Abraxas Petroleum (AXAS) 8-K Abraxas Announces 2011 Results and Provides an Operational Update

ABRAXAS PETROLEUM CORPORATION

www.abraxaspetroleum.com

Exhibit 99.1

NEWS RELEASE

Abraxas Announces 2011 Results and Provides an Operational Update

SAN ANTONIO (March 15, 2012) – Abraxas Petroleum Corporation (NASDAQ:AXAS) today reported financial and operating results for the three and twelve months ended December 31, 2011 and provided an operational update.

Financial and Operating Results

Including Abraxas’ equity interest in Blue Eagle’s production, the twelve months ended December 31, 2011 resulted in:

·   Production of 1.4 MMBoe (3,762 Boepd), of which 45% was oil or natural gas liquids

The twelve months ended December 31, 2011 resulted in:

·   Production of 1.3 MMBoe (3,484 Boepd), excluding Abraxas’ equity interest in Blue Eagle’s production

·   Revenue of $64.6 million

·   EBITDA(a) of $31.5 million

·   Discretionary cash flow(a) of $24.7 million

·   Net income of $13.7 million, or $0.15 per share

·   Adjusted net income(a) of $6.3 million, or $0.07 per share, excluding certain non-cash items

(a)   See reconciliation of non-GAAP financial measures below.

Net income for the year ended December 31, 2011 was $13.7 million, or $0.15 per share, compared to a net income of $1.8 million, or $0.02 per share, for the year ended December 31, 2010.

Adjusted net income, excluding certain non-cash items, for the year ended December 31, 2011 was $6.3 million, or $0.07 per share, compared to adjusted net loss, excluding certain non-cash items, of $3.7 million or $0.05 per share for the year ended December 31, 2010.  For the year ended December 31, 2011, adjusted net income excludes the unrealized gains on derivative contracts of $7.5 million.  For the year ended December 31, 2010, adjusted net loss excludes the ceiling test impairment of $4.8 million and unrealized gains on derivative contracts of $10.3 million.

Unrealized gains or losses on derivative contracts are based on mark-to-market valuations which are non-cash in nature and may fluctuate drastically period to period.  As commodity prices fluctuate, these derivative contracts are valued against current market prices at the end of each reporting period in accordance with Accounting Standards Codification 815, “Derivatives and Hedging,” as amended and interpreted, and require Abraxas to either record an unrealized gain or loss based on the calculated value difference from the previous period-end valuation.  For example, NYMEX oil prices on December 31, 2011 were $98.83 per barrel compared to $79.20 on September 30, 2011; therefore, the mark-to-market valuation changed considerably period to period.

18803 Meisner Drive

San Antonio, Texas 78258

Phone: 210.490.4788    Fax: 210.918.6675

Operational Update

Rocky Mountain – North Dakota / Montana

·   In the Bakken / Three Forks play in the Williston Basin, during the fourth quarter of 2011, 1 gross (<1% net) non-operated well came on-line and 2 gross (0.3 net) wells are currently drilling or awaiting completion.  Additionally, we have recently elected to participate in 6 gross (0.6 net) wells that have yet to spud.

·   The refurbishment of the Company owned drilling rig has been completed and the rig is currently on its way to McKenzie County, North Dakota to begin drilling its first multi-well pad site.

Rocky Mountain – Wyoming

·   In Campbell County, Wyoming, the Hedgehog State 16-2H, a horizontal well targeting the Turner formation, was recently completed with a 17-stage fracture stimulation.  The well is currently flowing back with encouraging initial results.  Abraxas owns a 100% working interest in this well.

South Texas – Eagle Ford

·   At December 31, 2011, Abraxas owned a 34.7% equity interest in Blue Eagle, a joint venture between Abraxas and Rock Oil Company, LLC.

·   In McMullen County, Texas, the Cobra 1H, a horizontal well targeting the Eagle Ford Shale, was recently completed with a 15-stage fracture stimulation.  The well is currently flowing back at very promising rates.  Blue Eagle owns a 100% working interest in this well.

Canada – Pekisko

·   In Alberta, Canada, the pipeline hook-up for three wells is underway and should be completed within the next few weeks.  Two wells continue to await stimulation; however, the completions have been delayed as the availability of acid for the stimulations is in short supply.  Canadian Abraxas owns a 100% working interest in each of these wells which have targeted the Pekisko formation.

Commodity Hedges

The Company’s gas hedges were recently monetized for $12.4 million and additional NYMEX-based fixed price oil hedges were entered into at prices above $100 per barrel for the remainder of 2012 through 2014.

Comments

“2011 was an eventful year for us.  We embarked on a new endeavor to own and operate our own 2000 hp drilling rig in the Williston Basin.  The rig has been completely refurbished, winterized and equipped with a top drive and walking system, as well as many other new components.  The rig is currently being trucked to North Dakota and after assembly, it will begin drilling pad development wells in McKenzie County where we have all of the infrastructure, including a semi-permanent man camp for our rig employees, in place and ready to go.  We, as are all heavy load transporters, are having to deal with some road detours due to the frost melt but so far we haven’t encountered anything insurmountable.  Production in the 4th quarter was negatively impacted from reduced gas production as a number of our dry gas wells were subjected to shut-ins and curtailments due to pipeline and gas plant capacity issues.  We determined that spending capital to access alternative delivery points did not make sense in the current gas price environment.  We did not make our exit rate guidance due to various delays in getting wells on production, which is becoming standard in our industry in both the U.S. and Canada; nonetheless, the Canadian pipeline construction is almost complete and two new wells in the Eagle Ford and a well in the Turner formation (Wyoming) are currently cleaning up or have recently come on-line.  Therefore, we have a good chance of achieving our exit rate guidance, just delayed by a few months.  During 2012, all of our activity will be focused on oil and liquids-rich projects as we continue to increase our percentage of oil & NGLs to take advantage of the commodity price arbitrage between oil and natural gas.  In addition, we will continue to high-grade our diverse portfolio of assets.  Since the Blue Eagle joint venture (Eagle Ford Shale Play, South Texas) has experienced great success since its formation 18 months ago, we will be exploring strategic alternatives this year for this property as well as for an acreage block in the Wolfbone play in Reeves County, Texas and potentially our interest in the Pekisko play in Alberta, Canada,” commented Bob Watson, Abraxas’ President and CEO.

Conference Call

Abraxas invites you to participate in a conference call on Thursday, March 15, 2012, at 2:00 p.m. CT (3:00 p.m. ET) to discuss the contents of this release and respond to questions.  Please dial 1.866.713.8310, passcode 40561271, 10 minutes before the scheduled start time, if you would like to participate in the call.  The conference call will also be webcast live on the Internet and can be accessed directly on the Company’s website at www.abraxaspetroleum.com under Investor Relations.  In addition to the audio webcast replay, a transcript of the conference call will be posted on the Investor Relations section of the Company’s website approximately 24 hours after the conclusion of the call, and will be accessible for at least 60 days.

Abraxas Petroleum Corporation is a San Antonio based crude oil and natural gas exploration and production company with operations across the Rocky Mountain, Mid-Continent, Permian Basin and onshore Gulf Coast regions of the United States and in the province of Alberta, Canada.

Safe Harbor for forward-looking statements:  Statements in this release looking forward in time involve known and unknown risks and uncertainties, which may cause Abraxas’ actual results in future periods to be materially different from any future performance suggested in this release.  Such factors may include, but may not be necessarily limited to, changes in the prices received by Abraxas for crude oil and natural gas.  In addition, Abraxas’ future crude oil and natural gas production is highly dependent upon Abraxas’ level of success in acquiring or finding additional reserves.  Further, Abraxas operates in an industry sector where the value of securities is highly volatile and may be influenced by economic and other factors beyond Abraxas’ control.  In the context of forward-looking information provided for in this release, reference is made to the discussion of risk factors detailed in Abraxas’ filings with the Securities and Exchange Commission during the past 12 months.

FOR MORE INFORMATION CONTACT:

Barbara M. Stuckey/Vice President – Chief Financial Officer

Telephone 210.490.4788

bstuckey@abraxaspetroleum.com

www.abraxaspetroleum.com

ABRAXAS PETROLEUM CORPORATION

CONSOLIDATED

FINANCIAL HIGHLIGHTS

	Three Months Ended December 31,						Twelve Months Ended December 31,
	2011			2010			2011			2010
Financial Results (In thousands except per share data):
Revenues	$	16,453		$	13,834		$	64,622		$	58,060
EBITDA(a)		7,742			6,330			31,504			28,200
Discretionary cash flow(a)		6,298			3,615			24,714			17,310
Net income (loss)		(5,260	)		(13,861	)		13,743			1,766
Net income (loss) per share – basic	$	(0.06	)	$	(0.18	)	$	0.15		$	0.02
Adjusted net income (loss), excluding certain non-cash items(a)		(11,215	)		(1,391	)		6,267			(3,732	)
Adjusted net income (loss), excluding certain non-cash  items(a), per share – basic	$	(0.12	)	$	(0.02	)	$	0.07		$	(0.05	)
Weighted average shares outstanding – basic		91,590			75,989			90,151			75,923
Production:
Crude oil per day (Bopd)		1,564			1,369			1,479			1,366
Natural gas per day (Mcfpd)		11,248			13,345			11,567			15,011
Natural gas liquids (Bblpd)		111			29			77			28
Crude oil equivalent per day (Boepd)		3,549			3,621			3,484			3,896
Crude oil equivalent (MBoe)		327			333			1,272			1,422
Crude oil equivalent per day (Boepd) (b)		3,749			3,621			3,762			3,896
Crude oil equivalent (MBoe) (b)		345			333			1,373			1,422
Realized Prices, net of realized hedging activity:
Crude oil ($ per Bbl)	$	77.23		$	66.44		$	76.11		$	66.76
Natural gas ($ per Mcf)		5.58			4.96			5.64			4.97
Natural gas liquids ($ per Bbl)		49.77			38.54			50.07			37.81
Crude oil equivalent ($ per Boe)		53.28			43.68			52.13			42.81
Expenses:
Lease operating ($ per Boe)	$	19.38		$	14.25		$	16.97		$	13.69
Production taxes (% of oil and gas revenue)		9.3	%		10.1	%		8.9	%		10.2	%
General and administrative, excluding stock-based compensation ($ per Boe)		5.49			6.27			5.85			5.14
Cash interest ($ per Boe)		2.62			6.39			3.49			6.03
Depreciation, depletion and amortization ($ per Boe)		14.77			11.15			12.73			11.40

(a)   See reconciliation of non-GAAP financial measures below.

(b)   Includes Abraxas’ equity interest in Blue Eagle’s production.

BALANCE SHEET DATA

(In thousands)	December 31, 2011			December 31, 2010
Cash	$	—		$	99
Working capital (a)		(14,404	)		(5,948	)
Property and equipment – net		179,552			117,248
Total assets		241,150			182,909
Long-term debt		126,258			140,940
Stockholders’ equity (deficit)		62,651			(14,976	)
Common shares outstanding		92,261			76,428

(a)   Excludes current maturities of long-term debt and current derivative assets and liabilities.

ABRAXAS PETROLEUM CORPORATION

CONSOLIDATED

STATEMENTS OF OPERATIONS

(In thousands except per share data)	Year Ended December 31,
	2011		2010		2009
Revenues:
Oil and gas production	$	64,615	$	58,050	$	51,829
Other	7		10		7
	64,622		58,060		51,836
Operating costs and expenses:
Lease operating	21,581		19,475		20,265
Production and ad valorem taxes	5,766		5,910		5,803
Depreciation, depletion, and amortization	16,194		16,212		17,886
Ceiling test impairment	—		4,787		—
General and administrative (including stock-based compensation of $1,987, $1,560 and $1,239)	9,433		8,869		7,705
	52,974		55,253		51,659
Operating income	11,648		2,807		177
Other (income) expense:
Interest income	(7)		(8)		(15)
Interest expense	4,898		9,106		11,346
Amortization of deferred financing fees	1,762		2,479		1,326
Loss (gain) on derivative contracts - realized	676		(526)		(15,328)
(Gain) loss on derivative contracts - unrealized	(7,476)		(10,285)		27,650
Financing fees	—		—		362
Equity in (income) loss of joint venture	(2,187)		473		—
Other	316		(119)		2,071
	(2,018)		1,120		27,412
Income (loss) before income tax and non-controlling interest	13,666		1,687		(27,235)
Income tax benefit (expense)	77		79		(1,290)
Income (loss) before non-controlling interest	13,743		1,766		(28,525)
Non-controlling interest	—		—		9,745
Net income (loss)	$	13,743	$	1,766	$	(18,780)
Net income (loss) per common share - basic	$	0.15	$	0.02	$	(0.34)
Net income (loss) per common share - diluted	$	0.15	$	0.02	$	(0.34)
Weighted average shares outstanding:
Basic		90,151		75,923		55,499
Diluted		92,244		77,224		55,499

 

ABRAXAS PETROLEUM CORPORATION

 RECONCILIATION OF NON-GAAP FINANCIAL MEASURES

To fully assess Abraxas’ operating results, management believes that, although not prescribed under generally accepted accounting principles ("GAAP"), discretionary cash flow and EBITDA are appropriate measures of Abraxas' ability to satisfy capital expenditure obligations and working capital requirements.  Discretionary cash flow and EBITDA are non-GAAP financial measures as defined under SEC rules. Abraxas' discretionary cash flow and EBITDA should not be considered in isolation or as a substitute for other financial measurements prepared in accordance with GAAP or as a measure of the Company's profitability or liquidity.  As discretionary cash flow and EBITDA exclude some, but not all items that affect net income and may vary among companies, the discretionary cash flow and EBITDA presented below may not be comparable to similarly titled measures of other companies.  Management believes that operating income calculated in accordance with GAAP is the most directly comparable measure to discretionary cash flow and EBITDA; therefore, operating income is utilized as the starting point for these reconciliations.

Discretionary cash flow is defined as operating income plus depreciation, depletion and amortization expenses, non-cash expenses and impairments, cash portion of other income (expense) less cash interest. The following table provides a reconciliation of discretionary cash flow to operating income for the periods presented.

(In thousands)	Three Months Ended December 31,						Twelve Months Ended December 31,
	2011			2010			2011			2010
Operating income (loss)	$	1,482		$	(3,251	)	$	11,648		$	2,807
Depreciation, depletion and amortization		4,823			3,717			16,194			16,212
Ceiling test impairment		—			4,787			—			4,787
Stock-based compensation		488			355			1,987			1,560
Realized gain (loss) on derivative contracts		361			136			(676	)		526
Cash interest		(856	)		(2,129	)		(4,439	)		(8,582	)
Discretionary cash flow	$	6,298		$	3,615		$	24,714		$	17,310

EBITDA is defined as net income (loss) plus interest expense, depreciation, depletion and amortization expenses, deferred income taxes and other non-cash items.  The following table provides a reconciliation of EBITDA to operating income for the periods presented – see consolidated statements of operations for a reconciliation of net income (loss) to operating income.

(In thousands)	Three Months Ended December 31,					Twelve Months Ended December 31,
	2011		2010			2011		2010
Operating income (loss)	$	1,482	$	(3,251	)	$	11,648	$	2,807
Depreciation, depletion and amortization		4,823		3,717			16,194		16,212
Ceiling-test impairment		—		4,787			—		4,787
Stock-based compensation		488		355			1,987		1,560
Realized gain (loss) on derivative contracts(a)		949		722			1,675		2,834
EBITDA	$	7,742	$	6,330		$	31,504	$	28,200

(a)   Excludes realized gain (loss) associated with interest rate derivative contract.

·This release also includes a discussion of “adjusted net income (loss), excluding certain non-cash items,” which is a non-GAAP financial measure as defined under SEC rules.  The following table provides a reconciliation of adjusted net income (loss), excluding ceiling test impairment and change in unrealized derivative contracts, to net income (loss) for the periods presented.  Management believes that net income (loss) calculated in accordance with GAAP is the most directly comparable measure to adjusted net income (loss), excluding certain non-cash items.

·

·

(In thousands)	Three Months Ended December 31,						Twelve Months Ended December 31,
	2011			2010			2011			2010
Net income (loss)	$	(5,260	)	$	(13,861	)	$	13,743		$	1,766
Ceiling test impairment		—			4,787			—			4,787
Loss (gain) on unrealized derivative contracts		(5,955	)		7,683			(7,476	)		(10,285	)
Adjusted net income (loss), excluding certain non-cash items	$	(11,215	)	$	(1,391	)	$	6,267		$	(3,732	)
Net income (loss) per share – basic		(0.06	)		(0.18	)		0.15			0.02
Adjusted net income (loss), excluding certain non-cash items, per share – basic	$	(0.12	)	$	(0.02	)	$	0.07		$	(0.05	)