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Abraxas Announces Second Quarter 2018 Financial and Operating Results

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Abraxas Petroleum Corporation (NASDAQ:AXAS) today reported financial and
operating results for the three and six months ended June 30, 2018.

Financial Highlights for the Three Months Ended
June 30, 2018

The three months ended June 30, 2018 resulted in:

  • Production of 745 MBoe (8,188 Boepd)
  • Revenue of $30.9 million
  • Net loss of $10.6 million, or $0.06 per share
  • Adjusted net income(a) (excluding certain non-cash items)
    of $3.2 million, or $0.02 per share
  • EBITDA(a) of $14.5 million
  • Adjusted EBITDA per bank loan covenants of $14.5 million(a)

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

Operational Highlights for the Three Months Ended
June 30, 2018
:

Williston Basin

In North Dakota, seven new wells were successfully fracture stimulated
and placed on production. Due to our conservative flowback protocol,
these wells have not yet achieved peak 30 day rates. On the Yellowstone
NE Central pad, three wells, one in the Middle Bakken and two in the
Three Forks, all with approximate 10,000 foot laterals, are currently
flowing back at a 2 stream average of 1,418 boe/d per well (81% oil).
This current rate is approximately 55% above our previously published
type curves. Abraxas owns a 51.6% working interest in this pad. On the
Lillibridge NE pad, four wells with approximate 10,000 foot laterals,
two each in the Middle Bakken and Three Forks, were successfully
completed and are flowing back on our conservative protocol without yet
achieving peak 30 day rates, at a 2 stream average of 771 boe/d per well
(81% oil). These wells are producing on or slightly below our previously
published type curves. This performance was not unexpected, as these are
infill wells next to wells that have been on production approximately
five years. Abraxas owns an average of approximately 26.8% in these
wells. Our Company owned drilling rig, Raven Rig #1, successfully
drilled four new wells with approximate 10,000 foot laterals on the
Ravin NE Central pad and is currently drilling laterals in four wells on
the Ravin NE pad. These eight wells are scheduled to be fracture
stimulated starting in mid-September. Abraxas owns an average 46.8%
working interest in these eight wells.

Delaware Basin

In the Delaware Basin of West Texas, specifically in Ward County,
Abraxas successfully completed and placed on production our four well
Caprito 99 downspacing test pad. These wells with approximate 4,800 foot
laterals have been on production for approximately one month and due to
our conservative flowback protocol have not achieved peak rates, which
from past experience we expect to achieve between 45 to 60 days from
initial oil production. The wells are currently producing at a 2 stream
average of 668 boe/d per well (88% oil). All wells are producing above
our previously published type curves. The two wells closest to our
original section 99 producer, which has been on production almost two
years, are not as strong with rate or pressure than the two wells
further away, showing some parent-child influence, the degree of which
will only be determined with production data over the next several
months. Abraxas collected a considerable amount of analytical data
including micro seismic and tracers to help analyze the amount of well
to well interference, if any, between these wells which were spaced 660
feet apart in the same zone as opposed to the previous spacing of 1,320
feet between wells in the same zone. This data along with production
data will be analyzed over the next several months to help determine
proper spacing for future development. Abraxas owns a 57.8% working
interest in this pad.

Five miles to the north, still in Ward County, Abraxas successfully
drilled the two well Greasewood pad with approximate 4,800 foot laterals
in the Upper Wolfcamp A-1 and A-2. These wells are currently being
fracture stimulated with flowback expected around mid-August. Abraxas
owns a 100% working interest in the Greasewood section. Five miles south
of Caprito, also in Ward County, Abraxas has successfully drilled the
two well Mesquite pad, with approximate 4,800 foot laterals in the Upper
Third Bone Spring (a new zone for Abraxas) and in the Lower Third Bone
Spring (successfully tested in Caprito 82). Abraxas owns a 73.3% working
interest in the Mesquite pad which is scheduled to be fracture
stimulated in mid-September. The rig is currently moving approximately
seven miles south but still in Ward County, to drill an approximate
4,800 foot lateral to test the Upper Wolfcamp A-1, in our Pecan 47 unit,
in which Abraxas owns a 100% working interest.

Potential Divestitures

Abraxas has entered into a definitive agreement to sell certain non-core
assets located on the Eastern Shelf of the Permian Basin, currently
producing approximately 113 boe/d (69% oil), for $3 million.

2018 Production and Guidance Update

Despite second quarter production levels, the Company reiterates its
yearly guidance for 2018.

      2018 Operating Guidance
     
Operating Costs Low High
 
LOE ($/Boe) $4.00 $6.00
Production Tax (% Rev) 8.0% 9.0%
Cash G&A ($mm) $8.5 $12.5
Production (boepd) 10,000 12,000
 

Comments

Bob Watson, President and CEO of Abraxas, commented, "Over the past
several months, Abraxas has concluded multiple land trades, swaps and
acquisitions in our core area of Ward County, Texas. The goal of these
transactions was to not only increase the size of our footprint, but to
also make our acreage better by trading non-operated leases for
interests that lead to operated tracts. We have been successful in this
endeavor and have additional deals still in the works. A new ownership
map will be released soon, which will show the vast majority of our
current 9,780 acres as operated. This number does not include 2,270 net
acres of perpetual minerals Abraxas owns in Pecos County, near the
Alpine High area, nor does it include any acres from deals in the final
stages of being formalized with additional parties. The 581 net acres
added in these transactions were at an average cost per acre
considerably less than recently announced transactions by industry in
our area. The remaining deals in the works target swapping the remaining
non-operated tracts for interests considered core, as well as additional
bolt ons to our existing acreage blocks.

"On the operations front, the second quarter was very active. Average
production for the quarter of 8,188 boe/d was lower than we originally
anticipated. During the quarter, we were informed of two third party
operators offset fracture activity which caused Abraxas to shut in and
subsequently remediate more wells than the Company had originally
anticipated at the end of the first quarter. In total, 18 high volume
wells were shut in for fracture protection for various lengths of time
during the quarter. Current production now exceeds 11,000 boe/d and is
continuing to grow as eleven new wells, detailed above, and the fracture
protected wells, are brought on line and cleaned up."

Conference Call

Abraxas Petroleum Corporation (NASDAQ:AXAS) will host its second quarter
2018 earnings conference call at 11 AM ET on August 8, 2018. To
participate in the conference call, please dial 844.347.1028 and enter
the passcode 3089129. 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 through September 5,
2018 by dialing 855.859.2056 and entering the passcode 3089129 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 Permian Basin, Rocky Mountain, and South Texas 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
 
    Three Months Ended     Six Months Ended
June 30, June 30,
(In thousands except per share data)   2018         2017     2018         2017  
Financial Results:
Revenue $ 30,916 $ 13,152 $ 71,546 $ 31,954
Net (loss) income (10,554 ) 7,195 225 20,885
Net (loss) income per share - basic $ (0.06 ) $ 0.04 $ 0.00 $ 0.13
Net (loss) income per share - diluted $ (0.06 ) $ 0.04 $ 0.00 $ 0.13
Capital expenditures - acquisitions 7,476 - 21,769 -
Capital expenditures - drilling and completion 37,290 29,496 54,352 40,453
Total capital expenditures 44,766 29,496 76,121 40,453
EBITDA(a) 14,472 8,135 41,487 19,853
Adjusted net income, excluding certain non-cash items(a) 3,151 2,124 18,024 7,054
Adjusted net income, excluding certain non-cash items, per share -
basic(a)
$ 0.02 $ 0.01 $ 0.11 $ 0.04
Adjusted net income, excluding certain non-cash items, per share -
diluted(a)
$ 0.02 $ 0.01 $ 0.11 $ 0.04
Liquidity(a) 63,632 84,402 63,632 84,402
Weighted average shares outstanding - basic 165,162 162,357 164,812 158,259
Weighted average shares outstanding - diluted 165,162 163,805 167,715 159,942
 
Production from Continuing Operations:
Crude oil per day (Bblpd) 4,821 2,873 5,763 3,308
Natural gas per day (Mcfpd) 12,290 7,817 12,732 9,115
Natural gas liquids per day (Bblpd) 1,318 996 1,445 1,165
Crude oil equivalent per day (Boepd) 8,188 5,172 9,330 5,992
Crude oil equivalent (Mboe) 745 471 1,689 1,085
 
Realized Prices, net of realized hedging activity:
Crude oil ($ per Bbl) $ 48.81 $ 48.54 $ 51.40 $ 48.02
Natural gas ($ per Mcf) 1.44 1.49 1.73 1.88
Natural gas liquids ($ per Bbl) 15.29 8.39 15.51 9.78
Crude oil equivalent ($ per Boe) 33.36 30.84 36.51 31.28
 
Expenses:
Lease operating ($ per Boe) $ 7.69 $ 7.27 $ 6.10 $ 6.95
Production taxes (% of oil and gas revenue) 8.0 % 8.8 % 7.8 % 8.7 %
General and administrative, excluding stock-based compensation ($
per Boe)
$ 2.93 $ 4.08 $ 2.56 $ 3.58
Cash interest ($ per Boe) 2.00 0.83 1.59 0.72
Depreciation, depletion and amortization ($ per Boe) 11.68 9.38 11.15 9.02
 

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

 
 
 
ABRAXAS PETROLEUM CORPORATION
CONSOLIDATED
 
BALANCE SHEET DATA
 
    June 30,     December 31,

(In thousands)

  2018     2017  
Cash $ 882 $ 1,618
Working capital (53,199 ) (34,361 )
Property and equipment - net 294,956 237,767
Total assets 330,807 273,806
 
Long-term debt - less current maturities 115,226 87,354
Stockholders' equity 108,014 106,308
Common shares outstanding 166,711 165,890
 

Working capital per bank loan covenants(a)

(31,461 ) (23,262 )
(a) Excludes current maturities of long-term debt and current
derivative assets and liabilities in accordance with our bank loan
covenants. This working capital calculation excludes the unused
commitment amount which is included for our current ratio
calculation.
 
 
ABRAXAS PETROLEUM CORPORATION
CONSOLIDATED
 

STATEMENTS OF OPERATIONS

 
    Three Months Ended     Six Months Ended
June 30, June 30,

(In thousands except per share data)

  2018         2017     2018         2017  
Revenues:
Oil $ 27,472 $ 11,313 $ 63,466 $ 26,814
Gas 1,608 1,063 3,985 3,045
Natural gas liquids   1,835     760     4,058     2,064  
30,915 13,136 71,509 31,923
Other   1     16     37     31  
30,916 13,152 71,546 31,954
Operating costs and expenses:
Lease operating 5,730 3,421 10,299 7,539
Production and ad valorem taxes 2,485 1,158 5,598 2,778
Depreciation, depletion, and amortization 8,705 4,415 18,835 9,789
General and administrative (including stock-based compensation of
$879, $979, $1,466 and $1,749, respectively)
  3,065     2,898     5,793     5,635  
  19,985     11,892     40,525     25,741  
Operating income 10,931 1,260 31,021 6,213
 
Other (income) expense:
Interest income (1 ) (1 ) (1 ) (1 )
Interest expense 1,627 501 2,956 1,008
Amortization of deferred financing fees 111 117 207 254
Loss (gain) on derivative contracts 19,763 (6,450 ) 27,646 (15,831 )
Gain on sale of non-oil and gas assets   (15 )   (102 )   (12 )   (102 )
  21,485     (5,935 )   30,796     (14,672 )
(Loss) income before income tax (10,554 ) 7,195 225 20,885
Income tax (expense) benefit   -     -     -     -  
Net (loss) income $ (10,554 ) $ 7,195   $ 225   $ 20,885  
 
Net (loss) income per common share - basic $ (0.06 ) $ 0.04 $ 0.00 $ 0.13
 
Net (loss) income per common share - diluted $ (0.06 ) $ 0.04 $ 0.00 $ 0.13
 
Weighted average shares outstanding:
Basic 165,162 162,357 164,812 158,259
Diluted 165,162 163,805 167,715 159,942
 
 

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") in the United States of America, EBITDA is an appropriate
measure of Abraxas' ability to satisfy capital expenditure obligations
and working capital requirements. EBITDA is defined as net income plus
interest expense, deferred income taxes, depreciation, depletion and
amortization expenses, impairments, unrealized gains and losses on
derivative contracts, and stock-based compensation. EBITDA is a non-GAAP
financial measure as defined under SEC rules. 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. EBITDA excludes some, but not all
items that affect net income and may vary among companies. The EBITDA
presented below may not be comparable to similarly titled measures of
other companies.

We have also disclosed Adjusted EBITDA per bank loan covenants. Adjusted
EBITDA per bank loan covenants is a non-GAAP financial measure as
defined under SEC rules. Our management believes that information
regarding Adjusted EBITDA per bank loan covenants is material to an
understanding of our financial condition and liquidity. Adjusted EBITDA
per bank loan covenants 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.
Adjusted EBITDA per bank loan covenants presented below may not be
comparable to similarly titled measures of other companies.

The following table provides a reconciliation of EBITDA and Adjusted
EBITDA to net income for the periods presented.

       
Three Months Ended Six Months Ended
June 30, June 30,
(In thousands)   2018         2017     2018       2017  
Net (loss) income $ (10,554 ) $ 7,195 $ 225 $ 20,885
Net interest expense 1,626 500 2,955 1,007
Depreciation, depletion and amortization 8,705 4,415 18,835 9,789
Amortization of deferred financing fees 111 117 207 254
Stock-based compensation 879 979 1,466 1,749
Unrealized loss (gain) on derivative contracts       13,705         (5,071 )       17,799       (13,831 )
EBITDA     $ 14,472       $ 8,135       $ 41,487     $ 19,853  
 
EBITDA $ 14,472 $ 8,135 $ 41,487 $ 19,853
Expenses related to equity offering/loan amendments/permitted
acquisitions
      9         703         212       4,493  
Adjusted EBITDA per bank loan covenants     $ 14,481       $ 8,838       $ 41,699     $ 24,346  
 

This release also includes a discussion of "adjusted net income,
excluding certain non-cash items," which is also a non-GAAP financial
measure as defined under SEC rules. The following table provides a
reconciliation of adjusted net income, excluding ceiling test impairment
and unrealized changes in derivative contracts. Management believes that
net income calculated in accordance with GAAP is the most directly
comparable measure to adjusted net income, excluding certain non-cash
items. The calculation of adjusted net income, excluding certain
non-cash items presented below may not be comparable to similarly titled
measures of other companies.

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, which requires Abraxas to record a gain or loss based on
the calculated value difference from the previous period-end valuation
for open contracts. For example, NYMEX oil prices on June 30, 2017 were
$46.04 per barrel compared to $74.15 on June 30, 2018; therefore, the
mark-to-market valuation changed considerably from period to period.

       
Three Months Ended Six Months Ended
June 30, June 30,
(In thousands except per share data)   2018         2017     2018       2017  
Net (loss) income $ (10,554 ) $ 7,195 $ 225 $ 20,885
Unrealized loss (gain) on derivative contracts       13,705         (5,071 )       17,799       (13,831 )
Adjusted net income, excluding certain non-cash items     $ 3,151       $ 2,124       $ 18,024     $ 7,054  
Net (loss) income per share - basic     $ (0.06 )     $ 0.04       $ 0.00     $ 0.13  
Net (loss) income per share - diluted     $ (0.06 )     $ 0.04       $ 0.00     $ 0.13  
Adjusted net income, excluding certain non-cash items, per share -
basic
    $ 0.02       $ 0.01       $ 0.11     $ 0.04  
Adjusted net income, excluding certain non-cash items, per share -
diluted
    $ 0.02       $ 0.01       $ 0.11     $ 0.04  
 

Liquidity is calculated by adding the net funds available under our
revolving credit facility and cash and cash equivalents. We use
liquidity as an indicator of the Company's ability to fund development
and exploration activities. However, this measurement has limitations.
This measurement can vary from year-to-year for the Company and can vary
among companies based on what is or is not included in the measurement
on a company's financial statements. This measurement is provided in
addition to, and not as an alternative for, and should be read in
conjunction with, the information contained in our financial statements
prepared in accordance with GAAP (including the notes), included in our
SEC filings and posted on our website.

       
(In thousands) June 30, 2018 June 30, 2017
Borrowing base $ 175,000 $ 115,000
Cash and cash equivalents 882 652
Revolving credit facility- outstanding borrowings (112,000 ) (31,000 )
Outstanding letters of credit       (250 )       (250 )
Liquidity     $ 63,632       $ 84,402  
 
 

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