Borders & Southern has announced the results of the Darwin fluid sample analysis. As previously reported, well 61/17-1 encountered a good quality sandstone reservoir comprising 67.8m of net pay with an average porosity of 22%. The gas condensate reservoir was sampled at four separate levels with 3 fluid samples taken at each level.
The initial condensate yield from the Darwin gas samples, as measured in a laboratory separator test, varies from 123 to 140 stb/MMscf. The API gravity of the condensate is 46 to 49 degrees. Based on the condensate yield and ongoing reservoir modelling, the Company estimates the recoverable volume of condensate to be 130 to 250 million barrels with a mid case of 190 million barrels.
Following these positive laboratory results, the Board will approve a work programme that includes appraisal drilling of the Darwin discovery. Additional wells are necessary to confirm the initial resource estimates and establish a commercial development. In the coming months, activity will focus on a comprehensive technical evaluation of all the data collected from well 61/17-1 and a review of potential development concepts along with project economics.
These results have exciting implications for the Company’s prospect and lead inventory and particularly for those prospects in the Lower Cretaceous play fairway to the south of the Falkland Islands. Borders & Southern’s prospect inventory contains further relatively low risk structural prospects of a similar size to Darwin along with stratigraphically trapped fans of slightly higher risk but larger scale. Some of these prospects will be targeted in the next drilling phase with the objective of adding to the discovered resources of Darwin and building a core development area.
“Discussions with a seismic contractor regarding the acquisition of additional 3D seismic are in progress and we plan to have a vessel in the Falklands at the start of 2013 to commence the survey,”said Borders & Southern in a statement.
This survey will focus on similar prospects to Darwin currently outside our existing 3D area. Whilst the final costs of the 2012 drilling programme will not be fully known until after the demobilisation of the rig later in the year, the Company can state that it is fully funded for the 3D seismic acquisition and processing, the reprocessing of the Company’s 2007 3D seismic data and all the technical studies that need to be undertaken on the samples collected from the two wells.
Given the encouraging results from the Darwin well, the Company will start planning the next drilling programme, which is likely to include both exploration and appraisal wells. The company has said that the the timing of drilling will be dependent on rig availability, but “realistically this will not occur before 2014“. The Company is currently exploring the best way to fund the next phase of the programme, including the possibility of now bringing in partners.
“The Heidelberg sidetrack appraisal well was successfully drilled and defined the down-dip limits of the Heidelberg field,” said Chuck Meloy, Anadarko Sr. Vice President, Worldwide Operations. “This well extends the oil/water contact down structure by approximately 700 feet, and continues to validate the field’s estimated resource range, while providing support for the option of a stand-alone development. Anadarko and Heidelberg’s co-owners have initiated pre-FEED (front-end engineering and design) work to evaluate development solutions with the objective of advancing commercialization of this emerging mega project.”
The Heidelberg sidetrack appraisal well in Green Canyon block 903 is located approximately 1.3 miles from the Heidelberg discovery well. The well was drilled to a total depth of approximately 30,440 feet in water depths of approximately 5,260 feet.
Anadarko operates Green Canyon block 903 with a 44.25-percent working interest. Co-owners in the block include Apache Deepwater LLC, a subsidiary of Apache Corporation (12.5 percent), Eni (12.5 percent), Statoil (12 percent), ExxonMobil (9.375 percent) and Cobalt International Energy, L.P. (9.375 percent).
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by Range Resources – Press Release – Friday, March 09, 2012
Range Resources reported Friday further success in the appraisal and development of the North Chapman Ranch Field onshore Texas (Range 20-25 percent interest), with the successful drilling of the Smith #2 and Albrecht #1 wells.
Initial gross flow rates from the uppermost pay zone, which is one of four principal pay zones, in the Smith #2 well reached more than 3 million cubic feet per day and 125 barrels of oil per day, with more than 7,500 pounds per square inch flowing casing pressure on a 10/64-inch choke. Work is being conducted now to remove all of the plugs below the upper pay zone and combine the remaining lower pay zones to achieve maximum rate and recovery, Range said.
The Smith #2 well was drilled approximately 1,350 feet southeast of the Smith #1 discovery well, further extending the Company’s Proved Reserves in that direction.
The Smith #2 was followed immediately by the Albrecht #1, drilled more than 1,500 feet southeast of the Smith #2. The Albrecht #1 confirmed the presence of the Howell Hight reservoir in that area and is also expected to add significant Proved Reserves to the Company’s portfolio.
With four wells now drilled in the field, Range estimates that over 80 percent of the structural closure at the Howell Hight reservoir falls into the proved and probable (2P) category. Work is currently underway to revise the reserve estimates at North Chapman Ranch, and is expected to be finalized once The Albrecht #1 well comes online. The Albrecht well is scheduled for completion and fracture stimulation within the next four to six weeks.
Once the Smith #2 and Albrecht #1 wells are both online, Range estimates that its net production and cash flow from the project will increase by more than 200 percent over current levels.
Company: Range Resources
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