Abraxas Petroleum (AXAS) 8-K Regulation FD Disclosure

November 2012

Stephens

Exhibit 99.1

2

Forward-Looking Statements

The information presented herein may contain predictions, estimates and other
forward-looking statements within the meaning of Section 27A of the Securities
Act of 1933 and Section 21E of the Securities Exchange Act of 1934.Although
the Company believes that its expectations are based on reasonable
assumptions, it can give no assurance that its goals will be achieved.

Important factors that could cause actual results to differ materially from those
included in the forward-looking statements include the timing and extent of
changes in commodity prices for oil and gas, the need to develop and replace
reserves, environmental risks, competition, government regulation and the
ability of the Company to meet its stated business goals.

3

Corporate Profile

Shares outstanding(1)…….......93.3
mm

Institutional………………..~59%

Insider………………………..~13%

Market cap(2) ……………………...$188
mm

Bank debt net of cash(1)……….$131
mm

PV-10(3)………………………………..
$276mm

EV/BOE(1,2,3)………………………….
$11.13

(1)As of 9/30/12; production inclusive ofBlue Eagle interest

(2)As of 10/31/12

(3)As of 6/30/12 inclusive of Blue Eagle interest and CANAXAS reserves.Uses 6/29/12 strip

(4)Based on mid year reserves and 3Q12 production annualized; inclusive of Blue Eagle

Proved Reserves(3).………….....30.8
mmboe

% Oil/Liquids………………~54%

% Proved developed…..~49%

% Operated PV-10………~94%

Production(1).………………………
~4,172boepd

R/P Ratio(4)………………………….
20.2x

2012E CAPEX………………………
$70mm

NASDAQ: AXAS

4

Investment Thesis

ØExposure to “core” acreage in top U.S. oil resource plays

ØSignificant exposure to emerging NAM oil resource plays

Premier
Acreage

Value +
Growth

ØLow decline legacy production

Ø“Manufacturing” model in repeatable resource plays leads to visible growth

ØRecent neighboring transactions recognize significant unbooked upside

Proven
Operator

ØCompany owned rig in Bakken = pad drilling = efficiency gains

ØDeep technical and G&G staff

Oil
Weighted

Ø53% crude oil and liquids weighted(1)

ØPercentage likely to grow meaningfully given capital focus

(1)As of 06/30/12; production inclusive ofBlue Eagle interest

5

Business Plan - 2012& Beyond

§FOCUS + DELEVER + GROW

§ReFOCUS Portfolio and CAPEX on Highest Returning Basins

§Currently: Williston, Eagle Ford, PRB, Permian

§DELEVER: Actively Pursue Divestitures

§Properties trading above internal assessment of fair value

§Lack of scale/high margin production

§Reduce leverage and maintain that profile

§Target Debt/EBITDA < 2.0x by YE13 (1)

§GROW:The Outcome of Sound Investment Decisions

§Bakken/TFS:

§Accelerate with company owned drilling rig

§Eagle Ford:

§Mobilize rig to commence 10 well program

(1)Excluding building mortgage and rig loan which are secured by the building and rig, respectively.EBITDA definition per bank loan agreement

6

Low Risk Development

Focus On Four Core Positions in Premier Oil Resource Plays Predominately HBP

§Williston: 23,000+ net acres; Bakken, Three Forks

§Eagle Ford: 7,300+ net acres: Eagle Ford, Buda

§PRB: 17,000+ net acres; stacked potential

§Permian: 40,000+ net acres: conventional & stacked pay opportunities

Premier Positions in Emerging Oil Resource Plays

§Permian: 40,000+ net acres; exposure to numerous emerging plays

§Canada: 20,000+ net acres; stealth oil play

Low Risk Conventional Development

§Williston Basin: Red River/Duperow

§PermianBasin: Spires Ranch - hz Strawn

§Permian Basin: Delaware Basin - dry gas

7

ND

MT

WY

CO

UT

OK

Proved Reserves (MMBoe)(1):30.8

•Proved Developed:49%

•Liquids:54%

•Operated (by PV10):94%

Abraxas Petroleum Corporation

Williston:

Bakken / Three Forks

Permian Basin: Midland/Eastern Shelf

Emerging Cline, Wolfcamp

Permian Basin: CBP Conventional

Rocky Mountain

Mid-Continent

Permian Basin

Gulf Coast

Eagle Ford Shale

High Quality Assets

Alberta

PRB:

Niobrara, Turner

Alberta

Permian Basin: Delaware

Emerging Bone Spring, Wolfcamp

(1)Net proved reserves as of June 30, 2012, including AXAS’ share of

Blue Eagle’s proved reserves per the September 2012 dissolution

8

Reserve / Production Summary

Proved Reserves(1) - 30.8 MMBoe

Production(2) - 4,172 Boepd

Production Mix

Revenue By Production Stream

9

AXAS Production

(1) Includes AXAS’ share of Blue Eagle’s production (50% in Q1 and Q2 2011, 41% in Q3 2011 and 35% in Q4 2011, Q1 2012 andQ2 2012)

Oil/NGL %34%35%36%39%43%44%48%48%52%53%53%

Production Net to AXAS(1)

61% Liquids
Growth
Since 1Q10

10

2012 Capital Budget

§Large inventory of drilling locations in unconventional and conventional oil plays

§Additional inventory of gas projects await higher gas prices (all HBP)

(1)Unrisked locations based on eight wells (four Bakken and four Three Forks) per 1,280 acre units; 80 acre spacing assumptions in the Eagle Ford Shale; 3-D identified locations in the
Niobrara Shale play;

(2)Inclusive of 298 net acre pending acquisition at WyCross

Project Area	Net Acres	Net Unrisked Locations(1)	2012 Drilling Program		2012 Net Capital ($MM)
			Gross	Net
Bakken / Three Forks	23,320	146	32.0	4.8	$34.0
Eagle Ford Shale (2)	7,306	91	3.0	0.75	$6.1
PRB	17,800	54	1.0	1.0	$9.0
Permian Basin	41,131	NA	3.0	3.0	$6.3
Pekisko Fairway	5,760	6	1.0	1.0	$8.9
Other	20,000+	-	-	-	$5.8
Total:	123,764+	297+	37.0	10.6	$70.1

11

AXAS Hedges

	2012	2013	2014	2015	2016
OIL - weighted average price	$76.00	$86.70	$94.05	$85.00	$84.00
% of 3Q Oil Production	~66%	~71%	~59%	~50%	~47%
$MM Revenue Protected	$34mm	$42mm	$37mm	$29mm	$27mm

NYMEX-based fixed price swaps:

12

(1)PV10 calculated using strip pricing as of 4/18/12

(2)PV10 calculated using strip pricing as of 6/29/12

Acquisition/Dissolution Reserve Adds

13

Bakken / Three Forks

County	McKenzie	Richland	Burke	Sheridan	Billings	Divide	Roosevelt	Williams	Stark	Dunn
Net Acres	5,535	5,551	3,255	2,261	1,879	1,442	1,367	1,239	563	123
Percent Operated	55%	30%	0%	0%	0%	0%	47%	0%	0%	0%
Net Bakken Locations (1)	17	17	10	7	6	5	4	4	0	1
Net TFS Locations(1)	17	17	10	7	6	5	4	4	2	1

(1)Unrisked locations based on eight wells (four Bakken and four Three Forks) per 1,280 acre units;

§109,658 Gross/23,320 Net Acres

§~100% held by production

§Drilling Inventory:

§D&M Risked/Identified

§409 gross / 64 net

§$34.0 MM budget

§Operated

§Pad-drilling

§Company owned rig

§7 gross (3.62 net)

§Non-operated wells

§2012 to-date

§25 gross (1.1 net)

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Recent QEP/Helis Transaction

§Approximately 5 Miles East of North Fork

§Transaction metrics

§$1.38 bn for 27.6k net acres

§10,500 boepd

§@ $80k/mboepd = $19,600/acre

§Assumed EUR: 1mmboe

§Abraxas North Fork

§3,314 net acres

§1,280 acre units: 8 B/TF wells

§Locations: 64 gross (19.7 net)

§Drilled: 4 gross (1.5 net)

§Remaining: 60 gross (18.2 net)

§Assumed EUR: 462mboe

15

Bakken / Three Forks

§North Fork

§3,314 Net Acres

§D&M Risked Operated Locations:

§Drilled: 2 Gross / 1.4 Net

§Completing: 3 Gross / 1.7 Net

§Remaining: 26 Gross / 12 Net

§Recent Operated Activity:

§Ravin 26-35 1H:

§Cum. production (22 mos): 122 Mboe

§Stenehjem 27-34 1H:

§Cum. production (14 mos): 120 MBoe

§Ravin 26-35 2H:

§COMPLETING

§Ravin 26-35 3H:

§COMPLETING

§Jore Federal 2-11 3H:

§COMPLETING

16

Bakken / Three Forks

Significant Long Term Investments:

§Raven Drilling:

§2000 HP walking rig

§Dedicated AXAS crew

§Company owned man camp

§Allows for significant efficiency gains

§North Fork Water System

§Will service all North Fork wells

§Enables AXAS to achieve cost savings via
centrally located frac pond & disposal well

17

Economics:

§~462 mboe recovery

§80% oil; 8% NGLs; 11% gas

§$8.7mm D&C

Parameters

di99.0

b1.5

dm7.0

GOR1150

Bakken / Three Forks

18

Eagle Ford Shale

§Blue Eagle Joint Venture:

§Dissolved as of September 1, 2012

§WyCross McMullen County:

§~25% working interest

§6,139 gross / 999 net(1)

§Eagle Ford: Volatile Oil

§Jourdantan: Atascosa County

§100% working interest

§~4,467 gross / 4,399 net

§Eagle Ford/Buda: Oil

§Yoakum: DeWitt county

§100% working interest

§2,097 gross / 1,908 net

§Eagle Ford: Dry Gas

§Planned Activity:

§10 well program

§Cobra B1H: Completing

§Mustang 1H: Currently Drilling

§Economics (WyCross):

§EUR 575mmboe

§$8.0mm D&C

(1) 298 acres pending acquisition

19

Eagle Ford Shale - Core Area

WyCross

§Core of the volatile oil window

§6,139 Gross/999 Net(1)

§Locations (assuming 80s)

§77 Gross / 19 net

§Cobra 1H

§Cum. production (7 mos): 120 MBoe

§95% Oil / NGLs

§Cobra B 1H

§Completion Scheduled 11/12

§Mustang 1H

§Drilling

§Corvette C 1H

§Permitted

(1) 298 acres pending acquisition

20

Eagle Ford - WyCross

Economics:

§~575 mboe recovery

§70% oil; 11% NGLs; 20% gas

§$8mm D&C

Parameters

di99.11

b1.3

dm7.0

GOR1000

21

PRB - Stacked Pay Opportunities

Converse / Niobrara Counties, Wyoming

§Gross / Net Acres:

§20,720 / 17,800

§Primarily in Converse and Niobrara
Counties

§~2,100 net acres in Campbell County

§~90% held by production

§Drilling Inventory:

§54 net locations (3-D identified)

§Historical Activity:

§13 wells (2000 - 2011)

(8 horizontal / 5 vertical)

§Recent Activity:

§Hedgehog State 16-2H (Crossbow)

§Restricted rate - 400 Boepd

§> $5.00 per Mcf w/ NGLs

§100% working interest

§Cum (6 months): 79 MBoe

§54% Oil / NGLs

Brooks Draw:

Sage Grouse 3H:

(Cum Oil 25 MBbl / 50 MBbl EUR)

Prairie Falcon 3H (Niobrara)

Recent Industry Activity:

74 Permits

8 Completions

Porcupine Field:

Hedgehog State 16-2H(Turner)

22

PRB - Hedgehog State 16 - 2H

23

Permian Basin - Ward County Acq.

§Purchase Price…$6.7mm(1)

§PDP PV -15………$6.7mm(2)

§Assumes 5/1/12 Strip

§5/1/12 2012 Strip = $2.29

§Production……...1,440 mcfepd

§Reserves…….......7.613 bcfe

§Transaction Metrics

§Production:$4,650/mcfe/day

§Reserves:$.88/mcfe

§Upside Potential

§Producing into low pressure line

§Emerging Horizontal Plays

§Previously > 20 bcfe booked PUD reserves
(net to Abraxas’ interest)

(1)Net of purchase price adjustments

(2)PV10 calculated using strip pricing as of 5/1/12

24

Permian Basin - Spires Ranch

§5,600 Gross/Net Acres

§2012 Activity:

§3 gross / net wells

§Current Activity:

§Spires 89-1H

§Cum. Prod (1 mos): 7.8 mboe

§86% oil; 9% NGLs

§Economics:

§D&C Cost: $1.8 MM

§EUR: 145 MBoe

§54% Oil / NGLs

AXAS owns 100% working interest in Spires Ranch leasehold

5,600 net acres

Nolan
County

Spires 89-1H

25

Permian Basin - Emerging Hz

Spires Ranch (Nolan County)

§Monitoring industry activity

§Geologic evaluation

§Logged shales through Spires 89 1H

Millican Reef (Coke County)

§Monitoring industry activity

§Geologic evaluation

26

Canada - Pekisko + Stealth Play

§Pekisko Gross / Net Acres:

§5,760 (100% WI)

§Pekisko :

§D&C Cost: $3.5 MM

§EUR: 150 MBoe

§6 wells on production

§Planned Activity:

§Continue to expand acreage position in
emerging shale play in central Alberta

§Post accumulation, actively market for
JV/sale as a commingled package

Tomahawk

Twining

Pekisko Trend

Alberta, Canada

?

Stealth Oil Play

Recently Drilled
Neighboring Well in
Stealth Oil Play

27

Near-Term Drilling Catalysts

(1)Significant downtime during 30 day IP month

(2)Restricted rate

28

NASDAQ: AXAS