Abraxas Announces Third Quarter 2015 Results

SAN ANTONIO--(BUSINESS WIRE)--Nov. 4, 2015-- Abraxas Petroleum Corporation (NASDAQ:AXAS) today reported financial and operating results for the three and nine months ended September 30, 2015.

On October 31, 2014 we closed on the sale of our interest in Canadian Abraxas Petroleum, ULC (“Canadian Abraxas”), a wholly-owned Canadian subsidiary of Abraxas Petroleum Corporation. As a result of the disposal of Canadian Abraxas, the results of operations of Canadian Abraxas are reflected in our Financial Statements and in this document as “Discontinued Operations” and our remaining operations are referred to in our Financial Statements and in this document as “Continuing Operations” or “Continued Operations.” Unless otherwise noted, all disclosures are for continuing operations.

Financial and Operating Results for the Three Months Ended September 30, 2015

The three months ended September 30, 2015 resulted in:

Production of 552 MBoe (6,004 Boepd)
Revenue of $17.8 million inclusive of realized hedge settlements
Adjusted EBITDA^(a) of $10.0 million inclusive of Raven Drilling
Adjusted discretionary cash flow^(a) of $9.2 million inclusive of Raven Drilling
Net loss of $52.4 million, or $0.50 per share
Adjusted net loss^(a), excluding certain non-cash items and inclusive of Raven Drilling of $2.7 million, or $(0.03) per share

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

Net loss for the three months ended September 30, 2015 was $52.4 million, or $0.50 per share, compared to net income of $25.4 million, or $0.24 per share, for the three months ended September 30, 2014.

Adjusted net loss, excluding certain non-cash items, for the three months ended September 30, 2015 was $2.7 million, or $(0.03) per share, compared to an adjusted net income, excluding certain non-cash items, of $16.1 million or $0.15 per share for the three months ended September 30, 2014. For the three months ended September 30, 2015 and 2014, adjusted net income (loss) excludes the unrealized gain on derivative contracts of $10.5 million and $10.0 million, respectively. Included in adjusted net income (loss) is the net income for the quarters ended September 30, 2015 and September 30, 2014 from our subsidiary, Raven Drilling, LLC of $0.2 million and $0.6 million, respectively. For the three months ended September 30, 2015 adjusted net loss excludes the loss attributable to the ceiling test impairment of $59.9 million.

Pursuant to SEC Regulation S-X, no income is recognized for Raven Drilling, LLC. Contractual drilling services performed in connection with properties in which Abraxas holds an ownership interest cannot be recognized as income, rather it is credited to the full cost pool and recognized through lower amortization as reserves are produced.

Unrealized gains or losses on derivative contracts are based on mark-to-market valuations which are non-cash in nature and may fluctuate drastically from 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 September 30, 2014 were $91.16 per barrel compared to $45.09 on September 30, 2015; therefore, the mark-to-market valuation changed considerably period to period.

Comments

Bob Watson, Abraxas' President and CEO, commented, “Our focus on driving down cash expenses benefited our financials as lease operating expenses (LOE) came in below the low end of the range at $9.48/Boe. We continue to look for ways to optimize the portfolio and drive costs out of the business, which with success will allow us to maintain solid operating margins despite the distressed commodity price environment.

“Despite significant shut in time associated with the postponed Bakken fracs and gas capture issues, our production steadied late in the third quarter. Looking into the fourth quarter, we will benefit from the addition of high margin barrels following the successful completion of three additional wells in the Bakken/Three Forks. Furthermore, the planned third party infrastructure expansion in the Bakken scheduled for the fourth quarter should eliminate the volatile production performance we experienced in 2015. We look forward to updating the street with updated 2015 guidance when we achieve stabilized rates from our new completions.”

Conference Call

Abraxas Petroleum Corporation (NASDAQ:AXAS) will host its third quarter 2015 earnings conference call at 11 AM ET on November 4, 2015. To participate in the conference call, please dial 888.680.0892 and enter the passcode 94482371. Additionally, a live listen only webcast of the conference call can be accessed under the investor relations section of the Abraxas website at www.abraxaspetroleum.com. A replay of the conference call will be available until December 2, 2015 by dialing 888.286.8010 and entering the passcode 31071155 or can be accessed under the investor relations section of the Abraxas website.

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

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.



ABRAXAS PETROLEUM CORPORATION
CONSOLIDATED

FINANCIAL HIGHLIGHTS

(In thousands except per share data)	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014

Financial Results:
Revenues	$	16,077		$	43,874		$	53,682		$	102,584
Adjusted EBITDA^(a)		10,043			31,804			35,189			70,861
Adjusted discretionary cash flow^(a)		9,161			31,342			32,711			69,171
Capital expenditures		12,931			44,733			52,614			137,462
Net income (loss)		(52,372	)		25,399			(59,691	)		33,137
Net income (loss) per share – basic	$	(0.50	)	$	0.24		$	(0.57	)	$	0.34
Net income (loss) per share – diluted	$	(0.50	)	$	0.24		$	(0.57	)	$	0.33
Adjusted net income (loss), excluding certain non-cash items^(a)		(2,726	)		16,124			(4,031	)		33,749
Adjusted net income (loss), excluding certain non-cash items^(a), per share – basic	$	(0.03	)	$	0.15		$	(0.04	)	$	0.35
Adjusted net income (loss), excluding certain non-cash items^(a), per share – diluted	$	(0.03	)	$	0.15		$	(0.04	)	$	0.34
Weighted average shares outstanding – basic		104,614			104,408			104,561			96,742
Weighted average shares outstanding – diluted		104,614			107,671			104,561			99,531

Production from Continuing Operations:
Crude oil per day (Bblpd)		3,967			4,743			4,030			3,570
Natural gas per day (Mcfpd)		8,154			9,086			8,229			7,645
Natural gas liquids per day (Bblpd)		678			752			618			517
Crude oil equivalent per day (Boepd)		6,004			7,010			6,020			5,361
Crude oil equivalent (MBoe)		552			645			1,643			1,463

Realized Prices, net of realized hedging activity:
Crude oil ($ per Bbl)	$	43.81		$	86.81		$	49.15		$	88.24
Natural gas ($ per Mcf)		2.02			3.86			2.39			4.21
Natural gas liquids ($ per Bbl)		5.07			32.11			9.32			36.25
Crude oil equivalent ($ per Boe)		32.26			67.19			37.12			68.26

Expenses:
Lease operating ($ per Boe)	$	9.48		$	11.06		$	10.83		$	12.55
Production taxes (% of oil and gas revenue)		9.8	%		8.5	%		9.8	%		8.6	%
General and administrative, excluding stock-based compensation ($ per Boe)		3.29			2.79			3.71			4.01
Cash interest ($ per Boe)		1.53			0.63			1.43			1.03
Depreciation, depletion and amortization ($ per Boe)		18.40			21.45			18.89			20.80

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



BALANCE SHEET DATA

(In thousands)	September 30, 2015			December 31, 2014

Cash	$	—		$	3,772
Working capital ^(a)		(21,463	)		(52,832	)
Property and equipment – net		284,420			322,879
Total assets		322,423			374,899

Long-term debt		124,991			76,554
Stockholders’ equity		151,058			207,495
Common shares outstanding		106,346			106,187

(a)

Excludes current maturities of long-term debt and current derivative assets and liabilities in accordance with our loan covenants.



ABRAXAS PETROLEUM CORPORATION
CONSOLIDATED
STATEMENTS OF OPERATIONS

(In thousands except per share data)	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014

Revenues:
Oil and gas production	$	16,075		$	43,865		$	53,658		$	102,521
Other		2			9			24			63
		16,077			43,874			53,682			102,584
Operating costs and expenses:
Lease operating		5,236			7,131			17,806			18,361
Production and ad valorem taxes		1,569			3,744			5,255			8,786
Depreciation, depletion, and amortization		10,165			13,836			31,044			30,441
Impairment		59,891			—			59,891			—
General and administrative (including stock-based compensation of $835, $582, $3,085, and $2,050, respectively)		2,654			2,379			9,190			7,915
		79,515			27,090			123,186			65,503
Operating (loss) income		(63,438	)		16,784			(69,504	)		37,081

Other (income) expense:
Interest income		—			—			(1	)		(1	)
Interest expense		992			548			2,784			1,927
Amortization of deferred financing fees		161			150			481			779
(Gain) loss on derivative contracts - realized		(1,745	)		534			(6,899	)		2,624
(Gain) on derivative contracts - unrealized		(10,474	)		(9,979	)		(6,198	)		(1,899	)
Other		—			(8	)		—			(8	)
		(11,066	)		(8,755	)		(9,833	)		3,422
(Loss) income from continuing operations before income tax		(52,372	)		25,539			(59,671	)		33,659
Income tax (expense) benefit		—			—			—			—
Net (loss) income from continuing operations		(52,372	)		25,539			(59,671	)		33,659
Net loss from discontinued operations - net of tax		—			(140	)		(20	)		(522	)
Net (loss) income	$	(52,372	)	$	25,399		$	(59,691	)	$	33,137


Net (loss) income per common share - basic
Continuing operations	$	(0.50	)	$	0.24		$	(0.57	)	$	0.35
Discontinued operations	$	—		$	—		$	—		$	(0.01	)
Net (loss) income per common share - basic	$	(0.50	)	$	0.24		$	(0.57	)	$	0.34

Net (loss) income per common share - diluted
Continuing operations	$	(0.50	)	$	0.24		$	(0.57	)	$	0.34
Discontinued operations	$	—		$	—		$	—		$	(0.01	)
Net (loss) income per common share - diluted	$	(0.50	)	$	0.24		$	(0.57	)	$	0.33

Weighted average shares outstanding:
Basic		104,614			104,408			104,561			96,742
Diluted		104,614			107,671			104,561			99,531

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 (loss) calculated in accordance with GAAP is the most directly comparable measure to discretionary cash flow; therefore, operating income (loss) is utilized as the starting point for the discretionary cash flow reconciliation.

Discretionary cash flow is defined as operating income (loss) plus depreciation, depletion and amortization expenses, non-cash expenses and impairments, cash portion of other income (expense) less cash interest. Adjusted discretionary cash flow is defined as discretionary cash flow, plus cash flow from Raven Drilling’s operations. Accounting rules do not permit the inclusion of the net income and other components of Raven Drilling’s operations to be included in our consolidated results of operations and cash flow, instead, the results of Raven Drilling’s operations are credited to the full cost pool. Accordingly, for purposes of adjusted discretionary cash flow, Raven Drilling’s cash flow is added back. The following table provides a reconciliation of discretionary cash flow and adjusted discretionary cash flow to operating income (loss) for the periods presented.


(In thousands)	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Operating income (loss)	$	(63,438	)	$	16,784		$	(69,504	)	$	37,081
Depreciation, depletion and amortization		10,165			13,836			31,044			30,441
Impairment		59,891			—			59,891			—
Stock-based compensation		835			582			3,085			2,050
Realized gain (loss) on derivative contracts ^(a)		1,745			(534	)		7,346			(2,624	)
Cash interest		(847	)		(406	)		(2,357	)		(1,506	)
Discretionary cash flow	$	8,351		$	30,262		$	29,505		$	65,442
Cash flow from Raven Drilling operations		810			1,080			3,206			3,729
Adjusted discretionary cash flow	$	9,161		$	31,342		$	32,711		$	69,171


(a)		Realized gain (loss) on derivative contracts does not include a loss of $0.4 million for the nine months ended 2015 related to the monetization of the July-December 2015 fixed price oil swaps. The monetization resulted in cash proceeds of $4.6 million.

EBITDA is defined as net income (loss) plus interest expense, depreciation, depletion and amortization expenses, deferred income taxes and other non-cash items. Adjusted EBITDA includes all of the components of EBITDA plus Raven Drilling’s EBITDA. Accounting rules do not permit the inclusion of the net income and other components of Raven Drilling’s operations to be included in our consolidated results of operations, instead, the results of Raven Drilling’s operations are credited to the full cost pool. Accordingly, for purposes of Adjusted EBITDA, Raven Drilling’s EBITDA is added back. The following table provides a reconciliation of EBITDA and Adjusted EBITDA to net income (loss) for the periods presented.


(In thousands)	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Net income (loss)	$	(52,372	)	$	25,399		$	(59,691	)	$	33,137
Net interest expense		992			548			2,783			1,926
Depreciation, depletion and amortization		10,165			13,836			31,044			30,441
Amortization of deferred financing fees		161			150			481			779
Stock-based compensation		835			582			3,085			2,050
Impairment		59,891			—			59,891			—
Unrealized (gain) on derivative contracts		(10,474	)		(9,979	)		(6,198	)		(1,899	)
Realized loss on derivative monetization		—			—			447			—
Loss from discontinued operations		—			140			20			522
Other non cash items		—			(8	)		—			(8	)
EBITDA	$	9,198		$	30,668		$	31,862		$	66,948
Raven Drilling EBITDA		845			1,136			3,327			3,913
Adjusted EBITDA	$	10,043		$	31,804		$	35,189		$	70,861


EBITDA	$	9,198		$	30,668		$	31,862		$	66,948
Monetized derivative contracts		—			—			4,610			—
Adjusted EBITDA per bank covenants	$	9,198		$	30,668		$	36,472		$	66,948

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 unrealized changes in derivative contracts and net income related to Raven Drilling, LLC capitalized to the full cost pool, 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 September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014

Net income (loss)	$	(52,372	)	$	25,399		$	(59,691	)	$	33,137
Impairment		59,891			—			59,891			—
Net income related to Raven Drilling		229			564			1,500			1,989
Unrealized (gain) on derivative contracts		(10,474	)		(9,979	)		(6,198	)		(1,899	)
Realized loss on derivative monetization		—			—			447			—
Loss from discontinued operations		—			140			20			522
Adjusted net income (loss), excluding certain non-cash items	$	(2,726	)	$	16,124		$	(4,031	)	$	33,749
Adjusted net income (loss), excluding certain non-cash items, per share – basic	$	(0.03	)	$	0.15		$	(0.04	)	$	0.35
Adjusted net income (loss), excluding certain non-cash items, per share – diluted	$	(0.03	)	$	0.15		$	(0.04	)	$	0.34
Net income (loss) per share – basic	$	(0.50	)	$	0.24		$	(0.57	)	$	0.34
Net income (loss) per share – diluted	$	(0.50	)	$	0.24		$	(0.57	)	$	0.33

View source version on businesswire.com: http://www.businesswire.com/news/home/20151104005263/en/

Source: Abraxas Petroleum Corporation

Abraxas Petroleum Corporation
Geoffrey King, 210-490-4788
Vice President – Chief Financial Officer
[email protected]
www.abraxaspetroleum.com

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