Surge Issues Update on Valhalla South Ops

- Surge Issues Update on Valhalla South Ops

Monday, September 12, 2011
Surge Energy Inc.

Surge Energy Inc. on Monday provided the results of its fifth horizontal multi-frac well at Valhalla South, and to announce that it has confirmed its bank line at $150 million.

Operations Update:

Surge provided the following operations update with respect to its Valhalla property due to drilling results which are believed to be material.

Surge's fifth horizontal well (16-7-74-8W6M; 100 percent working interest "WI") in the Valhalla South Doig light oil pool (40 degree API) has been successfully drilled and completed. The well encountered approximately 820 meters of Doig Formation and was completed with nine frac stages averaging approximately 30 Tonnes of proppant per frac. A five day flow test on the well has been recently completed, resulting in flow rates averaging 1,992 boe per day (78 percent light oil and NGLs) with the last day of the test flowing at a rate of 1,866 boe per day (72 percent light oil and NGLs). The well produced through the 114.3mm (4.5") tie back liner.

This five day rate for 16-7, is comparable to that of Surge's previously announced horizontal multi-frac well at 11-18-074-08W6 (71 percent WI), which had a five day flow test rate of 1,979 boe per day (82 percent light oil and NGLs) with the last day of testing flowing at a rate of 1,903 boe per day (77 percent light oil and NGLs). The 11-18 well averaged approximately 1,180 boe per day (72 percent light oil and NGLs) for the first 30 producing days which is well above the Company's type curve for the area (675 boe per day), and it was producing approximately 870 boe per day (73 percent light oil and NGLs) on September 1, 2011 when it was last tested. The first month average production rate for Surge's 16-7 well is expected to be in line with results from 11-18.

Surge began drilling its sixth horizontal multi-frac well into the pool (8-31-073-08W6; 100 percent WI) during August 2011 with plans of having production on stream in the fourth quarter of 2011. The Company has one more horizontal multi-frac well (11-5-074-08W6; 100 percent WI) budgeted for the remainder of 2011 for a total of seven gross horizontal multi-frac wells budgeted for 2011.

In addition to operations at Valhalla South, Surge is actively drilling in each of its other core areas at Windfall, Waskada and South East Alberta. At Windfall, the Company has recently drilled and completed its sixth horizontal multi-frac well and is currently drilling its seventh well into the Bluesky light oil pool (36 degree API). At Waskada, Surge has commenced its nine horizontal multi-frac well drilling program targeting the Spearfish light oil Formation (36 degree API) and now has three wells drilled and cased. In South East Alberta, the Company continues to exploit its low cost, low decline, high rate of return crude oil assets via infill drilling and waterflood. Surge will drill a combination of vertical and horizontal wells in the area during the third and fourth quarters of 2011.

Increase in Bank Line:

Surge has recently confirmed the Company's bank line at $150 million, up from $120 million. The increase is subject to standard legal documentation which is in the process of being finalized.

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Dart Commences Drilling Ops at China Daijing Proj.

- Dart Commences Drilling Ops at China Daijing Proj.

Thursday, September 08, 2011
Dart Energy Ltd.

Dart Energy has commenced drilling activities at the Dajing project in Xinjiang Province, China, with the spudding of the first two exploration wells (DJD-02E and DJD-10E). This is part of an initial exploration program which will see a total of up to 14 exploration wells drilled prior to year end, and assuming no program delays, Dart would expect first core drilling results to be available in the first quarter of 2012.

This follows approval in August of the 2011 exploration program and budget by the Dajing Joint Management Committee (JMC). The JMC is comprised of representatives of both Dart and its partner at Dajing, China National Petroleum Corporation (CNPC).

In addition to the spudding of the first wells, the following other activities have been completed at the Dajing project:

• 4 drilling rigs have been mobilized to site
• 3 on-site desorption units and 2 permeability testing units have been mobilized to site
• 3 work camps established on-site
• Site and road construction for 2 other exploration wells has been completed (DJD-O1E; DJD-O4E), with those wells expected to be spud within the next week

Nick Davies, Dart Executive Chairman, said, "We are now operationally underway at Dajing, which is a major milestone for Dart. Dajing has the potential to be a project of substantial scale within the Dart global portfolio, and our attention is completely focussed on executing the exploration drilling campaign diligently, quickly and safely. Dart Energy looks forward to working collaboratively with our partner, CNPC, to unlock the potential of this block."

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Oilex Notes Progress in Cambay Clean-Up Ops

- Oilex Notes Progress in Cambay Clean-Up Ops

Wednesday, September 07, 2011
Oilex Ltd.

Oilex advised that operations to prepare for well clean-up flow and production testing are continuing. Operations to retrieve down hole equipment, open up the remaining fracture stimulation stages and install production tubing will be conducted with a workover rig. Given the likely duration of this phase of the operations will be a few weeks, Oilex will provide the next update on operations when progress has been made.

The Cambay-76H "proof of concept" horizontal well is evaluating the production potential of the Y Zone interval of the extensive deep Eocene "tight" reservoirs in the onshore Cambay Production Sharing Contract area, Gujarat, India.

• Report date: September 6, 2011
• Status Preparations for well clean-up flow and production testing
• Past Week's Operations
  • Sourcing rig and equipment for the planned operation to retrieve tools in well
  • Successfully completed chemical cutting of coil tubing in hole
  • Demobilized surplus equipment, personnel and services.
• Objective: Cambay Eocene "tight" reservoir Y Zone
• Total Depth: 2,740 meters including 610 meters horizontal section

The participating interests in the Cambay PSC are:

• Oilex Ltd (Operator) 30%
• Oilex NL Holdings (India) Limited 15%
• Gujarat State Petroleum Corporation Ltd 55%

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Flexlife Expands Ops across South America

- Flexlife Expands Ops across South America

Tuesday, September 06, 2011
Flexlife

Flexlife has expanded its operations in Brazil to increase its capacity across South America.

The company is targeting initial revenue of approximately £4million per year, but that is expected to ramp up by 30-60% per year within two years.

As well as investing in new office accommodation in Rio de Janeiro at Rua Assembleia, Flexlife is manufacturing its ground-breaking integrity management products locally and offering a full assembly, deployment and maintenance service by staff based in the region.

The company has a suite of game-changing products to identify breaches in flexible pipes and repair them without interruption to production, a first in the 40 year history of the Oil & Gas industry.

Flexlife Chief Executive Stuart Mitchell said, "Flexlife is experiencing a period of significant growth and our new South American operation will expand our capability to offer specialised support to clients.

"Flexlife has continued to build on its reputation for offering a full subsea integrity and project management package, assisting clients to cost-effectively manage all of their subsea assets and infrastructure. We have built up high levels of expertise in deepwater markets and have a proven track record of providing a service that helps operators reduce risk in a cost-effective manner."

Leonardo Dias, Executive Manager Brazil, said, "Our aim is to establish ourselves in Brazil and also target work in Venezuela. We have recruited a team of engineering, technical and support staff who are all highly experienced in the Brazilian Oil & Gas market."

As part of a continuing global growth strategy Flexlife recently appointed Stephen Burgdorf as Vice President of Business Development for North America.

Based in Houston, Texas, he will focus on promoting Flexlife's award-winning offshore project and integrity management services to operators in the region.

A Newcastle base has also been opened in the last few months and the plans are in place to open an additional base in Angola.

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Frontera Commences Drilling Ops at Georgia Field

- Frontera Commences Drilling Ops at Georgia Field

Tuesday, September 06, 2011
Frontera Resources Corp.

Frontera announced commencement of new drilling operations at the Mtsare Khevi Field within its Shallow Fields Production Unit, Block 12, in the country of Georgia.

Site preparation and mobilization of drilling equipment were completed in late August and drilling is currently underway at the Mtsare Khevi #31 development well location. The #31 well is the first of a planned twenty well program over the next twenty four months designed to exploit multiple Upper Pliocene sandstone reservoirs situated at a depth of approximately 300 meters. In addition, efforts are underway to implement a pump optimization program designed to enhance production from existing oil wells within the field. Planning is also progressing related to a previously disclosed infrastructure project designed to initiate gas sales from currently shut-in gas wells within the field.

The Mtsare Khevi Field, which Frontera operates with 100% interest, is located in the western portion of the Shallow Fields Production Unit and currently delivers approximately 90 barrels of oil per day from its shallow reservoirs. Twenty new well locations have been identified for ongoing low-cost drilling, targeting both oil and gas reservoirs and providing for reservoir pressure support through three proposed water injection wells.

The independent engineering firm of Netherland, Sewell & Associates "NSA" places a "Best Estimate" for gross original oil-in-place for the Mtsare Khevi Field of 14.9 million barrels, with a "low"-to-"high" range of 11.3-19.7 million barrels; and a "Best Estimate" for associated recoverable gross contingent and unrisked prospective oil resources of 2.1 million barrels, with a "low"-to-"high" range of 1.4-3.2 million barrels. This assessment is generally consistent with Frontera's internal estimates.

For gas, NSA places a "Best Estimate" for gross original gas-in-place for the Mtsare Khevi Field of 2.6 billion cubic feet, with a "low"-to-"high" range of 2.1-3.1 billion cubic feet; and a "Best Estimate" for associated gross contingent and unrisked prospective resources of 1.5 billion cubic feet, with "low"-to-"high" range of 1.2-1.9 billion cubic feet. Frontera's internal estimates reflect additional resource potential along the northwest trend of the field's fault block, which NSA have not yet been asked to evaluate.

The Shallow Fields Production Unit is located in the central portion of Block 12 and represents what the Company believes to be an extensive trend of low-cost, low-risk oil and gas resources. The unit contains a number of known oil fields; Mirzaani, Mtsare Khevi, Nazarlebi and Patara Shiraki, representing undeveloped or under-developed fields that have additional associated exploitation potential. The unit also contains an inventory of "look-alike" exploration prospects, the Kakabeti, Lambalo, Mkralihevi, Mlashiskhevi-Oleskhevi and Tsitsmatiani prospects, each of which contains Soviet-era wells that had hydrocarbon shows while drilling, but were never placed on production or adequately appraised. Reservoir objectives are the well-known, regional clastic reservoirs of Pliocene and Miocene age, situated at depths from 10 meters to 1,500 meters.

Further to the successful completion of the recently announced equity financing package, the new drilling campaign at Mtsare Khevi Field is part of an overall plan whereby Frontera intends to increase production from its portfolio within Block 12 from 225b/d to c.5,000b/d over the next two years,

Steve C. Nicandros, Chairman and Chief Executive Officer, commented, "The commencement of drilling operations, which began in August at the Mtsare Khevi Field, represents the launch of an exciting and extensive drilling campaign at this undeveloped, low-cost asset. Like the other assets within the Shallow Fields Production Unit, this field represents near term value realization and reserve additions for our company."

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BOEMRE: Operators Evacuate Ops in GOM

- BOEMRE - Operators Evacuate Ops in GOM

Monday, September 05, 2011
BOEMRE

Offshore oil and gas operators in the Gulf of Mexico are evacuating platforms and rigs in the path of Tropical Storm Lee. The Bureau of Ocean Energy Management, Regulation, and Enforcement (BOEMRE) Hurricane Response Team is monitoring the operators' activities. The team will continue to work with offshore operators and other state and federal agencies until operations return to normal and the storm is no longer a threat to Gulf of Mexico oil and gas activities.

Based on data from offshore operator reports submitted as of 11:30 a.m. CDT Sunday, personnel have been evacuated from a total of 239 production platforms, equivalent to 38.7 percent of the 617 manned platforms in the Gulf of Mexico. Production platforms are the structures located offshore from which oil and natural gas are produced. Unlike drilling rigs, which typically move from location to location, production facilities remain in the same location throughout a project's duration

Personnel have been evacuated from 25 rigs, equivalent to 35.7 percent of the 70 rigs currently operating in the Gulf. Rigs can include several types of self-contained offshore drilling facilities including jackup rigs, submersibles and semisubmersibles.

As part of the evacuation process, personnel activate the applicable shut-in procedure, which can frequently be accomplished from a remote location. This involves closing the sub-surface safety valves located below the surface of the ocean floor to prevent the release of oil or gas. During the recent hurricane seasons, the shut-in valves functioned 100 percent of the time, efficiently shutting in production from wells on the Outer Continental Shelf and protecting the marine and coastal environments. Shutting-in oil and gas production is a standard procedure conducted by industry for safety and environmental reasons.

From operator reports, it is estimated that approximately 60.2 percent of the current oil production in the Gulf of Mexico has been shut-in. It is also estimated that approximately 44.3 percent of the natural gas production in the Gulf of Mexico has been shut-in. The production percentages are calculated using information submitted by offshore operators in daily reports. Shut-in production information included in these reports is based on the amount of oil and gas the operator expected to produce that day. The shut-in production figures therefore are estimates, which BOEMRE compares to historical production reports to ensure the estimates follow a logical pattern.

After the hurricane has passed, facilities will be inspected. Once all standard checks have been completed, production from undamaged facilities will be brought back on line immediately. Facilities sustaining damage may take longer to bring back on line. BOEMRE will continue to update the evacuation and shut-in statistics at 1:00 p.m. CDT each day as appropriate.

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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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Oilex Prepares Cambay Well for Clean-Up Ops

- Oilex Prepares Cambay Well for Clean-Up Ops

Wednesday, August 31, 2011
Oilex Ltd.

Oilex advised that operations to prepare for well clean-up flow and production testing are continuing. The coil tubing unit was not able to retrieve milling tools being used to open the second fracture stimulation stage. Consequently, it is planned to mobilize a work-over rig to the well location to retrieve the milling tools. Following this, operations will resume to open up the remaining fracture stimulation stages so that clean-up operations and a flow test can be conducted.

The Cambay-76H "proof of concept" horizontal well is evaluating the production potential of the Y Zone interval of the extensive deep Eocene "tight" reservoirs in the onshore Cambay Production Sharing Contract area, Gujarat, India.

• Report date: August 30, 2011
• Status: Preparations for well clean-up flow and production testing
• Past Week's Operations:
  • Coil tubing operations to retrieve tools
  • Mobilizing chemical cutting equipment
  • Initial planning for work-over rig operations
• Objective: Cambay Eocene "tight" reservoir Y Zone
• Total Depth: 2,740 meters including 610 meters horizontal section

The participating interests in the Cambay PSC are:

• Oilex Ltd (Operator) 30%
• Oilex NL Holdings (India) Limited 15%
• Gujarat State Petroleum Corporation Ltd 55%

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Drilling Ops Commenced at Polish Kutno Well

- Drilling Ops Commenced at Polish Kutno Well

Monday, August 29, 2011
FX Energy Inc.

FX Energy announced the start of drilling on the Kutno-2 well in the Company's 700,000 acre Kutno concession. The Kutno-2 well is planned to test a large (approximately 35,000 acres or 140 square kilometers) 2-D defined Rotliegend structure at a depth of approximately 6,500 meters (21,000 feet).

"FX Energy is pleased to be joined in this project by PGNiG, the most experienced explorer in Poland," said David Pierce, the Company's CEO. "Given that Poland currently imports approximately one-third of a Tcf of gas annually, and the Kutno prospect could have an EUR of up to 9.5 Tcf, both companies recognize that this project has the potential to change the energy balance in the entire region."

The current rig will be used to drill the first sections of the well prior to moving Nafta Pila's larger IDM 2000 rig with 500 ton load capacity onto location for the bottom sections of the well. Drilling is expected to take approximately eight to nine months. FX Energy is the operator and will be 50% owner of the Kutno concession; PGNiG will earn 50%.

Plawce-2

The Plawce-2 tight gas well reached total depth of 4,200 meters. Gas shows were encountered as expected throughout the Rotliegend sandstone reservoir. Cores and logs are currently being analyzed. Based upon the results of this analysis, the well is expected to be perforated at the deepest part of the well to determine whether the entire Rotliegend reservoir is water-free. Thereafter, current plans call for perforating and fracking approximately 50 meters of Rotliegend in the upper portion of the well where porosity is approximately 9-10%. After testing, the well is expected to be completed as a vertical producer.

The Plawce-2 well is located on an uplifted tight Rotliegend block that could contain as much as 500 Bcf of gas in place within the Fences concession. The Company holds a non-operating 49% interest in the Fences concession and the Plawce-2 well; PGNiG operates and holds 51% interest.

U.S. Alberta Bakken

In Montana, FX Energy is in the early stages of appraising the Alberta Bakken oil potential in approximately 75,000 net acres. The Company has drilled and fracced a vertical well in its Cutbank acreage and is currently monitoring the flow back. The Company has drilled a second vertical well in another of its acreage blocks and plans to frac the vertical section. In three to four weeks the Company plans to drill a lateral section of approximately 4,000 feet at this location. Two further wells are planned in the fourth quarter, one vertical and one with a lateral section, assuming results of the Company's first two wells meet technical expectations. FX Energy is operator and holds a one-third working interest in approximately 75,000 net acres; American Eagle Energy, Inc., and Big Sky Operating, LLC, each own a one-third working interest.

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Cobalt Kicks Off Drilling Ops Offshore Angola

- Cobalt Kicks Off Drilling Ops Offshore Angola

Monday, August 29, 2011
Cobalt International Energy Inc.
by SubseaIQ

Cobalt provided the following update on its West Africa drilling program.

Cobalt has initiated drilling operations on its Cameia No. 1 well in Block 21, Offshore Angola. Well operations are being conducted with the Diamond Ocean Confidence drilling rig. After drilling and evaluating the Cameia-1 prospect, Cobalt will drill the Bicuar-1A well to test the Bicuar prospect, also in Block 21. Both wells are targeting pre-salt objectives.

As previously announced, Cobalt expects each well to take 80 to 100 days to drill and an additional 10 to 20 days to evaluate, if successful. Cobalt is the operator of Cameia and Bicuar and has a 40% working interest in each prospect.

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Completion Ops Underway at Gulf Shores' Saskatchewan Well

- Completion Ops Underway at Gulf Shores' Saskatchewan Well

Thursday, August 25, 2011
Gulf Shores Resources Ltd.

Completion operations are underway on the 4-2-15-33W1 well in the Wapella area of Southeast Saskatchewan in which Gulf Shores Resources has earned a 47.5% working interest. This new oil well offsets the producing 5-2-15-33W1 Bakken oil well in which Gulf Shores also owns a 47.5% working interest.

The rig will now move to the 3-34-14-33W1 location in the Coothill area of Southeast Saskatchewan where drilling is expected to commence within a few days.

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TDW Finishes Isolation Ops Offshore Malaysia

- TDW Finishes Isolation Ops Offshore Malaysia

Wednesday, August 24, 2011
TDW Offshore Services AS

TDW Offshore Services (TDW) has successfully completed a series of pipeline pressure isolation operations offshore western Borneo in Malaysia for Sarawak Shell Berhad. The operations were carried out on the Jintan, B11 and F6 platforms in the South China Sea, as part of Sarawak Shell Berhad's ongoing pipeline valves maintenance program.

Pipeline pressure safely isolated

The first of the three operations took place on the Jintan platform on a 24-inch gas export pipeline that extends from the JNDR-A platform to platform M1 off the West coast of Sarawak. TDW executed a double-block pressure isolation against 90 bar pipeline pressure so that Shell could safely replace a passing shut down valve (SDV). A 24-inch SmartPlug® isolation tool was pigged using production gas approximately 30 meters into the pipeline and set at the vertical section of the riser. Throughout the entire operation the SmartPlug tool was remotely operated, monitored and tracked continuously by TDW with its SmartTrack™ technology. The SmartTrack system, which uses proprietary electromagnetic and Extremely Low Frequency (ELF) technology, provides the operational security required to safely isolate pipelines in a wide range of operating environments. After the topside section was safely depressurized, a spool section was replaced and a new flange welded to it to accommodate the new shutdown valve. TDW utilized a joint tester tool to verify the flange installation prior to Shell installing the replacement SDV. Overall, the affected section was isolated for a period of 13 days at a pressure of 90 bar while necessary testing and SDV installation took place.

Passing motor-operated valves (MOVs) replaced at B11-A platform

On the second operation, a 32-inch SmartPlug isolation tool was utilized to replace two passing launcher motor-operated valves (MOVs) on a 32-inch gas export pipeline at the B11 platform that connects to the E11RB platform. By pigging in a SmartPlug tool with water over a distance of 50 meters and monitoring it with SmartTrack technology, TDW set the tool vertically in the riser and created a double-block isolation against the gas pressure. The SmartPlug tool remained in the riser for eight days at 102 bar to facilitate safe replacement of the MOVs.

One-month isolation facilitates replacement of MOVs and topside maintenance

The third operation also involved replacement of launcher MOVs on a 32-inch gas export pipeline that extends from the F6P-A platform to the E11 hub. This particular operation required TDW to utilize the SmartPlug system to successfully isolate the pipeline against 70 bar. The pipeline was isolated for 11 days for the replacement of defective MOVs and an extended duration for additional topside maintenance activities.

TDW carried out all three pressure isolation operations with SmartPlug tools that were custom-built at its headquarters in Stavanger, Norway. Local support was provided by TDW personnel based in Singapore and TDW's agent Amserve Engineering in Malaysia.

Reliable isolation services play pivotal role in pipeline maintenance

Since 2001, TDW has performed a number of pipeline pressure isolation operations to facilitate safe valve replacements on behalf of Sarawak Shell Berhad in Malaysia. "On behalf of Shell and the SKME2 team, I would like to thank TDW for their commitment and dedication to making sure that the isolation operations were executed with care and attention to detail," said Redzuan Zulkflie, Mechanical Static Engineer for Sarawak Shell Berhad.

"I am very proud of the isolation work that the TDW team carried out for Shell in Malaysia," said Rolf Gunnar Lie, Business Development Manager for TDW. "As a result of our joint efforts, TDW successfully isolated the designated sections of the pipeline network for safe execution of riser valve replacement. Had Shell been required to depressurize the long pipelines to replace the valves, it would have caused longer production downtime. It would also have been extremely costly, time-consuming and harmful to the environment had flaring taken place," he added.

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EDS Welcomes New Area Manager for Marcellus Ops

- EDS Welcomes New Area Manager for Marcellus Ops

Wednesday, August 24, 2011
Environmental Drilling Solutions LLC

Environmental Drilling Solutions, (EDS), a leader in solids control, cuttings processing and zero discharge services, has named Richard Guillory Area Manager for Marcellus Shale operations.

Guillory will manage day-to-day field operations locally and be based out of the company's local office in Bradford County, Pa.

Guillory most recently served as Environmental Solutions Projects Manager with M-I SWACO where he developed new systems to manage growing numbers of projects in multiple locations.

"Richard has proven himself as an effective project manager with the ability to create more efficient operations," said Jake Garber, EDS Regional Manager. "His assignment to the Marcellus Shale region is an essential step toward meeting our growing demand in the area."

Guillory received a master of business administration in management and a bachelor's degree in mechanical engineering, both from the University of Louisiana at Lafayette.

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Canadian Natural Resources Resumes Ops in Alberta

- Canadian Natural Resources Resumes Ops in Alberta

Tuesday, August 23, 2011
Canadian Natural Resources Ltd.

Canadian Natural Resources announced that Synthetic Crude Oil ("SCO") sales have recommenced from its Horizon Oil Sands operation in Northern Alberta.

On August 16, 2011, Canadian Natural successfully and safely resumed production at Horizon from the fire that occurred in the coker unit on January 6th, 2011. Production for the past four days has consistently averaged approximately 75,000 bbl/d of SCO. Ramp up to full production capacity of 110,000 bbl/d of SCO is expected in the next week. First pipeline deliveries commenced on August 18, 2011.

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Gulf Shores Starts Drilling Ops in Southeast Saskatchewan

- Gulf Shores Starts Drilling Ops in Southeast Saskatchewan

Friday, August 19, 201
Gulf Shores Resources Ltd.

Drilling has commenced on the 4-2-15-33W1 well in the Wapella area of Southeast Saskatchewan, said Gulf Shore Resources. Gulf Shores Resources Ltd. is paying 47.5% of the cost of this well to earn a 47.5% working interest. The well offsets the producing 5-2-15-33W1 Bakken oil well in which the Company also owns a 47.5% working interest.

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Entek to Test Ops at Niobrara Shale Program

- Entek to Test Ops at Niobrara Shale Program

Thursday, August 18, 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) test program will be initiated within the next 10 days. The Niobrara (primary objective) completion program, which includes testing and fracture stimulation of the potential Niobrara pay zones, is scheduled to start in September 2011.

Slater Dome (SD) Federal 24-9DL – The well is currently drilling ahead at 3,200 ft after successfully setting casing at 2,520 ft. The planned total depth of the well is 8,627 ft.

Entek holds a 55% interest in the Green River Basin Joint Venture (GRBJV) with Emerald O&G 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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American Petro-Hunter Starts Drill Site Ops at N. Oklahoma Proj.

- American Petro-Hunter Starts Drill Site Ops at N. Oklahoma Proj.

Wednesday, August 17, 2011
American Petro-Hunter Inc.

American Petro-Hunter announced that drill site operations have commenced in preparation for the next horizontal oil well at the Company's North Oklahoma Mississippi Project development.

Site arrangements are underway including permitting and requisite documentation in advance of the spud of the newly designated NOW-2H well. The directional drilling contractor has been secured and the Company expects a spud date shortly.

The well is a direct offset to the NOM-1H well, which began production in July and will involve a similar lateral drilling operation into the recently discovered Mississippi reservoir. The Company has purchased full working interest participation in up to 11 additional horizontal wells within the play with the NOW-2H becoming the 2nd well implemented under the planned development program.

The leases in the horizontal play are being developed on 80 acre parcels, however the well spacing will be evaluated after each well is put into production for a period of 30-45 days prior to engineering any additional infill wells. This prudently engineered plan will ensure the maintenance of reservoir integrity over the life of the proposed 24 month drilling schedule. The program is envisioned to involve the drilling of approximately one horizontal Mississippi formation well every 30 to 60 days.

Given the dramatically increased levels of activity in the area, rig availability has become a key scheduling issue. As a result, the Company and partners have accelerated the spud date of the NOW-2H and have further determined that the previously announced vertical NOS-2-22 required a shift to October based on current rig logistics which ultimately provides greater overall benefits allowing for improved operational efficiency across both wells.

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Matra Shuts-In Ops at Well-12

- Matra Shuts-In Ops at Well-12

Wednesday, August 17, 2011
Matra Petroleum plc

Matra announced an update on its operations and plans in the Sokolovskoe Field, Russia.

Current Operations

Well-12

Well-12 has suffered from a build-up of wax in the tubing and an increase in water cut to 70% and has ceased to flow and has now been shut-in.

Prior to the increase in water cut and shut-in of the well, the Company had sought an independent review of the status of well-12. This review, which was conducted by Gaffney, Cline & Associates ("GCA"), concluded that, although there was insufficient data available to definitively determine the source of the water, the available data was not typical of an aquifer influx and that the water may be flowing behind the production liner from overlying formations. The GCA review recommended acquisition of further data in order to identify the source of the water before attempting a remedial work-over.

Following the GCA review, the directors have sourced a work-over rig (expected to be on site on August 17) that will allow the Company to pull and clean the production tubing and then to artificially place the well into temporary production, using nitrogen. This will also allow production logging over the entire liner interval and into the production casing and will provide the best opportunity to identify the source of the water production.

Following production logging, a pressure survey will be conducted before deciding on the viability of further remedial work on the well.

Well-13

After establishing water-free oil production, the leased production equipment at the site was demobilized and the well shut-in. Analysis of the production and pressure data shows that the well should be expected to produce at around 100 bopd with the installation of an electrical submersible pump and surface production facilities at the site. A firm decision to install this equipment has not yet been made but the directors expect that its installation will enable well-13 to generate a positive cash flow after the deduction of production taxes and other costs. The directors have taken the decision to await the results of the well-12 work-over before committing to this expenditure.

Future Program

Evaluation of the Sokolovskoe Field requires two further elements before proceeding with a full field development:

• Delineation of the full extent of the Sokolovskoe structure by means of a full field 3D seismic survey; and
• The establishment of commercial production over an extended period and the confirmation of the geological model by the drilling of well-14.

Recent changes by the Russian authorities to the drilling approval process require the Company to complete additional environmental and ecological surveys and studies prior to approval of new wells. These studies have commenced and approval for well-14 is expected later this year.

The cost of acquiring the 3D survey would be approximately $2 million and the cost of well-14 is estimated at $5 million. These costs are subject to change due to variations in exchange rates and local market conditions. Additional funding would be required before the Company could commit to such a work program.

The Company will continue to update the market as required.

Managing Director, Peter Hind commented, "The continuing problems at well-12 are frustrating. We are, however, continuing efforts to obtain further information from the well and to see if we can continue production. Importantly, given that the well is low on the mapped structure, it is not key to the overall development of the field.

"The Aphonenski reservoir has been produced over the longer term in nearby fields and the prognosis for well-14 remains good."

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Imperial Commences Drilling Ops at Green Tide SWDF

- Imperial Commences Drilling Ops at Green Tide SWDF

Thursday, August 11, 2011
Imperial Resources Inc.

Imperial announced that, further to its announcement of rig arrival on August 9, 2011, the drilling rig to deepen the disposal well at the Company's Green Tide Salt Water Disposal Facility ("SWDF") is expected to commence drilling operations, slightly earlier than expected, Thursday, August 11, 2011.

The rig is expected to set a whipstock and sidetrack the well to TD over the next 10 days. The aim is to deepen the Green Tide SWDF well from 3,100 to 8,500 feet to establish the well around 500 feet to 600 feet into the Ellenburger formation. Casing will then be cemented from 500 feet into the Ellenberger to approximately 1,000 feet back up the hole and the well then drilled ahead to ideally create about 2,000 feet of open hole exposure in the Ellenburger so as to maximize disposal capacity.

Subject to success, commercial disposal operations are expected to commence immediately targeting full disposal capacity of 15,000 barrels per day as quickly as possible. At full capacity, the Company believes the Green Tide SWDF has the potential to generate significant cash flow at relatively low operating costs.

The Green Tide SWDF

The Green Tide SWDF is conveniently located for the disposal of large volumes of salt water generated from essential fracture stimulation operations on Barnett Shale gas wells. There are approximately 6,000 such Barnett wells within 20 miles of the SWDF.

Imperial plans to reopen Green Tide to dispose of up to 15,000 barrels of salt water a day. The Company's acquisition and development of the low run-time Green Tide assets and disposal permit is expected to save in excess of $5,000,000, compared to a new build cost.

Green Tide is one of two key projects identified as transformational for Imperial (the other being the Company's Oklahoma project).

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Fracking, Testing Ops Commenced at Global Petroleum's Eagle Ford Well

- Fracking, Testing Ops Commenced at Global Petroleum's Eagle Ford Well

Wednesday, August 10, 2011
Global Petroleum Ltd.

Texon has advised that fracking and testing operations on the second Eagle Ford well in which Global has an interest (Tyler Ranch EFS #2H) began on August 8, 2011. The project involves 17 stages (compared with 15 in the first Eagle Ford well), with fracking expected to take about a week followed by testing.

Initial flow test results are expected to be available in two weeks.

The surface location of the well is close to the production facilities associated with the first Eagle Ford well so the well will be able to be immediately connected for production.

Global has a 7.939% working interest in approximately 1,651 acres beneath the Olmos formation including the Eagle Ford Shale. Global's interest in the Leighton prospect also includes a 15% working interest in approximately 873 acres from the surface down to the stratigraphic equivalent of the Olmos formation.

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