Cairn Updates Operations Offshore Greenland

- Cairn Updates Operations Offshore Greenland

Tuesday, September 13, 2011
Cairn Energy plc

The following operational update relates to Cairn's exploration drilling campaign offshore Greenland.

Gamma-1 Well: Eqqua Block, West Disko Area

The Gamma-1 exploration well, drilled by the Ocean Rig Corcovado drillship, located in 1,520 meters (m) of water and 294 kilometers (km) from Aasiaat, in the Eqqua Block in the West Disko area has reached total depth (TD) and preparations are under way to plug and abandon the well. The well had been targeted to test a deep water Tertiary basin floor fan located 100km down dip from the T8-1 well where biogenic and thermogenic gas had been encountered in 2010.

The Gamma-1 well intersected the prognosed basin floor fan at the anticipated depth, although no reservoir or hydrocarbon shows were encountered in the interval.

Delta-1 Well: Napariaq Block, West Disko Area

The Delta-1 exploration well, drilled by the Leiv Eiriksson semisubmersible drilling rig, located in a water depth of 293m and approximately 365km offshore Aasiaat, in the Napariaq Block is currently drilling ahead. The Delta-1 well is aiming to intersect Cretaceous sediments in a large structural closure beneath the Tertiary volcanic interval in which oil shows were encountered in the Alpha-1 well drilled in 2010. The well has so far encountered several hundred meters of Tertiary volcanic section, which is thicker than anticipated and with only minor hydrocarbon indications. A further update will be made later this month, once the well reaches TD.

AT7-1 Well: Atammik Block, South Ungava Area

Following completion of the operations on the Delta-1 Well, the Leiv Eiriksson is scheduled to move south to re-enter the AT7-1 well in the Atammik block, located in 909m of water and 198km offshore Nuuk, and drill to the planned TD.

Fifth Well: AT2 Prospect: Atammik Block, South Ungava Area

Once operations on the Gamma-1 well are complete, the Ocean Rig Corcovado is scheduled to move 597km south, to the Atammik Block, to drill the AT2 prospect as a fifth well in the 2011 exploration drilling campaign.

Further updates will be provided whenever a well is at TD and operations are complete.

Simon Thomson, Chief Executive, said, "The full results of the Gamma-1 well and the update from the Delta-1 well will be reviewed in the context of all the data gathered during the Greenland exploration campaign.

The rigs are scheduled to move south to drill the final two wells of the program on the Atammik block. We remain focused on the potential of our multi-basin position in Greenland."

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Entek Updates Activities in Niobrara Shale Oil Proj.

- Entek Updates Activities in Niobrara Shale Oil Proj.

Thursday, September 01, 2011
Entek Energy Ltd.

Entek provided an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L – The Frontier (secondary objective) has been successfully fracture stimulated. Limited testing has been performed before completion and testing operations start on the lowest of the Niobrara Benches in the well. Test results suggest the discovery of an oil prone sweet-spot in the Frontier Formation which is part of the Mowry Shale Resource Play. The play has been a secondary target across the Company's acreage since it tested hydrocarbons at an initial rate of 1.2 MMCFD and 10 BOPD in the Focus Ranch 12-1 well and since has shown significant oil and gas shows in each well where penetrated across the acreage.

Test results suggest that the 14 ft perforated zone in the Battle Mountain 14-10 well will be capable of around 20 BOPD and over 100 MCFD. It is most likely that the production from the Frontier will be comingled with production from the Niobrara once planned completion and testing operations in the well are complete. In the future the Frontier, like the Niobrara, is likely to become a candidate for horizontal drilling. The Company will provide an update as the appraisal program continues on the potential of the Frontier and Mowry Shale Resource Play across its acreage position.

The completion program for the Niobrara (primary objective), which includes fracture stimulation and testing, will be initiated this week with fracture stimulation planned around September 15.

Slater Dome (SD) Federal 24-9DL – The well has successfully reached its total depth of 8,300 ft after penetrating both the Niobrara and Frontier Formations. The well had significant oil and gas shows while drilling and was prepared for logging, with good hole condition reported. While pulling out of hole to run wireline logs a drill string connection mechanically failed. Operations are continuing to remove the drill string from the hole prior to logging.

C&C Cattle 18-8 – Location preparation is complete. It is anticipated that the rig will be mobilized from the 24-9 location to the 18-8 location over the next week. An additional rig is on standby to mobilize to the 18-8 location if operations on the 24-9 well take longer than expected.

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Circle Oil Updates Ops at Geyad Field in Egypt

- Circle Oil Updates Ops at Geyad Field in Egypt

Wednesday, August 31, 2011
Circle Oil plc

Circle Oil announced the following update regarding the Geyad-5X water injection well drilled to support production in the Geyad Field.

Geyad-5X

Geyad-5X, located to the south-west of the field and downdip of the Geyad-1X ST discovery well in the Geyad Development Lease, was drilled to 7,350 ft MD in the Upper Rudeis. The main objective for this well was to appraise the Shagar and Rahmi sandstones of the Kareem Formation in a downdip location and to provide water injection to support oil production from the updip Geyad field wells. The Shagar sands were encountered with 15 ft MD of net reservoir, an average porosity of 14% and perforations made between 6,510 and 6,525 ft MD. The Rahmi sands were encountered with 15 ft MD of net reservoir, an average of 13% porosity and perforations made between 6,583 and 6,899 ft MD. As expected, below the field oil-water contact both sands were found to be water bearing. The well has been completed as an injector.

The rig has now been mobilized to drill the water injector well Al Ola-2, located on the south-eastern flank of the Al Amir SE field, downdip of the Al Ola-1X producer. The well is planned to appraise both the Shagar and Rahmi sands for injection in that location.

The NW Gemsa Concession, containing the Al Amir and Geyad Development Leases, covering an area of over 260 square kilometers, lies about 300 kilometers southeast of Cairo in a partially unexplored area of the Gulf of Suez Basin. The concession agreement includes the right of conversion to a production license of 20 years, plus extensions, in the event of commercial discoveries. The NW Gemsa Concession partners include: Vegas Oil and Gas (50% interest and operator); Circle Oil Plc (40% interest); and Sea Dragon Energy (10% interest).

Prof Chris Green, CEO, said, "I am pleased to report another successful result as the partnership's plans in NW Gemsa continue on schedule. The rig will now move to start drilling the Al Ola-2 injector well situated on the Al Amir SE field. The water injection program is part of the continuing plan to increase production rates for the medium and long term."

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Treaty Updates Belize Operations

- Treaty Updates Belize Operations

Tuesday, August 30, 2011
Treaty Energy Corporation

Treaty Energy Corporation, a growth-oriented energy company in the oil and gas industry, today reported on its continued progress on the Belize project.

Treaty Energy is pleased to provide the following updates on projects that the Company is working on in Belize.

1) The surface lease agreement has been signed in partnership with one of the largest landowners in Belize, which covers a significant percentage of the 200,000 acre land portion of the concession.

2) The environmental approval for drilling of the two initial wells has been signed by Mr. Martin Alegria, Director of the Belize Ministry of the Environment and on file.

3) The passage way through a stream/ditch has been completed and pictures have been posted to Treaty Energy's Website, Twitter and Facebook sites. Continue to look for company updates, news and pictures on these sites

4) A roadway has been cut and cleared to the first drilling site and the well pad prepared.

5) All equipment cleared customs after approximately three weeks of paperwork and relocated to a secure site until our permanent 10 acre compound is ready to accept the equipment and become our established staging location near the Town of Independence. This Compound will include staff lodging; in addition, all buildings are being constructed by local craftsman at a very reasonable rate.

6) Mr. Keon Garbutt, a Belizean citizen, has been hired as Project Manager of the drilling operations in Belize for Treaty Belize Energy, Ltd.

7) Brian Luczywo has been promoted to Treaty Belize Energy Vice President of Operations.

The following is an update from Mr. Luczywo as of August 24th.

The Treaty Belize Energy office in Placencia is up and operating. In addition; our recently hired personnel and support staff are doing an excellent job. We have been busy getting our office functional. The following work has been completed:

Selected an office location key to the planning, implementation and coordination of the details of our day to day operations in Placencia

General maintenance repairs and upgrades to facility. Furniture and accessories delivered and suitable for office personnel

Central Air Conditioning installed in office and conference room. Internet, local phone, fax, US phone all installed and operational

Regular expense reports, accounting, banking, and communications back to the United States has been established

All project expenses brought under administration by the Belize office

Excitement is building in the area and Treaty Belize Energy is experiencing an influx of job applicants. We are currently building a database of names from which we will examine and determine the best qualified persons to ask and join the Treaty Belize Workforce

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AWE Updates Activities in Perth Basin

- AWE Updates Activities in Perth Basin

Friday, August 26, 2011
AWE Ltd.

AWE advised that preparations have continued for the planned hydraulic stimulation activities in the onshore Perth Basin. Preparation works on the Woodada Deep-1 and Arrowsmith-2 wells have been completed, and the final preparatory workover activities on the Senecio-1 well are now under way.

As previously advised to ASX, these stimulation activities are planned to proceed in the September quarter, subject to the receipt of all regulatory approvals.

Currently, the Woodada Deep and Arrowsmith activities have been referred to the Western Australian Environmental Protection Agency and a decision is expected in September.

The forward program for operational activities will be dependent on the receipt of these final regulatory approvals and the availability of the stimulation equipment, which is currently located at Dongara, in the Perth Basin. Given the current delays in the receipt of these approvals, there is a risk the stimulation equipment may not be available to commence this work in the September quarter.

AWE will advise further on this timing and the progress towards the stimulations when further information is made available from the regulators.

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Max Petroleum Updates Activities in Kazakh Blocks

- Max Petroleum Updates Activities in Kazakh Blocks

Wednesday, August 24, 2011
Max Petroleum plc

Max Petroleum announced an operational update of its activities in the Blocks A&E License area in Kazakhstan.

Drilling Commences at Sagiz West Prospect

Drilling has commenced at the SAGW-1 exploration well on the Sagiz West prospect in Block E, which has estimated unrisked mean resource potential of 26 million barrels of oil ("mmbo") in a four-way, Triassic rim structure. Total depth of the well will be approximately 1,600 meters.

New Drilling Contract for Additional Shallow Rig

The Company has executed a drilling contract with PM Lucas for a ZJ-50 rig capable of drilling to 5,000 meters, to drill the ASK-2 exploration well in the Asanketken Field in Block E. The rig is on location and is expected to commence drilling operations before 31 August 2011. The ASK-2 well is designed to test the field's deep Triassic potential, as well as further evaluate potential reservoirs in the shallower Jurassic section found to be productive in the ASK-1 discovery well.

Status of Pre-salt Drilling on Emba B Prospect

The Company expects to commence drilling operations for the NUR-1 pre-salt exploration well in the Emba B Prospect on Block E in October 2011, based on the Company's latest discussions with the drilling contractor, Saipem. The deep rig is currently completing a well for another operator and is expected to begin mobilization to NUR-1 location by the end of the month.

Expanded Post-salt Prospect Inventory

The Company has matured two additional prospects into the post-salt inventory, including the Uytas North and Karasai South prospects, both of which are four-way, Triassic rim prospects on Block A. Uytas North has unrisked mean resource potential of 11 mmbo with a 38% geological chance of success ("COS"), while Karasai South has unrisked mean resource potential of 12 mmbo and a 34% COS.

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Sentry Updates Appraisal Work at AU Wells

- Sentry Updates Appraisal Work at AU Wells

Tuesday, August 09, 2011
Sentry Petroleum Ltd.

Sentry provided the following update on its drilling exploration and appraisal work on ATP 862 and ATP 864 in Queensland Australia.

Sentry Petroleum has now completed the drilling of two Coal Seam Gas wells on ATP 862. The wells, Talundilly_CSG1 and Albilbah_CSG1 reached depths of 1,430 feet and 1,555 feet, respectively. In Talundilly_CSG1, 833 feet of core were cut, out of which 51 feet of coal and carbonaceous rock were canistered for gas desorption in 21 samples. Gas desorption is still ongoing as gas was found in all the canistered core samples. The Company expects this process to be completed for the Talundilly_CSG1 during the coming week. The Company further advises that isotherms will be obtained on selected coal and shale samples.

In Albilbah_CSG1, 472 feet of core were cut, out of which 35 feet of gaseous coal and carbonaceous rock were sealed in 20 canisters for desorption measurement. In addition, the lower Winton Sandstones were found to contain free gas and 20 feet of these cores were also canistered and evolved gas is being measured. Once these measurements are completed during the coming weeks the cores will be sealed and sent to a laboratory for routine core analysis to measure porosity, permeability and residual fluid saturation. The wireline logs from the previously drilled Albilbah-1 also indicate the presence of gas in these sands over a 128 feet interval starting beneath the last coal.

The Company's coalbed gas content measurements are using the direct method which is the preferred method in coalbed methane and gas shale resource assessment. The direct method physically measures the volume of gas released over time from a core sample sealed into a desorption canister—termed the measured gas content. Adjustments are made to the measured gas content to account for gas lost prior to the core being placed in the desorption canister and for residual gas remaining in the core at the completion of the desorption period. The process of acquiring the measured gas content generally requires four to five weeks. Upon completion of the gas desorption results will be forwarded for independent certification.

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Entek Updates Ops in Niobrara Shale Oil Proj. Appraisal Program

- Entek Updates Ops in Niobrara Shale Oil Proj. Appraisal Program

Friday, August 05, 2011
Entek Energy Ltd.

Entek provided an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L

The well has reached its total depth of 7,500 ft. Wire-line logs have been run and the well has been successfully cased and cemented ready for completion.

Preliminary interpretation of wire-line logs and correlation to offset wells show that the Niobrara section in this well contains significant potential pay zones (benches), as expected. In addition the Frontier Sandstone exhibits hydrocarbon saturation and is also being considered as a pay zone for fracture stimulation and completion.

The fracture stimulation program is currently being designed with Halliburton and is expected to start in August 2011.

The rig has been released and is currently mobilizing to the next location as the completion and fracture stimulation program is being designed for the Battle Mountain 14-10L well. Entek holds a 55% interest in the Green River Basin Joint Venture (GRBJV) with Emerald Oil & Gas NL holding 45%. Entek is the Operator. The GRBJV now controls close to 80,000 gross acres, approximately 60,000 net acres, covering the Niobrara Shale Oil Play.

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La Cortez Updates Ops at Putumayo Block

- La Cortez Updates Ops at Putumayo Block

Thursday, August 04, 2011
La Cortez Energy Inc.

La Cortez provided the following operational update on the Company's Putumayo-4 block located in the Putumayo Basin in southwestern Colombia:

Putumayo-4 Block

Social Activity

As previously disclosed, at the end of November 2010, the local community consultation process was suspended pending appoint of a new contractor to act on behalf of the Ministry of Interior. During July 2011, consultations were reinitiated, and significant progress has been made in the northern part of the block with two communities consulted to date. One agreement is ready for signature by the community and Petroleos del Norte S.A. (PetroNorte), operator of the Block; a second agreement is under discussion, with final approval currently expected within a month. Community consultations in the southern part of the block are proceeding more slowly, and while the negotiations continue in earnest, it has been agreed to focus all initial seismic activity in the northern area of the block in order to fulfill the commitments to the ANH (Agencia Nacional de Hidrocarburos).

Operational Activity

Assuming completion of the community consultation process under the timeline indicated above, the near-term operational objective is to shoot 104.8 km of 2D seismic over the block during October 2011. The seismic acquisition is a contractual obligation of the parties under the terms of our agreement with the ANH. The results of the seismic acquisition program will allow PetroNorte and us to finalize the selection of the drilling location for the first exploration well to be drilled on the Putumayo-4 block.

Bid specification for the seismic acquisition is expected to be complete by the end of August 2011, awarded in September, and initiated in October 2011. We anticipate that we will have the seismic volume interpretation from the acquired seismic by early 2012. In addition, once the community consultations are finalized, we will commence work on the Environmental Impact Study, which is required to secure the environmental license. Subject to completion of permitting and civil works at the drill-site, we and PetroNorte anticipate spudding the exploratory well (which is a commitment obligation under the contract with the ANH) during the second quarter of 2012.

Andres Gutierrez, President and CEO of La Cortez, commented on the announcement, "We are very pleased to announce the community consultation process is underway once again, and eagerly anticipate the increased level of activity over the coming months. We remain very optimistic about the exploration potential of the Putumayo-4 block and are encouraged that our views are shared by others who have recently approached us regarding their potential interest in partnering with us on future exploration and development activity."

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Solo Oil Updates Ausable Field Operations

- Solo Oil Updates Ausable Field Operations

Monday, August 01, 2011
Solo Oil plc

Solo Oil announced further updates of operations at the Ausable Field in South Western Ontario operated by its Joint Venture partner Reef Resources Limited.

Further to the announcement of July 12, 2011, Reef has informed the Company that the Ausable#5 well has been tied-in to the Ausable central production facilities and has been producing oil at variable rates since July 22, 2011 by means of a beam pump. Reef has indicated that the produced oil continues to foam with the completion fluids and that as a result it has so far not been possible to establish a representative production rate. The fluids used to acidize and stimulate the well have yet to be fully recovered. Reef is exploring alternative pumping strategies and has indicated that they will report further on progress shortly.

Work on recovering the frack tool left in Ausable#2 during work in 2010 has been started and fishing tools are being run in hole to make the first of several planned cuts in the tubing in order to retrieve the equipment resting across the production zone. These operations are expected to take one to two weeks to conclude.

Neil Ritson, Solo's Executive Director, commented, "The presence of moveable oil is very encouraging and we are pleased with the progress being made to bring both wells on to sustained production. We will further update shareholders as soon as additional information becomes available."

Solo currently holds a 23.8% working interest in the Reef Ausable properties and an option to increase its interest to 38.1% through co-investing a further CDN$1.5 million, with Reef, in the development of the Ausable and adjacent assets.

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Cobalt to Abandon Angola Well, Updates GOM Ops

- Cobalt to Abandon Angola Well, Updates GOM Ops

Wednesday, July 27, 2011
Cobalt International Energy Inc.

Cobalt announced a net loss of $19.5 million, or $0.05 per basic and diluted share for the second quarter of 2011, compared to a net loss of $41.8 million, or $0.12 per basic and diluted share, for the second quarter of 2010.

Cash expenditures (excluding changes in working capital) for the quarter ended June 30, 2011 were approximately $22 million and about $33 million year-to-date. For the full year 2011, Cobalt expects to spend $325 to 400 million which includes the cash expenditures associated with Block 20 offshore Angola. The timing of expenditures in the second half depends primarily on when the Block 20 Production Sharing Agreement is signed and when Cobalt recommences Gulf of Mexico drilling activities.

Cash, cash equivalents and investments at the end of the second quarter were approximately $1.64 billion. This includes about $339 million designated for future operations held in escrow and collateralizing letters of credit, but excludes approximately $196 million in the TOTAL drilling fund for the Gulf of Mexico. Cobalt expects it is well-funded to execute on its planned exploration and appraisal program, including expenditures relating to Block 20 offshore Angola, through the end of 2013.

Operational Update

On April 15, 2011, Cobalt completed a registered underwritten offering of 35,650,000 shares of its common stock at a public offering price of $14.00 per share, resulting in proceeds of approximately $499 million before expenses.

On May 3, 2011, Cobalt announced that the national oil company of Angola, Sociedade Nacional de Combust•veis de Angola-Empresa Publica (Sonangol), had approved Cobalt's drilling plans for its two initial pre-salt exploratory wells, Bicuar #1 and Cameia #1, on Block 21 offshore Angola. Subsequent to the end of the second quarter, on July 19, 2011, Cobalt commenced its initial two well pre-salt exploratory drilling program on Block 21 offshore Angola by spudding the surface hole of the Bicuar #1 exploratory well. On July 20, 2011, after setting the 36" conductor casing and drilling approximately 210 meters of surface hole, Cobalt encountered an over pressured water sand resulting in a water flow with limited quantities of natural gas. No safety or environmental issues resulted from the incident. Cobalt is focused now on its abandonment procedures for the Bicuar #1 exploratory well surface location. Given the unique nature of encountering pressured water sands in Angolan waters, Cobalt has agreed with Sonangol that Cobalt will take its learnings from this incident and reexamine its shallow hazard analysis of proposed Cameia and Bicuar drilling locations before moving the drilling rig to Cameia or a different surface location on Bicuar.

With respect to Cobalt's U.S. Gulf of Mexico drilling program, Cobalt believes it has satisfied all of the remaining requirements of the Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) related to its North Platte #1 and Ligurian #2 applications for permit to drill (APD's), except for the submission of the U.S. Coast Guard Certificate of Compliance for the Ensco 8503 drilling rig, which cannot be obtained until the rig returns to the U.S. Gulf of Mexico. Cobalt does not anticipate any issues related to obtaining this routine U.S. Coast Guard certification and it expects that after its submission the BOEMRE will promptly issue the APD's for both the North Platte #1 and Ligurian #2 exploratory wells. Cobalt expects that the Ensco 8503 drilling rig will be returned to Cobalt in the U.S. Gulf of Mexico late in the third quarter of 2011. Upon its return, the submission of the U.S. Coast Guard Certificate of Compliance, and the issuance of the APD's for the North Platte #1 and Ligurian #2 exploratory wells, Cobalt plans to drill the Ligurian #2 exploratory well. After drilling the Ligurian #2 exploratory well, Cobalt plans to move the rig to the North Platte #1 well location to drill that prospect. Cobalt anticipates that each of the Ligurian #2 and North Platte #1 exploratory wells will take approximately six months to drill.

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AWE Updates 2P Reserves at Tui Area Oil Fields

- AWE Updates 2P Reserves at Tui Area Oil Fields

Monday, July 25, 2011
New Zealand O&G Ltd.

AWE, as Operator of the Tui Joint Venture, has advised that preliminary work completed on the Tui Area Oil Fields indicates that the gross initial developed 2P reserves recoverable from the existing four well development of the fields will be reduced from the previously reported 50.5 million barrels to between 40 and 42 million barrels. This would leave gross remaining developed 2P reserves as at June 30, 2011 of between 9 and 11 million barrels and would represent a reduction of between 1.1 to 1.3 million barrels net to NZOG. An independent review of the reserves estimate is being undertaken by RPS Energy Pty Ltd (RPS). The RPS review is anticipated by AWE to be completed in early August 2011. A finalized 2P reserves estimate will be advised after the Joint Venture and RPS review has been completed.

AWE's evaluation has also identified possible additional volumes of oil not accessed by the current production wells in the Tui fields. To recover this oil additional wells or side tracks of existing wells will be required. Further work is being progressed that may mature these opportunities into a firm project that would add back a portion of the reserves reduction.

The revised 2P reserves estimate indicates an economic cut‐off for production in the 2019 to 2020 period based on operating costs for the FPSO Umuroa, the oil price forecast at that time, and no future infill drilling or exploration drilling success.

Concurrently, reprocessing and reinterpretation of the Tui 3D seismic undertaken by AWE has identified exploration prospects adjacent to the Tui fields which are under ongoing evaluation.

Participating interests in the Tui Joint Venture are:

• AWE Limited (Operator) 42.5%
• Mitsui E&P Australia Pty Limited 35.0%
• Stewart Petroleum Co Limited (NZOG) 12.5%
• WM Petroleum Limited (PPP) 10.0%

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Quetzal Updates Ops in Colombia

- Quetzal Updates Ops in Colombia

Wednesday, July 20, 2011
Quetzal Energy Ltd.

Quetzal provided the following update on operations in Colombia

The long term production testing of Canaguay #1 is continuing with the well currently producing approximately 500 barrels of oil and 150 barrels of water. The optimal production rate for the Mirador reservoir and facilities will be determined by the results of the long term production test.

Quetzal has a 25% working interest and is acting as the operator of the Canaguaro block and the Canaguay #1 well.

Block 27

A follow-up 54 square kilometer 3D seismic acquisition program has been completed in the south eastern portion of the block, and is currently being interpreted. The Company has defined drilling locations on three separate Block 27 structures, based on the interpretation of 3D seismic. Potential follow-up development drilling locations have been identified on several of these structures. Interpretation of the 3D seismic is continuing and several additional geological features are being studied as potential drilling locations.

Lengthy delays in the issuing of block environmental permits continue to adversely effect the operations of both large and small oil companies in Colombia. Quetzal has waited approximately 8 months for the Block 27 environmental permit. It is anticipated that permit will be granted during the 3rd quarter of 2011. Construction of drilling locations is scheduled to begin as soon as the required environmental permit is received. A two to three well drilling program is planned to commence approximately one month after location construction begins. The wells have a planned depth of approximately 10,000 feet and will test prospective oil bearing intervals in the Carbonera, Mirador and Une Formations.

Quetzal has a 50% paying interest in the block and is acting as operator.

Block 21

An 83 square kilometer 3D seismic survey has been competed on Block 21 and is currently being interpreted. Several geological features are being studied as potential drilling locations. The Company plans to drill 2 wells during the 4th quarter of 2011 or the 1st quarter of 2012.

Quetzal has a 50% paying interest in the block and is acting as operator.

Block 36

The acquisition of 109 square kilometers of 3D seismic on Block 36 has been completed and is being processed. Drilling of one 15,000 foot well is scheduled for 2012.

Quetzal has a 20% paying interest in the block.

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Nautical Updates Kraken Discovery Size

- Nautical Updates Kraken Discovery Size

Monday, July 18, 2011
Nautical Petroleum

Nautical Petroleum plc is pleased to announce the results of an Independent Resource Opinion conducted by Gaffney, Cline & Associates (GCA) on the Kraken discovery located in North Sea Blocks 9/2b (Nautical 50%) and 9/1a (Nautical 100%).

GCA have reviewed data and the Company's reservoir simulation studies on the Main Sand Unit of the Heimdal III reservoir in order to provide an independent opinion on the Contingent Resources. The Heimdal III reservoir is the focus of the proposed first phase of development of Kraken and has been penetrated by the 9/02-1A, 9/02b-2, 9/02b-4 and 9/02b-4z wells.

GCA have also provided comment on the Contingent and Prospective Resources in the lower Heimdal I reservoir, which was penetrated by the 9/02b-2 well and extends westward into Block 9/1a. For the Heimdal I reservoir, GCA estimates a gross 1C, 2C and 3C Contingent Resources of 9MMstb, 11MMstb and 13MMstb respectively (Net to Nautical*: 4.5MMstb, 5.5MMstb, and 6.5MMstb). Additionally, GCA estimates gross Low (P90), Best (P50) and High (P10) unrisked Prospective Resources of 14MMstb, 48MMstb and 110MMstb respectively (Net to Nautical*: 9MMstb, 34MMstb and 88MMstb).

Commenting on this announcement Steve Jenkins, Chief Executive Officer of Nautical said:

"The independent review endorses Nautical's resource estimate for the main sand, the Heimdal III reservoir, and confirms Kraken as a material asset, with significant upside. The Heimdal I sand prospective resources represent further upside, and shall be evaluated by the 3D seismic data currently being acquired, to better define the areal extent of the reservoir.

"We now look forward to the results of the key 9/02b-5 appraisal well (spudded on 6 July 2011), which will gather further information about the Heimdall III reservoir and seeks to confirm a commercial flowrate in the core area of the field."

* Net to Nautical resource figures are as per the Company's calculation, based on the gross resources estimated by GCA.

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Crimson Updates Production Activity, Ups 2011 Capital Plans

- Crimson Updates Production Activity, Ups 2011 Capital Plans

Monday, July 18, 2011
Crimson Exploration Inc.

Crimson Exploration Inc. on Monday provided an operational update and announced an increase in its 2011 capital program.

In Liberty County, TX, the Catherine Henderson #B-4 (64.0% WI) commenced production at a gross daily rate of 1,379 Boepd, or 721 barrels of condensate, 208 barrels of natural gas liquids and 3.2 Mmcf of natural gas on a 13/64th choke and 7,000 psi of flowing tubing pressure. This well was drilled to a total measured depth of 15,338 feet in the Lower Cook Mountain formation. Approximately one mile to the northwest, Crimson has drilled the Catherine Henderson A-10 (66.0% WI), targeting the Cook Mountain formation, to a total measured depth of 13,742 feet. Completion operations are scheduled to begin by the end of July with first production in early August.

In Zavala County, TX, Crimson completed the KM Ranch #1H (50.0% WI), targeting the Eagle Ford Shale, and has commenced flow-back operations with results expected in mid-August. The well was drilled to a total measured depth of 12,627 feet, including a 5,800 foot lateral and 20 stages of fracture stimulation. The KM Ranch #1H represents Crimson’s first well in Zavala County where Crimson has an estimated 147 drilling locations and approximately 2,300 net acres held by production. Crimson anticipates spudding the KM Ranch #2H (50.0% WI) in the beginning of November subsequent to spudding its first well in the Booth-Tortuga Area, approximately 13 miles to the southwest of the KM #1H, in the beginning of October.

In Karnes County, Texas, Crimson spud the Littlepage McBride #2H (53.0% WI), targeting the Eagle Ford Shale formation, which is drilling at 8,480 feet toward an estimated total measured depth of 15,850 feet. Completion operations are expected to begin mid-third quarter with initial production to follow in September. The Littlepage McBride #2H is located approximately 0.6 miles to the east of the Littlepage McBride #1H well (53.0% WI) which is currently producing 525 Boepd and has produced a cumulative 53,000 Boe since coming online in early April. Due to the success experienced in Karnes County, we have planned a continuous drilling program for the remainder of the year, commencing a well per month beginning in August.

Updated 2011 Capital Program

Crimson’s Board of Directors recently approved increasing its 2011 capital budget to $78 million, a 30% increase, to accelerate oil weighted drilling activities in Zavala, Dimmit and Karnes Counties. This decision was made based on Crimson’s extensive portfolio of drill ready oil opportunities and recent success. The increase in capital expenditures marks the beginning of an Eagle Ford development program that represents a strategic shift to oil and liquids rich projects in proven areas. As a result, preliminary internal forecasts indicate Crimson’s production mix will be over 40% crude oil and natural gas liquids by January 2012 and over 50% crude oil and natural gas liquids by the second quarter of 2012.

Second Quarter 2011 Production

Crimson produced approximately 4.4 Bcfe of natural gas equivalents, or an estimated 48,740 Mcfe per day, during the second quarter 2011, compared with 2.7 Bcfe, or 30,084 Mcfe per day, produced during the second quarter of 2010, a 62% increase period over period. The second quarter production results were in line with management’s guidance.

Crimson Exploration is a Houston, TX-based independent energy company engaged in the acquisition, development, exploitation and production of crude oil and natural gas, primarily in the onshore Gulf Coast regions of the United States. The Company owns and operates conventional properties in Texas, Louisiana, Colorado and Mississippi, approximately 12,000 net acres in the Haynesville Shale, Mid-Bossier, and James Lime plays in San Augustine and Sabine counties in East Texas, approximately 6,700 net acres in the Eagle Ford play in South Texas and approximately 11,000 net acres in the Denver Julesburg Basin of Colorado.

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ConocoPhillips Updates Bohai Bay Cleanup

- ConocoPhillips Updates Bohai Bay Cleanup

Wednesday, July 13, 2011
ConocoPhillips

ConocoPhillips provided additional information in regards to the oil spill incidents that occurred in Bohai Bay, People's Republic of China on June 4th and June 17th 2011, and the ongoing clean up and containment program that is underway.

On June 4 seepage on the seabed was observed along a naturally occurring fault near the ConocoPhillips-operated Peng Lai B Platform. The majority of seepage has been stopped following prudent adjustment of certain production activities. A containment device was designed and constructed and put in place as a precaution should the seep occur from the main source again. Trace amounts of oil, estimated to be no more than liters per day, continue to seep out intermittently near the original seep location and occasionally cause minor surface sheens. Booms are deployed around the immediate surface area and are containing and collecting any such oil.

In a second incident, oil and gas bubbles were observed on the surface June 17 near another platform (C Platform) during drilling operations. The platform is about two miles away from the seabed seep near Platform B. Expert teams were immediately mobilized to contain the release. A cementing procedure successfully stopped the release within 48 hours, and the well was stabilized, plugged and abandoned. Trace amounts of bubbles are occasionally observed from the sea floor, and these bubbles continue to be monitored. Absorbent boom is in place in appropriate locations. Final clean up operations are ongoing.

ConocoPhillips responded quickly to both events and mobilized extensive clean-up equipment, facilities and personnel, including substantial resources made available by our co-venturer China National Offshore Oil Corporation ("CNOOC"). Relevant authorities were promptly notified, along with CNOOC. Almost 3,000 meters of absorbent and inflatable booms were deployed to contain the oil sheen, and 33 vessels (workboats, fishing boats and tugs) supported clean-up activities. ConocoPhillips is appreciative of the support provided by CNOOC during the containment and cleanup effort and to the State Oceanic Administration (“SOA”) for their guidance during these unfortunate events.

ConocoPhillips' current estimates of the aggregate amount of fluid spilled from the two incidents ranges from between 1,500 barrels (240 cubic meters) to 2,000 barrels (320 cubic meters) of oil and oil-based drilling fluids. The company is working with independent experts to validate the total spill quantity. During these incidents, no oil sheen reached the shoreline, and there were no injuries to personnel.

On July 13th, the SOA instructed ConocoPhillips to suspend production from Platforms B and C, and this order was complied with immediately. This shut in will result in a temporary reduction of approximately 17,000 barrels of oil per day net after royalties to ConocoPhillips. According to the SOA order, this temporary shut in will be in effect until the risks of another spill are eliminated. While the detailed causes of these incidents are still under investigation, ConocoPhillips will continue to work diligently and safely to finalize clean up activities and will be implementing additional reservoir management and field operating procedures to eliminate risks of additional releases.

ConocoPhillips will work closely with SOA and CNOOC to minimize the impact to the environment. Working safely and in an environmentally prudent manner is always the top priority to ConocoPhillips.

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Ithaca Updates North Sea Ops

- Ithaca Updates North Sea Ops

Monday, July 11, 2011
Ithaca Energy Inc.

Ithaca announced progress on Athena and Stella Development projects.

Athena Project - Completions Update

Operations to prepare the Athena field development well 14/18b-A2Z ("the well" or "A2") for production have been successfully concluded. A 7" production liner and a dual electrical submersible pump system have been successfully installed above the horizontal section of the well and the subsea xmas tree and flowbase are ready for hook-up of flowlines by the subsea installation contractor. The Sedco 704 drilling unit, will stay on location to undertake further completion work for the project and is currently preparing to complete 14/18b-16 (to be renamed 14/18b-A3 or "A3"). This is the second of a five well program of completions (four production and one water injection) to be carried out before hook-up to the Floating Production Storage and Offloading vessel, BW Athena.

Athena Joint Venture Partners are Ithaca (operator, 22.5%), Dyas UK Ltd (47.5%), EWE Aktiengesellschaft (20%) and Zeus Petroleum Limited (10%).

Stella Project - Subsea Trees and Control Systems Contract Awarded

The development of the Stella field has moved a step forward through the placement of a contract with GE Oil & Gas to manufacture and supply subsea trees and controls systems. The initial phase of detailed engineering work has commenced and will focus on the procurement of forgings and materials for the systems. The systems will be delivered as an integrated package and are designed for installation using a heavy duty jackup drilling unit. The supply of the trees and control systems will be managed and delivered from GE Oil & Gas's Aberdeen facility.

The Company also confirms that a geotechnical program is currently ongoing to determine the suitability of certain jackup drilling units at four potential development drilling locations on the Stella and Harrier fields and incorporating test boreholes in advance of the planned Hurricane appraisal well. Two drill centers will be selected.

Stella Joint Venture Partners are Ithaca (operator, 50.33%), Dyas UK Limited (31.67%), Challenger Minerals (North Sea) Limited (18%).

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Victoria O&G Updates Ops at West Medvezhye

- Victoria O&G Updates Ops at West Medvezhye

Thursday, July 07, 2011
Victoria O&G plc

Victoria O&G provided an update on its appraisal and delineation program in the West Medvezhye, (West Med) oil, gas and condensate license area in Russia.

West Med Regional Background

VOG's wholly owned subsidiary, ZAO SeverGas-Invest (SGI), holds a 20-year Exploitation License for West Med covering 1,224 km2. The block is located in the Yamal Peninsula in the Nenets region of Siberia and was independently assessed in 2006 by DeGolyer and MacNaughton (D&M) to have total prospective resources of approximately 1.1 billion barrels of oil equivalent (boe). West Med is located in one of the most prolific oil and gas producing areas of the world and is adjacent to Gazprom's giant Medvezhye field that has already produced over 70 trillion cubic feet of gas.

In total, D&M identified 25 leads and prospects and the Company's first discovery in West Med, Well 103, was based on a prospect defined by D&M. The discovery has C1 and C2 reserves, independently assessed, under the Russian classification convention of 14.4 million boe as approved by the Russian Ministry of Natural resources.

West Med Appraisal Update

While VOG's principal focus has been the development and commencement of gas and condensate production at Logbaba in Cameroon which is scheduled for 4Q 2011, SGI's technical team and consultants Blackwatch Petroleum Services (Blackwatch) have been utilizing this time to acquire data and to carry out integrated multi-discipline studies in West Med.

This work has involved integration of new data with previous seismic and well data to screen and firm up the prospects and leads identified by D&M.

Passive Seismic and Gas Tomography Surveys

New data acquired in 2010 included 155 passive seismic points recorded by GeoDynamics Research S.r.l. (GDR) and 289 km lines of gas tomography data recorded by Exotrad Limited. The surveys identified direct hydrocarbon indications in six areas covering a total of 79 km2 in the opinion of GDR and VOG.

Preliminary internal volumetric estimates by the Company, based on these passive seismic areas and regional well and seismic data for reservoir properties, indicate hydrocarbons initially in-place estimated at 400 mmboe by SGI and Blackwatch.

The features are all part of previously identified prospects by D&M, based on conventional seismic, and the volumes were incorporated into the overall assessment of 1.1 billion boe Un-risked Prospective Resource potential for the West Med Block.

Conventional Seismic work

Further to these positive results, in February 2011, the Company commissioned a seismic reprocessing and geological modelling study to be carried out by a Russian geoscience consulting institute, Mineral. The first phase of the technical work, which included reprocessing of 845 km of 2D seismic, was completed in June 2011.

Re-interpretation of the reprocessed seismic data has now commenced and will incorporate the passive seismic and gas tomography results. The results of Mineral's work are scheduled to be considered in a workshop in Tyumen, Russia in July 2011.

West Med Appraisal / Development Planning

In addition to the subsurface technical studies, development studies have commenced for commercialization of the large prospective resources and exploitation of the Well 103 discovery. These include but are not limited to the following:

Drilling & Well Engineering

Studies have commenced on well design and engineering for future appraisal and development well drilling planned for 4Q 2012. The company is in discussions with international and Russian service companies and has compiled initial budgetary estimates for the wells and drill pads.

These studies conclude that the wells may be drilled in clusters of 3 to 10 to significantly reduce location preparation and access cost. This will have a marked impact on development economics.

Surface Production Facilities & Infrastructure

Conceptual design work has commenced to establish costs and schedules for oil, gas and condensate production facilities and supporting infrastructure. The gathering and distribution network design and engineering will be phased with facilities design, starting with fast track development of the Well 103 discovery.

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Max Petroleum Updates Kazakh Ops

- Max Petroleum Updates Kazakh Ops

Monday, July 04, 2011
Max Petroleum plc

Max Petroleum announced an update of its operations in the Blocks A&E license area in the Republic of Kazakhstan.

Extension of Trial Production Project for Zhana Makat Field

The Kazakh government has approved an extension of the trial production project for the Zhana Makat field until 15 December 2011, while the Company seeks final regulatory approval to convert Zhana Makat to full field development ("FFD") status under its Blocks A&E exploration and production contract (the "Contract"). FFD approval will allow the Company to develop and produce the field for up to 25 years, as well as grant the Company a right to sell 80% of its crude oil production on the export market under the terms of the Contract.

Sales and Production Update

Following correspondence and recent discussions with local regulatory authorities, Max Petroleum will sell 100% of its crude oil production on the domestic market pending FFD approval, which is projected to be in place during the fourth quarter of 2011. Current oil sales into the domestic market are generating after-tax net proceeds that are approximately $15-$17 per barrel lower than comparable export sales. The Company does not anticipate any material adverse impact to its financial condition or its ability to implement its ongoing post-salt and pre-salt drilling programs as a result of selling domestically during this period.

The Company is currently producing approximately 2,200 barrels of oil per day ("bopd"), generating approximately $3.5 million in net proceeds per month from domestic oil sales. The Company expects daily production to increase to more than 3,000 bopd during the third quarter of 2011 as four additional wells are brought onto production, including the ZMA-ET1 and ZMA-ET2 wells recently drilled in Zhana Makat, the BOR-3 well in the Borkyldakty Field, and the ASK-1 well in the Asanketken Field.

Drilling Update

The BOR-3 appraisal well in the Borkyldakty Field has reached a total depth of 1,688 meters, with electric logs indicating 28 meters of net oil pay in five Triassic sandstone reservoirs at depths ranging between 1,366 and 1,556 meters. Reservoir quality appears excellent with porosities ranging from 18% to 25%. The Company is running production casing in the well, which will be completed using a workover rig and placed on production in July 2011 under the terms of the trial production project ("TPP") for the Borkyldakty Field.

Following BOR-3, the rig will move on to drill the KZIE-1 exploration well on the East Kyzylzhar 1 prospect followed by the SAG-1 exploration well on the Sagiz West prospect, both of which are located in Block E. A second shallow rig is on location at the Uytas Field and is expected to begin drilling the first of three appraisal wells in early July 2011. When the rig has finished drilling all three Uytas appraisal wells it will move on to drill the ZLGS-1 exploration well on the Zhalgyz South prospect in Block A.

The Company has tendered for a third shallow drilling rig to drill the ASK-2 well in the Asanketken Field to accelerate the drilling of Max Petroleum's shallow exploration, appraisal and development program. The Company expects to spud the ASK-2 well in mid-August 2011. Furthermore, the Company is on plan to begin drilling the pre-salt NUR-1 well in the Emba B prospect on Block E in the latter half of the third quarter of 2011.

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Global Petroleum Updates Jupiter Acquisition

- Global Petroleum Updates Jupiter Acquisition

Friday, July 01, 2011
Global Petroleum Ltd.

Global Petroleum advised that the Notice of Meeting whereby Global will seek shareholder approval for the acquisition of Jupiter Petroleum Limited ("Jupiter") has been finalized and submitted for regulatory review.

Under the sale and purchase agreement, Global will acquire Jupiter which holds prospective oil and gas exploration interests in offshore Namibia and in offshore Juan de Nova, a French dependency in the Mozambique Channel.

The sale and purchase agreement is conditional on the satisfaction of a number of conditions precedent, including due diligence investigations, obtaining necessary consents from governmental authorities, a report from an independent expert that the transaction is fair and reasonable to Global shareholders, and shareholder approval at a General Meeting.

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