8-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

February 10, 2014

Date of Report (Date of earliest event reported)

ABRAXAS PETROLEUM CORPORATION

(Exact name of registrant as specified in its charter)

Nevada	1-16071	74-2584033
(State or other jurisdiction of incorporation)	(Commission File Number)	(I.R.S. Employer Identification Number)

18803 Meisner Drive

San Antonio, Texas 78258

(210) 490-4788

(Address of principal executive offices and Registrant’s telephone number, including area code)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e- 4(c))

Item 7.01 Regulation FD Disclosure

On February 10, 2014, Abraxas issued a news release titled  “ Abraxas Provides Operational Update; Announces Upcoming Presentation”. The full text of the news release is attached as exhibit 99.1.

Abraxas President and CEO, Bob Watson, will be presenting at the Oil and Gas Investment Symposium in Fort Lauderdale, FL on Wednesday February 12, 2014. Attached as Exhibit 99.2 are the materials that Mr. Watson will be presenting.

The information in this Report (including Exhibit 99.1) is furnished pursuant to Item 7.01 and shall not be deemed "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of the Section. The information in this Report will not be deemed an admission as to the materiality of any information required to be disclosed solely to satisfy the requirements of Regulation FD.

Item 9.01 Financial Statements and Exhibits.

(d)           Exhibits.

99.1 News Release

99.2  Slide Presentation

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

ABRAXAS PETROLEUM CORPORATION

By:   /s/ Geoffrey R. King                                                                

Geoffrey R. King

Vice President, Chief Financial Officer

Dated: February 10, 2014

EX-99.1

Exhibit 99.1

NEWS RELEASE

Abraxas Provides Operational Update; Announces Upcoming Presentation

SAN ANTONIO (February 10, 2014) – Abraxas Petroleum Corporation (NASDAQ:AXAS) is pleased to provide the following operational update.

Eagle Ford

At Abraxas’ Jourdanton prospect, in Atascosa County, Texas, the Blue Eyes 1H averaged 405 boepd (383 barrels of oil per day, 134 mcf of natural gas per day) over the well’s first 30 full days of production(1).  On the back of the Blue Eyes 1H success, the company leased an incremental 1,500 net acres on trend with the well.  Total acreage at Jourdanton now consists of approximately 5,700 net acres.   Abraxas also recently spud the Snake Eyes 1H, which is the first of four consecutive wells to be drilled on the Jourdanton prospect in 2014.  Additional wells scheduled to be drilled in 2014 include the Spanish Eyes 1H, Eagle Eyes 1H and Ribeye 1H.   Abraxas owns a 100% working interest across the Jourdanton prospect.

At Abraxas’ Cave prospect, in McMullen County, Texas, the company is currently completing the Dutch 2H with a 36 stage stimulation.   After drill out, the well will be placed on production and a thirty day rate will be provided when available.   Abraxas holds a 100% working interest in the Dutch 2H.

At Abraxas’ Dilworth East prospect, in McMullen County, Texas, the company recently drilled and cased the R. Henry 2H to 16,555 feet.   The well is scheduled to be fracture stimulated in early March.   Abraxas holds a 100% working interest in the R. Henry 2H.

Williston Basin

In McKenzie County, North Dakota, the company successfully drilled and cased the Jore 1H, 2H and 4H.   The three Jore wells are now scheduled to be fraced in March, weather permitting.   Raven Rig #1 recently mobilized to the Ravin West pad to drill four wells.   Abraxas owns a working interest of approximately 76% and 51% in the Jore and Ravin West pads, respectively.

Upcoming Presentation

Bob Watson, President and CEO of Abraxas will be presenting at IPAA OGIS Florida on Wednesday, February 12, 2013 at 10:15 AM ET.   A live webcast of this event can be accessed under the Investor Relations section of the Abraxas Petroleum website at www.abraxaspetroleum.com and at http://www.investorcalendar.com/CEPage.asp?ID=172112.

Bob Watson, President and CEO of Abraxas commented, “We could not be more excited with the results of the Blue Eyes 1H and what it implies for the potential on our now approximately 5,700 net acre position at Jourdanton.   Furthermore, we have been quite pleased with the well’s performance subsequent to its initial 30 day period.  The shallower depth of the wells should also lead to meaningfully lower well costs compared to our recent McMullen County Eagle Ford wells.   Currently, we have four additional wells planned at Jourdanton in 2014.

The first quarter of 2014 promises to be catalyst rich for Abraxas with numerous high impact and high working interest wells on the horizon in the Eagle Ford and Bakken.   Notably, our long lateral (9,000 foot) Dutch 2H should be turned over to production shortly.   We also look forward to updating the market with the results of the Henry 2H and three Jore completions in the near future.”

(1)   The production rates for each well do not include the impact of natural gas liquids and shrinkage at the processing plant and include flared gas.

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 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:

Geoffrey King/Vice President – Chief Financial Officer

Telephone 210.490.4788

gking@abraxaspetroleum.com

www.abraxaspetroleum.com

EX-99.2

Abraxas Petroleum Corporate Update February 2014 Exhibit 99.2

* 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. Forward-Looking Statements

* I. Abraxas Petroleum Overview

* Headquarters.......................... San Antonio Employees............................... 109 Shares outstanding(1)……......... 93.5 mm Market cap(3) …………………….... $296 mm Total debt (cash)(2)………………. $38 mm PV-10(7)……………………………….. $240 mm Fully diluted shares outstanding as of September 30, 2013. Total debt including RBL facility, rig loan and building mortgage less cash. As of 12/31/13. Share price as of January 31, 2013. Enterprise value includes working capital deficit as of September 30, 2013, but does not include building mortgage or rig loan. Includes RBL debt as of December 31, 2013. Mid-point of 2013 yearly average production guidance. Calculation using midpoint of 2013 yearly average production guidance and net proved reserves as of June 30, 2013 pro forma for WyCross divestiture. Net proved reserves as of June 30, 2013 pro forma for WyCross divestiture. Uses SEC TTM average pricing of $92.79/bbl and $3.50/mcf. EV/BOE(2,3,4)………………………... $17.15 Proved Reserves(7).…………..... 21.1 mmboe % Oil/Liquids……………… ~61% % Proved developed….. ~61% Production(5).……………………… 4,325 boepd R/P Ratio(6)…………………………. 13.4x 2014E CAPEX………………………. $105mm NASDAQ: AXAS Corporate Profile

* Exposure to "core" acreage in top U.S. oil resource plays Targeted acreage acquisitions in geologically controlled areas of core basins Premier Position Value + Growth Low decline legacy production provides solid foundation Disciplined, ROR focused development model = visible/repeatable growth Oil Weighted 67% crude oil and liquids weighted by production(1) 100% of 2014E capital directed towards Eagle Ford and Bakken Financially Sound Under 1.0x debt/EBITDA (2) High margin, long lived crude oil weighted production base = strong cash flow On production basis as of 9/30/13. As of 12/31/13, excluding building mortgage and rig loan which are secured by the building and rig, respectively. EBITDA definition per bank loan agreement (excludes Rig EBITDA) Experienced Leadership Senior management with 33 average years of industry experience Deep technical and geological/geophysical staff Abraxas Highlights

* Proved Reserves(1) – 21.1 mmboe Production(2) – 4,781 boepd Reserve Mix(1) Revenue By Production Stream Reserve / Production Summary High-quality, Long-Lived, Oil Weighted Assets Net proved reserves as of June 30, 2013 pro forma for WyCross divestiture. Daily net production for the quarter ended September 30, 2013

* (1) Assumes midpoint of AXAS 4Q13E production guidance of 4,300-4,350 boepd. (Boepd) Oil/NGL % 51% 52% 52% 54% 58% 60% 67% 68% Production Net to AXAS 51% Liquids Growth 1Q12-4Q13E Refocusing on Oil and Liquids

* Abraxas Hedging Profile On March 19, 2013 Abraxas entered Brent vs WTI spread to better reflect actual realized pricing for the company’s Eagle Ford volumes. The weighted average price for WTI was calculated by taking out the exact volumes of the Brent hedge, starting with the highest price WTI swaps.  PDP volumes per June 30, 2013 reserve report adjusted for asset sales (non op Bakken, WyCross).

* Williston: Bakken / Three Forks Powder River Basin: Turner Midland/Eastern Shelf: Conventional & Emerging Oil Eagle Ford Shale Delaware Basin: Montoya/Devonian/Miss Gas, Shallow Oil, Emerging Hz Oil Proved Reserves (mmboe)(1): 21.1 Proved Developed(1): 61% Liquids(1): 61% Abraxas Petroleum Corporation Core Regions Net proved reserves as of June 30, 2013 pro forma for WyCross divestitutre.

* II. Strategic Plan

* Strategic Plan – 2014+ Excluding building mortgage and rig loan which are secured by the building and rig, respectively. EBITDA definition per bank loan agreement (excludes Rig EBITDA)

* OGJ150 Quarterly. Includes companies whose accounting methods vary. Excludes companies whose results were inflated by identifiable extraordinary gains. Excludes royalty trusts. Other companies include: Prime Energy Corp, Comstock Resources, EPL Oil & Gas, American Eagle Energy Corp., Dorchester Minerals L.P., Continental Resources, Inc., Linn Energy LLC, Chaparral Energy Inc., Reserve Petroleum Co. Outcome of ROR Focused Strategy Abraxas is committed to focusing on full cycle ROR development drilling in its core basins. The results of this focus, in addition to an active 2013 divestiture campaign which removed numerous low margin, high LOE barrels from the production base, continue to be reflected in the company’s financial statements. According to the November 2013 Oil and Gas Financial Journal, Abraxas ranked first amongst all exploration and production companies on an ROE basis for the quarter end June 30, 2013.

* III. Asset Base Overview

* Bakken / Three Forks Positioned in Core Areas North Fork 4,935 Net Acres North Fork Area McKenzie County, ND Lillibridge Area McKenzie County, ND South Elm Coulee Area Richland County, MT Lillibridge South Elm Coulee

* North Fork 5 completed wells 3 wells waiting on completion 4 wells drilling 13 wells to drill 193 boepd net (1) Pershing Field (Lillibridge) 8 new completions East & West pad: on production 1 well to drill 1,414 boepd net (1) Bakken / Three Forks Positioned in a Core Area (North Fork) Average production net to Abraxas for the month of December 2013

* Well Objective Lat. Length Stages 30-day IP (boepd) (1) Status Ravin 26-35 1H Three Forks 10,000 23 391 Producing Stenehjem 27-34 1H Middle Bakken 6,000 17 688 Producing Jore Federal 2-11 3H Three Forks 10,000 35 510 Producing Ravin 26-35 2H Middle Bakken 10,000 16 421 Producing Ravin 26-35 3H Middle Bakken 10,000 26 627 Producing Lillibridge 4H Three Forks 8,472 26 922 Producing Lillibridge 3H Middle Bakken 10,000 33 1,291 Producing Lillibridge 2H Three Forks 9,529 30 958 Producing Lillibridge 1H Middle Bakken 10,000 33 1,275 Producing Lillibridge 8H Three Forks 10,000 33 1,020 Producing Lillibridge 7H Middle Bakken 10,000 34 1,005 Producing Lillibridge 6H Three Forks 10,000 33 921 Producing Lillibridge 5H Middle Bakken 10,000 33 1,049 Producing Jore Federal 2-11 1H Three Forks 10,000 NA NA Waiting on completion Jore Federal 2-11 2H Middle Bakken 10,000 NA NA Waiting on completion Jore Federal 2-11 4H Three Forks 10,000 NA NA Waiting on completion Ravin 8H Three Forks 10,000 NA NA Permitted Ravin 7H Middle Bakken 10,000 NA NA Permitted Ravin 6H Three Forks 10,000 NA NA Permitted Ravin 5H Middle Bakken 10,000 NA NA Permitted Bakken / Three Forks Focused on Execution The production rates for each well do not include the impact of natural gas liquids and shrinkage at the processing plant and include flared gas.

* Lillibridge Qi’s (30 days) Pete/Nancy Updating BOOKED BOOKED BOOKED ACTUAL ACTUAL ACTUAL Well # Oil Gas BOE Oil Gas BOE #1 13,500 13,500 15,750 31,000 42,500 38,000 #2 13,500 13,500 15,750 24,400 32,000 29,700 #3 13,500 13,500 15,750 32,200 47,000 40,000 #4 13,500 13,500 15,750 18,000 27,000 22,500 #5 13,500 13,500 15,750 25,400 34,300 31,100 #6 13,500 13,500 15,750 21,700 28,500 26,500 #7 13,500 13,500 15,750 25,000 30,100 30,000 #8 13,500 13,500 15,750 25,800 26,600 30,200

* Bakken / Three Forks Outperforming Type Curve (NorthFork)

* Abraxas’ Eagle Ford Properties ~8,500 Net Acres Jourdanton Area Atascosa County Black oil Cave Area McMullen County Black oil Dilworth East Area McMullen County Oil/condensate Yoakum Area (not shown) Dewitt and Lavaca County Dry gas Jourdanton Area Cave Area Dilworth East Area

* Eagle Ford Jourdanton Jourdanton 5,700 acre lease block, 100% WI 50 well potential Blue Eyes 1H 30 day IP 405 boepd (1) Now on sub-pump 2014 Activity Four wells planned Snake Eyes 1H drilling Spanish Eyes 1H permitted Austin Chalk and Buda also prospective Abraxas Grass Farm #1H 1st Prod: 9-1-11 Abraxas Blue Eyes #1H Cinco Area Recent Activity Hunt Area Recent Activity EOG Area Recent Activity The production rates for each well do not include the impact of natural gas liquids and shrinkage at the processing plant and include flared gas.

* Eagle Ford Cave Cave 410 acre lease block, 100% WI First well completing 4 potential locations (red) 9,000’+ lateral length Offset operators include Chesapeake, EOG and Marathon Best month cumulative oil shown in green Range 14-23 mbo

* Eagle Ford Dilworth East Dilworth East 440 acre lease block, 100% WI First well waiting on completion 4 potential locations (red) 5,000’+ lateral length Best month cumulative oil shown in green Range 9-22 mbo

* Well Area Lat. Length Stages 30-day IP (boepd) (1) Status Blue Eyes 1H Jourdanton 5,000 22 405 Producing Snake Eyes 1H Jourdanton 5,000 NA NA Drilling Spanish Eyes 1H Jourdanton 5,000 NA NA Permitted Eagle Ford Focused on Execution Well Area Lat. Length Stages 30-day IP (boepd) (1) Status Dutch 2H Cave 9,000 36 NA Completing Well Area Lat. Length Stages 30-day IP (boepd) (1) Status R Henry 2H Dilworth East 5,000 25 NA Waiting on completion Jourdanton Cave Dilworth East The production rates for each well do not include the impact of natural gas liquids and shrinkage at the processing plant and include flared gas.

* Edwards (South Texas) PDP: 7.8 bcfe (net) Keuster 1H: 10.5 bcfe gross Previous risked offsetting PUD locations: 27.9 bcfe (net) 11 gross / 7 net locations dropped to PRUD (SEC 5 year rule) 7 gross / 5 net locations drilled / completed, yet to be frac’d: unbooked Edwards economics New drill: $7.0 million well / 4.0 bcfe EUR / F&D $1.73/mcfe 20% ROR at $4.30/mcfe realized price Refrac: $0.7 million well / 0.5 bcfe EUR / F&D $1.40/mcfe 20% ROR at $1.98/mcfe realized price Montoya / Devonian (Delaware Basin, West Texas) PDP 28.0 bcfe (net) Caprito 98 98 01U Devonian: 39.0 bcfe gross Howe GU 5 1 Devonian: 31.7 bcfe gross Previous risked offsetting PUD locations: 29.7 bcfe (net) 12 gross/ 6 net locations dropped to PRUD (SEC 5 year rule) Montoya economics $5.0 million well / 6.6 bcfe EUR / F&D $.75/mcfe 20% ROR at $3.16/mcfe realized price Devonian economics $5.8 million well / 7.6 bcfe EUR / F&D $0.76/mcfe 20% ROR at $2.51/mcfe realized price Other Eagle Ford Shale, Yoakum: 1,908 net acres / ~24 net locations, unbooked PRB, Turner (~50% gas): 2 gross (1.7 net) PUD / 50 gross (13 net) PRUD locations, 40.6 bcfe (net) Delaware Basin, Hudgins Ranch: 3 gross / 2.6 net PSUD locations, 9.1 bcfe (net) Delaware Basin, Nine Mile Draw: 40 gross / 31 net PSUD locations, 18.0 bcfe (net) Williston Basin, Red River: 1 gross / .8 net PRUD location, 2.1 bcfe (net) Net of purchase price adjustments PV10 calculated using strip pricing as of 5/1/12 = $2.29 2012 Ward County Acquisition Acquisition of Partners’ Interests in West Texas Purchase Price $6.7mm(1) PDP PV -15 $6.7mm(2) Production 1,440 mcfepd Reserves 7.613 bcfe Production $4,650/mcfe/day Reserves: $.88/mcfe Abraxas’ “Hidden” Gas Portfolio

* Additional Assets Average net production for the month ending November 2013. As of 12/31/2013

* Additional Assets As of 12/31/2013 Tax assessment of AXAS surface ownership in 162 acres Coke, TX; 613 acres and offices in Scurry, TX. Purchase price of AXAS 1,769 acres and offices in San Patricio, TX; 12,178 acres Pecos, TX; 582 acres and condos in McKenzie, ND; 50 acres DeWitt, TX.

* Catalyst Rich First Quarter Upcoming Catalysts on High Working Interest Wells

* Appendix

* Powder River Basin Turner Sandstone Horizontal Play Powder River Basin: Turner Sandstone Isopach of Turner thickness Multiple producing vertical wells, tight sandstone Horizontal exploitation with multi-stage fracs recently AXAS – 21,733 net acres (not all on map)

* Powder River Basin Campbell & Converse Co., WY Powder River Basin: Turner Sandstone Porcupine Field 26/9 gross/net wells Hedgehog State 16-2H Cum Production (1): 193 mboe Gross/net: 55/47 mbo Gross/net: 825/697 mmcf Current Production (2) 56 bopd, 808 mcfpd, 46 bpd 28 EOG Turner wells Average production per well per month 6.6 mbo, 63 mmcf Hedgehog 16-2H Production Cum production estimated through 12/31/13. Monthly average as of 11/30/2013.

* Portilla Field San Patricio County, TX Portilla Field Annual Capex of $1 million to maintain flat decline rate Numerous infill and work over opportunities 100% WI ownership Abraxas owns 1,769 surface acres Ideal CO2 candidate, 10% additional recovery = 8 mmbo Cum Production (1) ~80 mmbo + ~92 bcf Gross from Frio sands Current Production (2) 169 boepd Net 100% Surface Ownership Cum production estimated through 11/30/13. Monthly average as of 11/30/2013.

* Permian Basin Spires Ranch SHERIDAN 81 SW NENA LUCIA UNIT SHERIDAN 905 SW NENA LUCIA UNIT Example of Abraxas Horizontal Strawn Well NW SE Nena Lucia Field: Discovered in 1955 Reef build-up currently on waterflood Cum production (1) ~38.7 mmbo Gross ~114.7 bcf Gross Abraxas’ Spires Ranch: Acreage located West of Nena Lucia Horizontal wells targeting algal mounds that developed in front of the main reef Modified from Toomey and Winland (1973) Nena Lucia LUCIA NENA COKE COUNTY, TX Cum production estimated through 11/30/13.

* Millican Reef & NE Millican: Targeting Gunsight and King sand Additional exploratory opportunities Cum Production (1) ~1 mmbo Current Production (2) 33 boepd net DEVON Price C #1H Recent Cline Shale Completion Millican Reef NE Millican Permian Basin Millican Reef Cum production estimated through 11/30/13. Monthly average as of 11/30/2013.

* Abraxas Cherry Canyon Field: 30 Active Wells, three zones Waterflood potential 27 active wells Eight Proposed Injection Wells Horizontal potential Cum production (1) ~5 mmboe Gross Current production (2) 171 boepd Net Permian Basin Bell, Cherry and Brushy Canyon Production Cum production estimated through 11/30/13. Monthly average as of 11/30/2013.

* Howe Deep: One active Montoya well Five active Devonian wells Cum production (1) ~62 bcf Gross Current production (2) 1,373 mcfepd Net Horizontal Wolfcamp Potential Permian Basin Howe Deep Cum production estimated through 11/30/13. Monthly average as of 11/30/2013.

* R.O.C. Deep: Six active Montoya wells Four active Devonian wells One active Ellenburger well Cum production (1) ~138 bcf Gross Current production (2) 1,429 mcfepd Net Permian Basin R.O.C. Deep Cum production estimated through 11/30/13. Monthly average as of 11/30/2013.

* NASDAQ: AXAS