Sonangol’s deepwater Orca-1 well encountered oil in the presalt layer of Block 20/11 in the Cuanza basin offshore Angola. The well reached a measured depth of 12,703 ft. Initial well tests saw flow rates of 16.3 MMcm/D of gas and 3,700 BOPD. Cobalt International Energy (40%) is the operator, with partners Sonangol Research and Production (30%) and BP Exploration Angola (30%).
Premier Oil’s Kuda Laut-1 well in Indonesia’s Tuna production sharing contract has encountered 183 net ft of oil-bearing reservoir and 327 net ft of gas-bearing reservoir. Following evaluation operations, the well will be sidetracked to drill the Singa Laut prospect in an adjacent fault block. Premier is the operator (65%), with partner Mitsui Oil Exploration Company (35%).
Philippines National Oil Company (PNOC) has begun drilling operations on its Baragatan-1 exploration well on service contract 63, offshore Palawan Island, west of the Philippines, using the Naga 5 jackup rig. PNOC (40%) is the operator, with partners Dragon Oil (40%) and Nido Petroleum (20%).
Statoil Australia Theta started drilling operations at the OzBeta-1 vertical exploration well, located in EP 127, south Georgina basin, Northern Territory, Australia. The well will be drilled to an approximate depth of 1300 m. The well will test three potential pay zones within the structures and formations in that area, particularly targeting a 40- to 50-m section expected within the Thorntonian Limestone formation. Statoil (60%) is the operator, with partners Baraka Energy & Resources (25%) and PetroFrontier (15%).
Hurricane Energy has spudded an appraisal well on the Lancaster discovery at P1368, in the North Sea, west of the Shetland Islands, at a 160-m water depth. According to a report prepared by RPS Consultants in November 2013, 2C recoverable contingent resources allocated to Lancaster were 207 million BOE. The well is being drilled by semisubmersible Sedco 712. Hurricane (100%) is operator of the license.
Statoil well 7220/7-3 S encountered hydrocarbons in the Drivis PL 532, Barents Sea. The vertical well intersected a 68-m gross gas column in the Stø formation and an 86-m gross oil column in the Stø and Nordmela formations. The well was drilled to a vertical depth of 2029 m below the sea surface and was terminated in the late Triassic Fruholmen formation. Water depth at the site is 345 m. Statoil estimates the total recoverable volumes in the Drivis prospect to be in the range of 44 to 63 million BOE (90% oil). Statoil (50%) is the operator, with partners Eni Norge (30%) and Petoro (20%).
Statoil’s 16/2-19 appraisal well, located on the PL265 Johan Sverdrup discovery in the North Sea’s Norwegian continental shelf, has encountered oil. The well found 6 m of oil-bearing sandstone of Lower Jurassic/Upper Triassic age in the Geitungen area in the northeastern part of the Johan Sverdrup discovery. Sidetrack well 16/2-19A encountered 13 gross m of low- to excellent-quality upper Jurassic sandstone. Statoil (40%) is operator, with Petoro (30%), Det Norske (20%), and Lundin (10%).
Chevron has spudded its first exploratory shale well in Romania. The well’s commencement has been repeatedly delayed by anti-fracturing protesters; it was originally set to be spudded at the end of 2013. The vertical well will be drilled to 13,000 ft, and will take approximately 90 days to reach total depth.
Oil Search has discovered hydrocarbons at 3255 m in its Taza-2 well in Kurdistan. These hydrocarbon shows were encountered in the Jeribe formation, where an 18-m core was cut from the carbonate reservoir. Taza-2 is located 10 km northwest of Taza-1 and is designed to appraise the hydrocarbon-bearing intervals discovered by Taza-1. The well is also targeting Tertiary and Cretaceous layers, including the Shiranish formation. Oil Search (60%) is the operator, with partners Total (20%) and the Kurdistan Regional Government (20%).
Khalda Petroleum Company, an Apache-operated joint venture with the Egyptian General Petroleum Company, made two natural gas and condensate discoveries in Egypt. The Herunefer-1X discovery, located in the Matruh basin, encountered pay in the Alamein, Alam El Buieb-6 (AEB), Masajid, Upper Safa, and Lower Safa formations. Tests from the Lower Safa and Upper Safa intervals flowed at a combined rate of 49 MMcf/D of gas and 7,700 B/D of condensate. The BAT-1X discovery, located in the northern Shushan basin, tested at 31 MMcf/D of gas and 390 B/D of condensate from a thick Paleozoic Shiffah sandstone interval. The 15,555-ft well also encountered pay in the Cretaceous Upper Bahariya, Lower Bahariya, Alamein, AEB-3C, and AEB-3D formations. Khalda (100%) is operator of the lease.
Leni Gas & Oil’s onshore Trinidad development well, GY-664, encountered approximately 193 ft of gross oil-bearing sands in the Upper Goudron sands. Drilling continues in the remaining Goudron sands, estimated to be 400 ft thick, to the first casing point at approximately 1,540 ft, where electric logs will be run. Drilling will then continue in order to test the primary objectives in the Gros Morne and the Lower Cruse sands at depths below 2,800 ft. Leni (100%) is the operator.
Stone Energy encountered more than 275 ft of net oil pay in three separate sections of the deepwater Cardona South well (MC 29 #5) in Mississippi Canyon 29, Gulf of Mexico. Water depth is 2,135 ft. Stone (65%) is operator, with partner Hunt Oil (35%).
Canacol Energy encountered light oil in the Pantro-1 exploration well in the LLA23 exploration and production contract in the Llanos basin, Colombia. The well was drilled to a total depth of 12,682 ft and encountered 83 ft of net oil pay in five separate reservoirs. The 37 ft of net pay within the Gacheta reservoir flowed at a net rate of 2,300 B/D of 31° API crude over a 24-hour period. Canacol (80%) is the operator, with partner Petromont (20%).