Tullow Oil appraised the Enyenra-4A well in the Deepwater Tano license offshore Ghana. The well, drilled to a total depth of 13,695 ft in 6,160 ft of water, encountered oil in very good quality sandstone reservoirs. Results of drilling, wireline logs, samples of reservoir fluids, and pressure data show Enyenra-4A has intersected 105 ft of net oil pay. Tullow (49.95%) is operator, with Kosmos Energy (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%), and the Ghana National Petroleum Corporation (10% carried interest).
Anadarko announced another success in the Rovuma basin, offshore Mozambique, with a new gas find at its Barquentine-4 appraisal well. The well—located in the 2.6-million-acre Rovuma basin Area 1 block approximately 19 miles north of the Lagosta discovery well at the southern end of the Windjammer/Lagosta/Barquentine/Camarao gas complex—encountered 525 net ft of natural gas pay. Anadarko (36.5%) is operator, with Mitsui E&P Mozambique Area 1 (20%), BPRL Ventures Mozambique (10%), Videocon Mozambique Rovuma 1 (10%), and Cove Energy (8.5%).
Coastal Energy announced a successful Miocene discovery in the Bua Ban South A-04 well, Gulf of Thailand. The well was drilled to a total vertical depth of 3,250 ft on the eastern flank fault block at Bua Ban South, about 1.5 miles south of the main Bau Ban Main A-11 well. The A-04 well encountered 42 ft of net pay in the Lower Miocene M75 and M100 sands with 29.5% average porosity. Coastal (100%) is operator.
China National Petroleum Corporation and Shell China Exploration and Production Company signed a production sharing contract (PSC) for shale gas exploration, development, and production in the Fushun-Yongchuan block in the Sichuan basin, China. Subject to government approval, this is the first shale gas PSC ever signed in China. The contract area covers approximately 3,500 km2.
Santos has found a new gas reservoir through the Sangu-11 well in the Sangu area, with about 66 ft of good quality gas pay. The well will be completed and tied into the Sangu facilities. Considered the first offshore gas field development in Bangladesh, the Sangu field is located in Block 16 in the Bay of Bengal about 28 miles southwest of Chittagong. Santos (75%) is operator with Halliburton (25%).
ConocoPhillips spudded the Boreas-1 well, located in permit WA-315-P in the Browse basin offshore Australia. The well is located on a large tilted fault block that is part of the northeast trending structural high of the greater Poseidon structure. The objective of the well is to test the extent, presence, and quality of reservoirs within the Boreas-1 fault block. ConocoPhillips (50%) operates the permit, while Karoon holds the remaining stake.
Eni commenced production from the Marulk field in the Norwegian North Sea. Marulk is part of the PL 122 license held by operator Eni (20%), with Statoil (50%) and Dong (30%). Marulk is a gas and condensate field with estimated reserves of 74.7 million BOE and produces 20,000 BOEPD.
Noreco commenced drilling at Exploration Well 7228/1-4 on the Eik prospect in Production License 396 in the Barents Sea. The well is being drilled by Transocean’s ultradeepwater semisubmersible the Transocean Barents. Noreco (50%) is operator, with Front Exploration (30%) and Petoro (20%).
Talisman Energy confirmed the presence of light oil at the Kurdamir-2 well in the Kurdistan region of northern Iraq. The well flowed at unstimulated rates of 7.3 MMcf/D of natural gas and 950 B/D of oil and condensate, with no indications of water and no observed decline. This openhole drillstem test was conducted only over the upper 180 ft of the Oligocene reservoir. A total of 459 ft of gross reservoir (289 net ft) was identified through wireline logging. Talisman (40%) is operator of the Kurdamir Block, with WesternZagros (40%) and the Kurdistan Regional Government (20% carried interest).
McMoRan completed technical work on the Davy Jones No. 1 well on South Marsh Island Block 230, US Gulf of Mexico (GOM), in 20 ft of water. The company expects the operations currently under way will enable a measurable flow rate during second-quarter 2012 followed by commercial production shortly thereafter. McMoRan (32.7%) operates the block, with PXP (27.7%), EXXI (15.8%), Nippon Oil (12%), W.A. “Tex” Moncrief Jr. (8.8%), and a private investor (3%).
Shell successfully drilled the northeast fault block of the Appomattox structure in the GOM. The company demonstrated contingent recoverable resources in the northeast block of approximately 215 million BOE, with a range of 120 million to 370 million BOE of light oil. Future planned appraisal drilling will further refine this range. Shell (80%) is operator, with Nexen (20%).
Petrobras announced a discovery, found while drilling Well 4-SPS-86B (4-BRSA-971-SPS), unofficially known as Carcará, 144 miles off the coast of São Paulo state. Sampling confirmed the presence of oil of approximately 31°API in reservoirs 18,865 ft deep. Petrobras (66%) is operator, with Petrogal Brasil (14%), Barra Energia do Brasil Petróleo e Gás Ltda. (10%), and Queiroz Galvão Exploração e Produção S.A. (10%).
The Ramiriqui-1 oil exploration well in the Llanos-22 block, located in the Andean foothills trend of the Llanos basin, Colombia, has reached total depth at 19,519 ft measured depth (MD). Initial testing has been completed on Ramiriqui-1, with 130 ft gross thickness in the Mirador formation, which was perforated and tested from 17,610 to 17,630 ft MD in the uppermost primary reservoir interval. The interval had natural flow rates of up to 2,525 BOPD gross over 32.5 hours with a 28/64-in. choke and a 0.12% water cut with 26°API oil. The Ramiriqui-1 well flowed at a restricted rate due to gas flaring limitations. Compania Espanola de Petroleos S.A.U. (55%) is operator, with Gran Tierra Energy (45%).