Tullow Oil’s Ngamia-1 exploration well onshore Kenya in Block 10BB was drilled to an intermediate depth of 4,970 ft and continues to a total depth (TD) of about 8,858 ft. Total net oil pay encountered so far is more than 328 ft across a gross oil-bearing interval of 2,133 ft. Tullow (50%) is operator, with Africa Oil (50%).
A contract for a 3D seismic survey in License Area L6 offshore Kenya has been awarded to Fugro-Geoteam. The survey will cover 680 km2. License Area L6 lies in the Lamu basin and within the Tana River Delta, north of recent natural gas discoveries off the coasts of Mozambique and Tanzania. Kenya L6 joint venture partners are FAR Limited (60%) and Pancontinental Oil & Gas (40%).
Coastal Energy’s Bua Ban South A-05 well was drilled to 3,525 ft total vertical depth (TVD) about 1,650 ft east of the A-04 well. The well encountered 20 ft of net pay across two Miocene zones with average porosity of 29%. The Bua Ban South A-03ST well was drilled to 9,700 ft TVD. It encountered 31 ft of net pay in the Lower Oligocene, with 15% porosity. A-03ST is about 5,700 ft north of the Bua Ban South A-01 Oligocene discovery. The well encountered 325 ft of reservoir in the Eocene with 11% porosity.
China National Offshore Oil Corporation made another discovery, Dongfang (DF)13-2, in a high-temperature, high-pressure natural gas reservoir in Yinggehai. DF13-2 is located in the north of a central sag in the Yinggehai basin in the western South China Sea. The discovery well DF13-2-1 encountered gas pay zones with a total thickness of 115 ft in a water depth of 213 ft and well depth of 10,394 ft. During the test period, the well flowed at an average rate of 42.4 MMcf/D of natural gas.
Australia awarded 12 new offshore exploration permits off Western Australia and Victoria—AC/P55, Ashmore platform of the Bonaparte basin off the Ashmore and Cartier islands, to Finder No. 13; WA-471-P, Caswell sub-basin of Browse basin offshore Western Australia, to IPM Browse; WA-472-P and WA-473-P, across the Lambert shelf, Beagle and Dampier sub-basins of the northern Carnarvon basin, to Woodside Energy; WA-474-P, Central Exmouth plateau, northern Carnarvon basin, to Hess Australia (Offshore); WA-475-P, Central Exmouth plateau, northern Carnarvon basin, to BHP Billiton Petroleum (Australia) and Apache Northwest; WA-476-P, Exmouth sub-basin, northern Carnarvon basin, to Murphy Australia Oil; WA-468-P, Beagle sub-basin, northern Carnarvon basin, to Finder No. 14; WA-469-P and WA-470-P, Exmouth plateau, northern Carnarvon basin, to BHP Billiton (Australia); and VIC/P68, Gippsland basin off Victoria, to Bass Strait Oil Co.
Total stopped the gas leak at the G4 well on its Elgin complex in the North Sea. A day earlier, the French oil major began conducting a well intervention program that involved pumping heavy mud into the leaking well. The firm said it took 12 hours to stop the leak. The G4 wellhead had been leaking gas following an incident on 25 March, which led to 238 people being evacuated from the Elgin platform and from an adjacent drilling rig, the Rowan Viking. The G4 well will be closely monitored to ensure the success of the intervention.
Faroe Petroleum commenced drilling on the Cooper prospect in the Norwegian Sea. The exploration well will target the Cooper prospect located in PL477 in Block 6506/11 on the Halten Terrace between the Smørbukk oil field to the east and the Morvin oil field to the west. Cooper consists of an untested north-to-south-trending fault block. The main reservoir objectives are the prolific Middle Jurassic Garn and Ile formations, the main producing reservoirs in the Smørbukk and Morvin fields. Centrica Resources (Norge) (40%) is operator, with Faroe (30%) and Suncor Energy Norge (30%).
Gulf Keystone’s Bakrman-1 exploration well was spudded on the Akri-Bijeel block in the Kurdistan region of Iraq. Bakrman-1, the third exploration well to be drilled on the Akri-Bijeel block, is located 20 miles northwest of the Bijell-1 discovery well and 16 miles northwest of the Aqra-1 appraisal well, currently being drilled to appraise the Bijell discovery. Bakrman-1 will target prospective intervals in the Jurassic, with a planned TD of about 11,811 ft in the Lower Jurassic. Kalegran Ltd. (80%)—a 100% subsidiary of MOL Hungarian Oil and Gas—is operator, with Gulf Keystone (20%).
Questerre Energy Corporation completed the first phase of a core hole program to assess its oil shale licenses in Saskatchewan, Canada. The program was designed to evaluate the western block, known as the Arborfield block, covering 58,112 net acres. During first-quarter 2012, over 2,297 ft of continuous core was obtained from 10 new wells. About 98 ft of the target oil shale formation was encountered in all wells drilled, with about 400 core samples taken. Testing includes geochemical analysis and modified Fischer assay analysis to evaluate potential oil yield.
Ecopetrol announced the discovery of hydrocarbons in the Tisquirama Este-1 exploratory well, located in the municipality of San Martin, Cesar, Colombia. In initial tests, the 9,100-ft well produced 624 BOPD, with a water cut of less than 1% and 23°API gravity. The results from this well are expected to significantly increase production from the Tisquirama block, where currently production is around 2,400 BOPD. Ecopetrol (100%) is operator.
OGX Petróleo e Gás Participações presented to Brazil’s National Petroleum, Natural Gas, and Biofuels Agency a declaration of commerciality for the Waikiki accumulation, for which the proposed new designation is the Tubarão Martelo field, in blocks BM-C-39 and BM-C-40 in shallow waters of the Campos basin. OGX holds a 100% interest in these blocks. The Waikiki accumulation was discovered through the wildcat well 1-OGX-25-RJS in December 2010, and production is expected to start late 2013.