			0.02			0.03			0.03
	$	7.09		$	7.09		$	6.92		$	6.18
Operating income	$	2.13		$	1.70		$	2.01		$	1.64
Interest expense, net of interest income (a)		(1.27	)		(0.85	)		(1.21	)		(0.87	)
Other income (expense)		0.04			0.17			0.07			0.11
Adjusted income	$	0.90		$	1.02		$	0.87		$	0.88

(a) Calculated as interest expense minus interest income divided by production for period.

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BRIGHAM EXPLORATION COMPANY
RECONCILIATION OF GAAP NET INCOME TO EARNINGS WITHOUT THE EFFECT OF CERTAIN ITEMS
(in thousands)

	Three months ended June 30,						Six months ended June 30,
	2008			2007			2008			2007
Net income (loss) as reported	$	1,517		$	2,310		$	3,044		$	4,183
Unrealized derivative (gains) losses		10,550			(2,258	)		15,944			2,658
Impairment of oil and natural gas properties		—			6,505			—			6,505
Tax impact		(3,996	)		(1,491	)		(6,105	)		(3,449	)
Earnings without the effect of certain items	$	8,071		$	5,066		$	12,883		$	9,897

Earnings without the effect of certain items represent net income excluding both unrealized gains and losses on derivative contracts and our non-cash impairment change in our oil and gas properties. Management believes that exclusion of both of these items will help enhance comparability of operating results between periods.

SUMMARY OF COMMODITY PRICE HEDGES OUTSTANDING AS OF JULY 29, 2008
(unaudited)

		2008				2009
		Q3		Q4		Q1		Q2		Q3
Natural Gas Costless Collars:
Daily volumes	MMBtu/d		12,283		7,391		6,778		4,615		4,565
Floor	$/MMBtu	$	7.42	$	8.51	$	8.75	$	7.54	$	7.54
Cap	$/MMBtu	$	9.95	$	10.81	$	11.09	$	10.23	$	10.23
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		533		446		333		99		—
Floor	$/Bbl	$	74.92	$	73.44	$	79.15	$	62.00	$	—
Cap	$/Bbl	$	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 ANNOUNCES 1,110 BOPD BAKKEN COMPLETION, GROWING WILLISTON BASIN OIL PRODUCTION AND APPARENT THIRD CONSECUTIVE SOUTHERN LOUISIANA DISCOVERY

Austin, TX — July 29, 2008 — Brigham Exploration Company (NASDAQ: BEXP) announced the high rate completion of its Carkuff 22 #1H Bakken well in its Ross Area at an early flowing rate of 1,110 barrels of oil per day, and that its Williston Basin oil production has grown to an estimated current net rate of approximately 1,500 barrels of oil per day. The company also announced that completion operations are underway on its Kvamme 2 #1H and Payara #1-21H in the Parshall/Austin Area, that it’s preparing to commence its first Three Forks test, and that it has apparently drilled its third consecutive successful well in its Southern Louisiana joint venture.

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

Resource Plays	Objective	WI%			NRI			Status / Comments
Carkuff 22 #1H	Bakken		67	%		55	%	Flowing after stimulation at rate of 1,110 Bopd & est. 400-500 Mcfgd, in Ross Area with ~27,000 net acres
Kvamme 2 #1H	Bakken		50	%		40	%	Completing 1st operated Parshall/Austin Area well after encountering good shows, results late August
Mrachek 15-22 #1H	Bakken		100	%		79	%	McKenzie County N.D. well’s initial 24 hr rate of 727 Boe, currently installing pumping unit
Johnson 33 #1H	Bakken		38	%		30	%	Producing N. Stanley Area well, early rate of 618 Boepd, currently flowing approximately 300 Boepd
Manitou State 36 #1H	Bakken		100	%		81	%	Completing Ross Area well, initial rate 272 Bopd, currently producing ~ 240 Bopd after installing pump
Slawson Payara#1-21H	Bakken		18	%		14	%	Completing Slawson operated well with good shows ~ 3 miles west of Parshall Field, results in August
EOG Austin 25-35 1H	Bakken		25	%		20	%	Drilling Parshall/Austin Area offset to Austin 8-26H (reported IP of 3,060 Bopd), results in September
Wayzetta 13-01H	Bakken		25	%		20	%	Reported August spud of Parshall/Austin Area well near EOG Austin 8-26H (reported IP of 3,060 Bopd)
Adix 25 #1H	Three Forks		32	%		26	%	Preparing to commence Three Forks test in 27,000 net acre Ross Area, results in October
Williams Cnty Well	Bakken		59	%		47	%	Planned September spud of well west of Nesson Anticline in acreage block north of Mrachek
McKenzie Cnty Well	Bakken		64	%		50	%	Planned October spud of well west of the Nesson Anticline in acreage block northeast of Mrachek
Anderson 28 #1-H	Bakken		25	%		20	%	Planned early October spud of Bakken well in Ross Area, results in December
Afseth 34 #1-H	Bkn or 3 Forks		41	%		33	%	Planned November spud of Bakken or/and Three Forks test in North Stanley Area
Hallingstad 35-34 #1H	Bakken		34	%		31	%	Planned December spud of 1280 acre unit Bakken test south of Hallingstad 27-1H in Parshall/Austin Area
Wanner 25 #1H	Bakken		100	%		85	%	Planned October spud of multipay test in southern extensional area, Brigham controls over 31,000 net acres

Conventional Wells	Objective	WI%			NRI			Status / Comments
SL 19054 #1	Miocene		50	%		38	%	Completing 3rd JV well @ Breton Sound, found 60’ of apparent pay, 15’ of which is above 20% porosity
SL 19312 #1	Miocene		50	%		38	%	Production tested Chandeleur Sound well at 2.7 MMcfg per day, expected sales in November
SL 18826 #1	Miocene		50	%		39	%	Main Pass well production tested at 15.4 MMcfgd, expected to produce 15-20 MMcfgd in late August
BLM 013045 #1	Miocene		50	%		38	%	Planned Sept./Oct. spud of 4th JV well at Romere Pass, testing amplitude attribute @ total depth ~10,550’
SL 18877 #1	Miocene		50	%		38	%	Planned Sept./Oct. spud of 5th JV well at Tiger Pass, testing amplitude attribute @ total depth ~9,000’
Cotten Land #5	Miocene		43	%		33	%	Planned August spud of acceleration well developing behind apparent pipe pay in Cotten Land #3
Harrison Unit #1	Melbourne		33	%		25	%	Planned 3rd quarter spud of development well offsetting producer in Matagorda County
Cary Sr. Estate #1	Oligocene		40	%		29	%	Currently completing
Richardson 30 #1	Red River		74	%		56	%	2nd consecutive Red River discovery tested with initial rate of 168 Bopd
Boneyard 13-20-29	Red River		25	%		19	%	Planned Sept. spud of Red River test in area of Richardson discoveries
Meagher 16-30	Red River		25	%		19	%	Planned Oct. spud of Red River test in area of Richardson discoveries

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Growing Bakken Oil Production — Since early 2008, Brigham has drilled continuously with one rig in the accelerating Williston Basin Bakken play. The company’s net production in the Williston Basin has grown from an approximate average of 100 barrels of oil per day in December 2007 to roughly 500 net barrels of oil per day in June 2008. As a result of a number of recent completions, Brigham’s current Williston Basin daily net production is estimated to be approximately 1,500 barrels of oil per day.

Bud Brigham, the Chairman, President and CEO stated, “With one rig running continuously we’ve grown long life predominantly oil reserves and production in the Williston Basin steadily during the year. Our Mrachek 15-22 #1H, Manitou State 36 #1H, Johnson 33 #1H and Carkuff 22 #1H have elevated our current net production in the Williston Basin to roughly 1,500 barrels of oil per day. In the prolific Parshall/Austin area we currently have the Kvamme 2 #1H and the Slawson operated Payara #1-21H completing, which should be followed by the EOG operated Austin 25-35 1H and Austin Wayzetta 13-01H wells. These potentially high production rate wells should commence production to sales over the next sixty to seventy five days. Further, our second operated rig is expected to commence by the end of September, and as a result we expect to double our operated completions from roughly one gross operated well per month to two gross operated wells per month.”

Bud Brigham continued, “Given current commodity prices these growing oil volumes generate substantially more revenue and cash flow per Mcf equivalent than do our gas volumes. During the second quarter, utilizing a 6:1 conversion, a Mcf equivalent of oil generated roughly 75% more revenue than a Mcf of natural gas. Therefore, our current Williston Basin oil production of over 1,500 net barrels of oil per day, which on a 6:1 conversion is 9 MMcf of natural gas equivalents per day, would generate revenue comparable to approximately 15.75 MMcf per day of natural gas production. We’re adding more valuable production in this basin, with substantially longer reserve lives, relative to our conventional Gulf Coast natural gas production, and we’re doing so very consistently.”

Mountrail County Bakken Completions — Brigham successfully drilled and recently stimulated the Carkuff 22 #1H, which flowed approximately 1,110 barrels of oil and an estimated 400 to 500 Mcf of natural gas up 7.5 inch casing over the last 24 hours. Brigham’s prior completion in the Ross Area, the Manitou State 36 #1H, was recently put on pump and has been producing approximately 240 barrels of oil per day. Both wells are in the Ross Area, where Brigham controls approximately 27,000 net acres. Assuming 320 acre spacing the company could drill approximately 84 net wells in the Ross Area.

Bud Brigham stated, “Based on its early performance, the Carkuff 22 #1H appears to be our strongest well drilled to date. It represents our eleventh horizontal completion in the Bakken play. The production performance we’ve seen from our drilling to date has improved significantly over time, almost on a well by well basis. Operational enhancements, such as more fracture stimulations per well, are having a positive impact on our results.”

Mountrail County Parshall/Austin Area Drilling — Brigham is currently completing the Kvamme 2 #1H in the prolific Parshall/Austin Area. The Kvamme 2 #1H encountered good drilling shows, and is expected to be stimulated in mid to late August.

Brigham is also participating in a non-operated role in three significant Parshall/Austin area wells that are currently completing, currently drilling or expected to spud in the near future. Brigham retains an 18% working interest in the Slawson Payara #1-21H, located approximately three miles west of the Parshall Field. The Slawson Payara #1-21H apparently encountered good drilling shows, with completion operations underway. In addition, Brigham is participating with a 25% working interest in the currently drilling EOG operated Austin 25-35H. Brigham retains a 25% working interest in the Austin 25-35H, which is a south offset to EOG’s 3,060 barrel of oil per day Austin 8-26H well. Results for the Slawson Payara #1-21H and the EOG Austin 25-35H wells are expected in late August and September, respectively.

One mile to the southeast of the EOG Austin 25-35H, Brigham expects to retain a 25% working interest in the EOG operated Wayzetta 13-01H in section 1 of T153N-R90W. The EOG Wayzetta 13-01H is reportedly expected to commence on August 10^th. Other operators are continuing to accelerate drilling in the Parshall/Austin Area, where Brigham controls approximately 8,700 net acres. Assuming 320 acre spacing, the company could drill approximately 27 net wells in the Parshall/Austin Area.

Planned Horizontal Three Forks Well — In August, Brigham plans to commence the Adix 25 #1H, its first horizontal Three Forks well. The Adix 25 #1H is located on the eastern edge of our Ross Area, in section 25 of T155N-R92W, with results anticipated in early October. In the North Stanley Area, Brigham may also drill the Afseth 34 #1-H in the Three Forks. The Afseth 34 #1-H is located in section 34 of T158N-R91W, and is currently scheduled to commence in November.

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Bud Brigham stated, “We’re eager to drill our first Three Forks well in Mountrail County, particularly given the recent positive drilling results from other operators in the area. On the western edge of our Ross Area, Encore recently announced an apparent 1,100 barrel of oil per day Three Forks discovery. Other apparent Three Forks discoveries have been drilled by another operator to the north and northeast of the Ross Area, which is also to the west and northwest of our North Stanley Area. In addition, yesterday Fidelity announced a Three Forks discovery flowing 634 barrels of oil per day. The Fidelity Domaskin 11-29H is located in section 29 of T154N-R92W, roughly four miles south from the edge of our 27,000 net acres in the Ross Area, and about seven miles south-southwest of our Adix 25 #1H location.”

Bud Brigham continued, “While we’re very busy converting our Williston Basin acreage to proved Bakken reserves and net asset value, the Three Forks drilling is a potential ‘double down’ in net asset value in this play. Three Forks drilling by other operators in the area is beginning to demonstrate the potentially vast geographic breadth of this play, and the quality of the early production. Thus far, our approximate 93,000 net acres east of the Nesson Anticline, and our estimated 100,000 net acres west of the Nesson Anticline in Williams and McKenzie Counties North Dakota, are the most proximal to the recent Three Forks discoveries. However, Three Forks wells are evidently planned by other operators for eastern Montana, where we control another 100,000 net acres. We believe that all of our 293,000 net acres in the play could be prospective for the Three Forks.”

Third consecutive Southern Louisiana Joint Venture Discovery — Brigham successfully drilled and is currently completing its third consecutive joint venture well. The Breton Sound SL 19054 #1 encountered 60 feet of apparent pay. Approximately 15 feet of the pay has apparent porosities greater than 20%, while 45 feet of apparent pay has porosities ranging from 18 to 20%. Production testing operations are underway, and the well is expected to be producing to sales by late October.

Brigham recently production tested its second joint venture discovery, the Chandeleur Sound SL 19312 #1, at a rate of approximately 2.7 MMcf of natural gas per day. Production to sales is expected in November. The Company’s fourth and fifth joint venture wells, the Romere Pass BLM 013045 #1 and the Tiger Pass SL 18877 #1, are expected to commence in either September or October. Brigham plans to drill its sixth prospect as part of its Southern Louisiana joint venture with Clayton Williams Energy Inc. (NASDAQ: CWEI) in early 2009.

Commencement of Bayou Postillion Cotten Land #5 — Brigham is currently commencing the Cotten Land #5, a twin to Brigham’s high production rate Cotten Land #3 discovery. The Cotten Land #3 encountered two apparent high quality pay intervals with 30 feet and 50 feet of estimated pay. The lower 30 foot pay interval was completed in March 2007 and produced at rates as high as 29 MMcfe per day, has produced approximately 9.5 Bcfe to date, and is currently producing approximately 10.1 MMcfe per day. The Cotten Land #5 targets the as yet unproduced upper 50 feet of apparent pay, with results expected in October.

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 for and develop onshore domestic oil and natural gas reserves. 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.

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Contact: Rob Roosa, Finance Manager
(512) 427-3300