Exhibit 99.1

DELTA PETROLEUM CORPORATION
Daniel Taylor, Chairman
Carl Lakey, President and CEO
Kevin Nanke, Treasurer and CFO
Broc Richardson, V.P. Corporate Development and IR
370 17th Street, Suite 4300
Denver, Colorado 80202

For Immediate Release

DELTA PETROLEUM CORPORATION
ANNOUNCES SECOND QUARTER 2010 RESULTS

     DENVER, Colorado (August 9, 2010) – Delta Petroleum Corporation (the “Company” or “Delta”) (NASDAQ Global Market: DPTR), an independent oil and gas exploration and development company, today announced its financial and operating results for the second quarter of 2010.

     Carl Lakey, Delta’s President and CEO, stated, “The second quarter for 2010 was a pivotal period for Delta Petroleum. We have now completed our strategic alternatives process and have begun analyzing the results from earlier changes in the well completion process in the Piceance Basin. The new completion technique is generating results that are better than expected. Although we are still early in the evaluation process, the results to date do suggest using the new technique on all 15 remaining wells.

     “After the end of the quarter, we received approximately $130 million in gross proceeds from the sale to Wapiti Oil & Gas of certain non-core properties that amounted to approximately 25% of our total proved reserves at year end 2009. With the proceeds from this transaction, we have reduced our credit facility borrowings to very minimal levels and we are now in the process of obtaining a new credit facility that we expect to have in place by the end of the third quarter. We will continue to stringently focus on cost control and efficient operations in the Vega area and are confident that we will be able to create value in doing so.”

$130 MILLION ASSET DIVESTITURE

     As previously announced, the Company closed on its $130 million non-core asset sale with Wapiti Oil & Gas, L.L.C. (“Wapiti”) on July 30, 2010 (the “Wapiti Transaction”). Of the $130 million purchase price, $112 million was received by the Company at closing and used to reduce bank debt and to pay transaction costs. The remaining $18 million is being held in escrow until third party consents are obtained for the assignment of the Company’s working interest in certain properties that were a part of the transaction. The Company expects to receive the consents and escrowed funds during the third quarter of 2010, and upon receipt, such funds will also be used to reduce debt.

     In accordance with applicable accounting standards, properties held for sale at June 30, 2010 in conjunction with the Wapiti Transaction in which the Company only sold half of its interest continue to be reported as a component of continuing operations and are primarily comprised of the Newton and Midway Loop fields. The fields classified as discontinued operations are fields in which the Company sold all of its interest and include the 31% working interest in the Garden Gulch field, the Baffin Bay field, and the Bull Canyon field, as well as the Company’s interest in its wholly-owned subsidiary, Piper Petroleum.

     The Company recorded impairment losses associated with assets held for sale during the three months ended June 30, 2010 of $96.1 million, of which $92.2 million was included in loss from discontinued operations and $3.9 million was included in dry holes and impairments. The Company expects to recognize a gain on sale for the closing of the Wapiti Transaction in the three months ending September 30, 2010 of approximately $29.4 million, subject to revision for normal and customary purchase price adjustments as provided for under the purchase and sale agreement. In total, the Wapiti Transaction is expected to result in a $66.7 million loss when

the second quarter asset held for sale impairments are considered in conjunction with the third quarter gain on sale.

     See Reconciliation of Non-GAAP Measures below for a reconciliation of non-GAAP measures to the GAAP measures each as provided herein.

LIQUIDITY UPDATE

     On July 23, 2010, the Company and its credit facility banks agreed to amend the credit agreement for its senior credit facility. As a result of the new amendment and the completion of the Wapiti Transaction, the Company’s borrowing base was reduced to $35 million. The amendment imposed capital expenditures limitations of $18 million for the third quarter 2010 and $10 million for the fourth quarter 2010 with a carry-over provision and eliminated all scheduled or special borrowing base redeterminations prior to the maturity of the facility in January 2011.

     The Company was in compliance with its financial ratio, capital expenditures and accounts payable covenants under its credit facility as of June 30, 2010.

     At July 30, 2010, the Company held approximately $10 million in cash after paying transaction costs on the Wapiti sale and $18 million held in escrow pending third party consents. Based on the revised borrowing base and the completion of the Wapiti Transaction, $11 million was available for borrowing under the amended credit facility, giving the Company approximately $40 million in liquidity.

RESULTS FOR THE SECOND QUARTER

     The Company reported a second quarter net loss attributable to common stockholders of ($149.8 million), or ($0.54) per share, compared with a net loss attributable to common stockholders of ($172.3 million), or ($0.89) per share, in the second quarter of 2009. The net loss attributable to common stockholders for the second quarter 2010 includes a $96.1 million impairment charge associated with the assets held for sale.

     For the quarter ended June 30, 2010, the Company reported production of 4.7 billion cubic feet equivalents (“Bcfe”). Approximately 1.3 Bcfe of production in the quarter was from assets sold in the Wapiti Transaction, of which 795 Mmcfe is accounted for under “Discontinued Operations”. The following discussion is on a “Continuing Operations” basis.

     Total revenue increased 73% to $36.0 million in the quarter, versus revenue of $20.9 million in the quarter ended June 30, 2009. The increase is primarily related to a $9.4 million increase in contract drilling and trucking fees, improved third party rig utilization, and a $5.8 million quarter-over-quarter increase in oil and gas sales. For the quarter ended June 30, 2010, oil and gas sales increased 30% to $25.1 million, as compared to $19.3 million for the prior year period. The increase was primarily the result of a 110% increase in natural gas prices and a 31% increase in oil prices, partially offset by a 21% decrease in production. The average natural gas price received during the quarter ended June 30, 2010 increased to $4.86 per thousand cubic feet (“Mcf”) compared to $2.31 per Mcf for the prior year period. The average oil price received during the quarter ended June 30, 2010 increased to $69.88 per barrel (“Bbl”) compared to $53.22 per Bbl for the prior year period.

SECOND QUARTER PRODUCTION VOLUMES, UNIT PRICES AND COSTS

     Production volumes, average prices received and cost per equivalent Mcf for the three months ended June 30, 2010 and 2009 are as follows:

		Three Months Ended
		June 30,
		2010				2009
Production – Continuing Operations:
Oil (Mbbl)			150				198
Gas (Mmcf)			3,004				3,776
Total Production (Mmcfe) – Continuing Operations			3,902				4,964
Average Price – Continuing Operations:
Oil (per barrel)		$	69.88			$	53.22
Gas (per Mcf)		$	4.86			$	2.31
Costs (per Mcfe) – Continuing Operations:
Lease operating expense		$	2.05			$	1.38
Transportation expense		$	1.14			$	0.44
Production taxes		$	0.35			$	0.21
Depletion expense		$	3.82			$	4.66
Realized derivative losses (per Mcfe)		$	0.15			$	—

     Lease Operating Expense. Lease operating expenses for the quarter ended June 30, 2010 increased to $8.0 million from $6.8 million in the year earlier period primarily due to increased water handling costs in the Vega area partially offset by lower offshore lease operating costs. Lease operating expense per Mcfe for the quarter ended June 30, 2010 increased to $2.05 per Mcfe from $1.38 per Mcfe. The quarter-over-quarter increase on a per unit basis was primarily due to the increased water handling costs in the Vega area and the effect of fixed costs spread over a 21% decline in production volumes.

     Transportation Expense. Transportation expense for the quarter ended June 30, 2010 increased to $4.5 million from $2.2 million in the prior year. Transportation expense per Mcfe for the quarter ended June 30, 2010 increased 159% to $1.14 per Mcfe from $0.44 per Mcfe. The increase on a per unit basis is primarily the result of changes to the Company’s Vega gas marketing contract that went into effect in October 2009 whereby the Company’s gas is processed through a higher efficiency plant. The Vega gas marketing contract has resulted in higher revenues in the Vega area from improved natural gas liquids recoveries and a greater percentage of liquids proceeds retained.

     Depreciation, Depletion, Amortization and Accretion – Oil and Gas. Depreciation, depletion and amortization expense decreased 33% to $15.9 million for the quarter ended June 30, 2010, as compared to $23.8 million for the comparable year earlier period. Depletion expense for the quarter ended June 30, 2010 decreased to $14.9 million from $23.1 million for the quarter ended June 30, 2009 due to lower production volumes and a decrease in the per unit depletion rate. The Company’s depletion rate decreased from $4.66 per Mcfe for the quarter ended June 30, 2009 to $3.82 per Mcfe for the current year period primarily due to the effect of impairments recorded during late 2009 on high depletion rate properties and Vega area proved undeveloped reserves added as a result of higher Piceance gas prices.

     General and Administrative Expense. General and administrative expense increased 30% to $11.6 million for the quarter ended June 30, 2010, as compared to $9.0 million for the comparable prior year period. The increase in general and administrative expenses is attributed to costs associated with the strategic alternatives evaluation process and to increased non-cash stock compensation expense related to restricted stock granted in December 2009, partially offset by reduced staffing as a result of reductions in force during the first half of 2009 resulting in lower cash compensation expense.

RESULTS FOR THE SIX MONTHS ENDED JUNE 30, 2010

     The Company reported a six month net loss attributable to common stockholders of ($162.5 million), or ($0.59) per share, compared with a net loss attributable to common stockholders of ($197.9 million), or ($1.35) per share, in the six months ended June 30, 2009. The net loss attributable to common stockholders for the six months ended June 30, 2010 includes a $96.1 million impairment charge associated with assets held for sale.

     For the six months ended June 30, 2010, the Company reported production of 9.7 Bcfe. Approximately 2.7 Bcfe of production for the six month period was from assets sold in the Wapiti Transaction, of which 1.7 Bcfe is accounted for under “Discontinued Operations”. The following discussion is on a “Continuing Operations” basis.

     Total revenue decreased 1% to $75.4 million for the six months ended June 30, 2010, versus revenue of $76.2 million in the six months ended June 30, 2009. The decrease is primarily related to a $31.2 million gain associated with the offshore California litigation in 2009, offset by a $16.9 million period-over-period increase in oil and gas sales and a $14.1 million increase in contract drilling and trucking fees, due to improved third party rig utilization. For the six months ended June 30, 2010, oil and gas sales increased 44% to $55.0 million, as compared to $38.1 million for the prior year period. The increase was principally the result of a 102% increase in natural gas prices and a 68% increase in oil prices, partially offset by a 22% decrease in production. The average natural gas price received during a six months ended June 30, 2010 increased to $5.38 per Mcf compared to $2.66 per Mcf for the year earlier period. The average oil price received during the six months ended June 30, 2010 increased to $70.54 per Bbl compared to $41.99 per Bbl for the year earlier period.

SIX MONTHS ENDED PRODUCTION VOLUMES, UNIT PRICES AND COSTS

     Production volumes, average prices received and cost per equivalent Mcf for the six months ended June 30, 2010 and 2009 are as follows:

		Six Months Ended
		June 30,
		2010				2009
Production – Continuing Operations:
Oil (Mbbl)			299				405
Gas (Mmcf)			6,299				7,934
Total Production (Mmcfe) – Continuing Operations			8,093				10,364
Average Price – Continuing Operations:
Oil (per barrel)		$	70.54			$	41.99
Gas (per Mcf)		$	5.38			$	2.66
Costs (per Mcfe) – Continuing Operations:
Lease operating expense		$	1.88			$	1.42
Transportation expense		$	0.96			$	0.45
Production taxes		$	0.35			$	0.25
Depletion expense		$	3.67			$	4.29
Realized derivative losses (per Mcfe)		$	0.58			$	—

     Lease Operating Expense. Lease operating expenses for the six months ended June 30, 2010 of $15.2 million was comparable to $14.7 million in the year earlier period. Lease operating expense per Mcfe for the six months ended June 30, 2010 increased to $1.88 per Mcfe from $1.42 per Mcfe for the comparable year earlier period. The increase on a per unit basis was primarily due to increased water handling costs in the Vega area and the effect of fixed costs spread over a 22% decline in production volumes.

     Transportation Expense. Transportation expense for the six months ended June 30, 2010 increased to $7.8 million from $4.6 million in the prior year. Transportation expense per Mcfe for the six months ended June 30,

2010 increased to $0.96 per Mcfe from $0.45 per Mcfe. The increase on a per unit basis is primarily the result of changes to the Company’s Vega gas marketing contract that went into effect in October 2009 whereby the Company’s gas is processed through a higher efficiency plant. The Vega gas marketing contract has resulted in higher revenues in the Vega area from improved natural gas liquids recoveries and a greater percentage of liquids proceeds retained.

     Depreciation, Depletion, Amortization and Accretion – Oil and Gas. Depreciation, depletion and amortization expense decreased 32% to $31.3 million for the six months ended June 30, 2010, as compared to $45.9 million for the comparable year earlier period. Depletion expense for the six months ended June 30, 2010 was $29.7 million compared to $44.4 million for the six months ended June 30, 2009. The depletion rate decreased from $4.29 per Mcfe for the six months ended June 30, 2009 to $3.67 per Mcfe for the current year period primarily due to the effect of impairments recorded during late 2009 on high depletion rate properties and Vega area proved undeveloped reserves added as a result of higher Piceance gas prices.

     General and Administrative Expense. General and administrative expense increased 7% to $23.0 million for the six months ended June 30, 2010, as compared to $21.6 million for the comparable prior year period. The increase in general and administrative expenses is attributed to costs associated with the strategic alternatives evaluation process and to increased non-cash stock compensation expense related to restricted stock granted in December 2009, partially offset by reduced staffing as a result of reductions in force during the first half of 2009 resulting in lower cash compensation expense.

ADDITIONAL FINANCIAL INFORMATION

     The following table summarizes the Company’s open derivative contracts at June 30, 2010:

Remaining

Commodity

Volume

Fixed Price

Term

Index Price

Crude oil

1,000

Bbls / Day1

$

52.25

July ’10 - Dec ’10

NYMEX – WTI

Crude oil

500

Bbls / Day

$

57.70

Jan ’11 - Dec ’11

NYMEX – WTI

Natural gas

6,000

MMBtu / Day

$

5.720

July ’10 - Dec ’10

NYMEX – HHUB

Natural gas

15,000

MMBtu / Day

$

4.105

July ’10 - Dec ’10

CIG

Natural gas

5,367

MMBtu / Day

$

3.973

July ’10 - Dec ’10

CIG

Natural gas

12,000

MMBtu / Day

$

5.150

Jan ’11 - Dec ’11

CIG

Natural gas

3,253

MMBtu / Day

$

5.040

Jan ’11 - Dec ’11

CIG

     The pre-credit risk adjusted fair value of the Company’s net derivative liabilities as of June 30, 2010 was $6.6 million. A credit risk adjustment of $0.6 million to the fair value of the derivatives reduced the reported amount of the net derivative liabilities to $6.0 million.

OPERATIONS UPDATE

     Total Company net production for the month of August is expected to be 34 Mmcfe/d. During the second quarter 2010 the Company completed one well from its drilled and uncompleted inventory in the Vega area. The Company expects to complete the remaining 15 drilled and uncompleted wells in the third and fourth quarters of this year, utilizing its redesigned completion techniques.

2010 CAPITAL EXPENDITURES AND PRODUCTION GUIDANCE

     With the completion of the Wapiti Transaction and the reduction in the Company’s credit facility borrowing base to $35.0 million, capital expenditure limitations in the Company’s credit agreement for the third and fourth quarters of 2010 are set at $18.0 million and $10.0 million, respectively. The Company intends to focus capital expenditures for the remainder of the year on completing 15 previously drilled wells in the Vega area. Based on

this level of development and considering production sold in the Wapiti Transaction, the Company expects oil and gas equivalent production for the remainder of the year to range between 6.9 Bcfe and 7.2 Bcfe.

INVESTOR CONFERENCE CALL

     The Company will host an investor conference call Tuesday, August 10, 2010 at 12:00 noon Eastern Time (10:00 am Mountain Time) to discuss financial and operating results for the second quarter 2010.

     Shareholders and other interested parties may participate in the conference call by dialing 877-317-6789 (international callers dial 412-317-6789) and referencing the ID code “Delta Petroleum call,” a few minutes before 12:00 noon Eastern Time on August 10, 2010. The call will also be broadcast live and can be accessed through the Company’s website at http://www.deltapetro.com/eventscalendar.html. A replay of the conference call will be available one hour after the completion of the conference call from August 10, 2010 until August 19, 2010 by dialing 877-344-7529 (international callers dial 412-317-0088) and entering the conference ID 443139.

ABOUT DELTA PETROLEUM CORPORATION

     Delta Petroleum Corporation is an oil and gas exploration and development company based in Denver, Colorado. The Company’s core area of operation is the Rocky Mountain Region, where the majority of its proved reserves, production and long-term growth prospects are located. Its common stock is listed on the NASDAQ Global Market System under the symbol “DPTR.”

FORWARD-LOOKING STATEMENTS

     Forward-looking statements in this announcement are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Readers are cautioned that all forward-looking statements are based on management’s present expectations, estimates and projections, but involve risks and uncertainty, including without limitation the effects of oil and natural gas prices, availability of capital to fund required payments on our credit facility and our projected capital development and working capital needs, the ability to obtain necessary third party consents to transfer assets to be conveyed in the Wapiti Transaction, as well as general market conditions, competition and pricing, the increase in supply and contraction in demand for natural gas in the United States, lack of availability of third party services including frac crews, the impact of current economic and financial conditions on our ability to raise capital, availability of borrowings under our credit facility and the ability to obtain a new or replacement credit facility, uncertainties in the projection of future rates of production, unanticipated recovery or production problems, unanticipated results from wells being drilled or completed, the effects of delays in completion of gas gathering systems, pipelines and processing facilities, as well as general market conditions, competition and pricing. Please refer to the Company’s report on Form 10-K for the year ended December 31, 2009 and subsequent reports on Forms 10-Q and 8-K as filed with the Securities and Exchange Commission for additional information. The Company is under no obligation (and expressly disclaims any obligation) to update or alter its forward-looking statements, whether as a result of new information, future events or otherwise.

For further information contact the Company at (303) 293-9133 or via email at investorrelations@deltapetro.com

SOURCE: Delta Petroleum Corporation

DELTA PETROLEUM CORPORATION
AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)

		June 30,				December 31,
		2010				2009
		(In thousands, except share data)
ASSETS
Current assets:
Cash and cash equivalents		$	11,051			$	61,918
Short-term restricted deposits			100,000				100,000
Trade accounts receivable, net of allowance for doubtful accounts of $100 and $100, respectively			17,757				16,654
Oil and gas properties held for sale			99,902				—
Deposits and prepaid assets			2,051				3,103
Inventories			4,150				5,588
Other current assets			3,169				5,189
Total current assets			238,080				192,452
Property and equipment:
Oil and gas properties, successful efforts method of accounting:
Unproved			236,096				280,844
Proved			944,163				1,379,920
Drilling and trucking equipment			175,844				177,762
Pipeline and gathering systems			96,446				92,064
Other			15,681				16,154
Total property and equipment			1,468,230				1,946,744
Less accumulated depreciation and depletion			(578,771	)			(800,501	)
Net property and equipment			889,459				1,146,243
Long-term assets:
Long-term restricted deposit			100,000				100,000
Investments in unconsolidated affiliates			4,928				7,444
Deferred financing costs			2,442				3,017
Other long-term assets			6,163				8,329
Total long-term assets			113,533				118,790
Total assets		$	1,241,072			$	1,457,485
LIABILITIES AND EQUITY
Current liabilities:
Credit facility – Delta		$	119,538			$	—
Credit facility – DHS			73,590				83,268
Installments payable on property acquisition			99,144				97,874
Accounts payable			31,175				44,225
Liabilities related to oil and gas properties held for sale			7,280				—
Offshore litigation payable			—				13,877
Other accrued liabilities			11,628				13,459
Derivative instruments			4,705				19,497
Total current liabilities			347,060				272,200
Long-term liabilities:
Installments payable on property acquisition, net of current portion			96,619				95,381
7% Senior notes			149,647				149,609
33/4% Senior convertible notes			106,268				104,008
Credit facility – Delta			—				124,038
Asset retirement obligations			4,620				7,654
Derivative instruments			1,319				7,475
Total long-term liabilities			358,473				488,165
Commitments and contingencies
Equity:
Preferred stock, $.01 par value: authorized 3,000,000 shares, none issued			—				—
Common stock, $.01 par value: authorized 600,000,000 shares, issued 282,760,000 shares at June 30, 2010 and 282,548,000 shares at December 31, 2009			2,828				2,825
Additional paid-in capital			1,631,517				1,625,035
Treasury stock at cost; 34,000 shares at June 30, 2010 and 42,000 shares at December 31, 2009			(75	)			(268	)
Accumulated deficit			(1,101,557	)			(939,010	)
Total Delta stockholders’ equity			532,713				688,582
Non-controlling interest			2,826				8,538
Total equity			535,539				697,120
Total liabilities and equity		$	1,241,072			$	1,457,485

DELTA PETROLEUM CORPORATION
AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2010				2009				2010				2009
		(In thousands, except per share amounts)
Revenue:
Oil and gas sales		$	25,067			$	19,267			$	54,970			$	38,116
Contract drilling and trucking fees			11,064				1,674				20,996				6,887
Gain (loss) on offshore litigation award and property sales, net			(109	)			(81	)			(538	)			31,204
Total revenue			36,022				20,860				75,428				76,207
Operating expenses:
Lease operating expense			8,015				6,845				15,202				14,749
Transportation expense			4,454				2,178				7,807				4,626
Production taxes			1,377				1,061				2,821				2,550
Exploration expense			358				471				584				1,531
Dry hole costs and impairments			30,767				106,621				31,121				108,064
Depreciation, depletion, amortization and accretion — oil and gas			15,920				23,846				31,339				45,850
Drilling and trucking operating expenses			8,123				2,342				16,012				7,598
Depreciation and amortization — drilling and trucking			5,226				6,175				10,798				11,967
General and administrative			11,640				8,966				23,027				21,594
Executive severance expense, net			—				3,739				—				3,739
Total operating expenses			85,880				162,244				138,711				222,268
Operating loss			(49,858	)			(141,384	)			(63,283	)			(146,061	)
Other income and (expense):
Interest expense and financing costs, net			(9,556	)			(15,775	)			(20,116	)			(32,201	)
Other income (expense), net			(299	)			1,256				(170	)			1,408
Realized loss on derivative instruments, net			(601	)			—				(4,714	)			—
Unrealized gain (loss) on derivative instruments, net			3,676				(15,647	)			20,948				(21,111	)
Income (loss) from unconsolidated affiliates			991				(3,617	)			983				(2,870	)
Total other expense			(5,789	)			(33,783	)			(3,069	)			(54,774	)
Loss from continuing operations before income taxes and discontinued operations			(55,647	)			(175,167	)			(66,352	)			(200,835	)
Income tax expense (benefit)			203				265				478				(318	)
Loss from continuing operations			(55,850	)			(175,432	)			(66,830	)			(200,517	)
Discontinued operations:
Loss from discontinued operations, net of tax			(96,630	)			(5,051	)			(101,642	)			(9,400	)
Net loss			(152,480	)			(180,483	)			(168,472	)			(209,917	)
Less net loss attributable to non-controlling interest			2,730				8,165				5,925				12,046
Net loss attributable to Delta common stockholders		$	(149,750	)		$	(172,318	)		$	(162,547	)		$	(197,871	)
Amounts attributable to Delta common stockholders:
Loss from continuing operations		$	(53,120	)		$	(167,267	)		$	(60,905	)		$	(188,471	)
Loss from discontinued operations, net of tax			(96,630	)			(5,051	)			(101,642	)			(9,400	)
Net loss		$	(149,750	)		$	(172,318	)		$	(162,547	)		$	(197,871	)
Basic income (loss) attributable to Delta common stockholders per common share:
Loss from continuing operations		$	(0.19	)		$	(0.86	)		$	(0.22	)		$	(1.29	)
Discontinued operations			(0.35	)			(0.03	)			(0.37	)			(0.06	)
Net loss		$	(0.54	)		$	(0.89	)		$	(0.59	)		$	(1.35	)
Diluted income (loss) attributable to Delta common stockholders per common share:
Loss from continuing operations		$	(0.19	)		$	(0.86	)		$	(0.22	)		$	(1.29	)
Discontinued operations			(0.35	)			(0.03	)			(0.37	)			(0.06	)
Net loss		$	(0.54	)		$	(0.89	)		$	(0.59	)		$	(1.35	)
Weighted average common shares outstanding:
Basic			275,832				193,028				275,652				146,248
Diluted			275,832				193,028				275,652				146,248

DELTA PETROLEUM CORPORATION
AND SUBSIDIARIES
RECONCILIATION OF NON-GAAP MEASURES
(Unaudited)

($ in thousands)

		June 30,				June 30,
THREE MONTHS ENDED		2010				2009
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		$	(6,332	)		$	38,757
Changes in assets and liabilities			6,650				(3,778	)
Less net proceeds from offshore litigation award			—				(48,701	)
Exploration costs			358				471
Discretionary cash flow (deficiency)*		$	676			$	(13,251	)

		June 30,				June 30,
SIX MONTHS ENDED		2010				2009
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		$	(23,273	)		$	32,849
Changes in assets and liabilities			27,271				(11,286	)
Less net proceeds from offshore litigation award			—				(48,701	)
Exploration costs			584				1,531
Discretionary cash flow (deficiency)*		$	4,582			$	(25,607	)

		June 30,				June 30,
THREE MONTHS ENDED		2010				2009
Net loss		$	(152,480	)		$	(180,483	)
Minority interest			2,730				8,165
Income tax expense			203				265
Interest expense and financing costs, net			9,556				15,775
Depletion, depreciation and amortization			26,973				36,107
(Gain) loss on offshore litigation award, property sales and other			440				(1,643	)
Unrealized (gain) loss on derivative instruments, net			(3,676	)			15,647
Exploration, dry hole and impairment costs			123,287				107,092
EBITDAX**		$	7,033			$	925

		June 30,				June 30,
THREE MONTHS ENDED		2010				2009
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		$	(6,332	)		$	38,757
Changes in assets and liabilities			6,650				(3,778	)
Less net proceeds from offshore litigation award			—				(48,701	)
Interest net of financing costs			6,141				10,446
Exploration costs			358				471
Other non-cash items			216				3,730
EBITDAX**		$	7,033			$	925

		June 30,				June 30,
SIX MONTHS ENDED		2010				2009
Net loss		$	(168,472	)		$	(209,917	)
Minority interest			5,925				12,046
Income tax expense (benefit)			478				(318	)
Interest expense and financing costs, net			20,116				32,201
Depletion, depreciation and amortization			55,731				68,721
(Gain) loss on offshore litigation award, property sales and other			801				(32,928	)
Unrealized (gain) loss on derivative instruments, net			(20,948	)			21,111
Exploration, dry hole and impairment costs			123,867				109,595
EBITDAX**		$	17,498			$	511

		June 30,				June 30,
SIX MONTHS ENDED		2010				2009
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		$	(23,273	)		$	32,849
Changes in assets and liabilities			27,271				(11,286	)
Less net proceeds from offshore litigation award			—				(48,701	)
Interest net of financing costs			12,901				20,774
Exploration costs			584				1,531
Other non-cash items			15				5,344
EBITDAX**		$	17,498			$	511

		June 30, 2010												June 30, 2009
THREE MONTHS ENDED		Oil (Mbbl)				Gas (Mmcf)				Mmcfe				Oil (Mbbl)				Gas (Mmcf)				Mmcfe
Total Production			153				3,777				4,697				202				4,483				5,695
Less Wapiti Transaction production reported in discontinued operations***			(4	)			(773	)			(795	)			(4	)			(707	)			(731	)
Production from Continuing Operations			150				3,004				3,902				198				3,776				4,964
Less Wapiti Transaction production reported in continuing operations***			(54	)			(223	)			(547	)			(71	)			(316	)			(742	)
Production from Remaining Operations			96				2,781				3,355				127				3,460				4,222

		June 30, 2010												June 30, 2009
SIX MONTHS ENDED		Oil (Mbbl)				Gas (Mmcf)				Mmcfe				Oil (Mbbl)				Gas (Mmcf)				Mmcfe
Total Production			309				7,889				9,743				414				9,532				12,016
Less Wapiti Transaction production reported in discontinued operations***			(10	)			(1,590	)			(1,650	)			(9	)			(1,598	)			(1,652	)
Production from Continuing Operations			299				6,299				8,093				405				7,934				10,364
Less Wapiti Transaction production reported in continuing operations***			(106	)			(443	)			(1,079	)			(147	)			(627	)			(1,509	)
Production from Remaining Operations			193				5,856				7,014				258				7,307				8,855