Drilling began on the Bamboo-1 well, located around 35 miles offshore Cameroon in the Ntem concession. The Bamboo prospect is a basin floor fan target within an Upper Cretaceous play. The well will be drilled to an estimated depth of 4200 m. Murphy Cameroon (50%) is the operator, with partner Sterling (50%).
The Nene Marine 3 exploration well—located in the Marine XII block, which is around 17 km offshore Congo—encountered a wet gas and light oil accumulation in a presalt clastic sequence. Eni (65%) operates the Marine XII block, with partners New Age (25%) and Société Nationale des Pétroles du Congo (10%).
China National Petroleum Corporation (CNPC) stated on its website that its subsidiary, PetroChina, discovered gas in the Moxi block of An’yue field, located in the Sichuan basin, China. CNPC said PetroChina is now building a production facility capable of pumping 4 Bcm/yr. No cost or timeline was given for the development.
KrisEnergy announced the acquisition of 1300 km of 2D seismic data in the East Muriah production sharing contract (PSC) in the East Java Sea, Indonesia. KrisEnergy (50%) operates the East Muriah PSC, with partner AWE (50%).
Drilling began on the Balqis-01 exploration well in the Baronang PSC, Natuna Sea, Indonesia. The main objectives of the well are the Oligocene fluvial sandstone reservoirs in stacked four-way dip closures. Lundin Petroleum estimates the Balqis prospect potentially contains unrisked, gross, prospective resources of 47 MMboe. Lundin, through its wholly owned subsidiary Lundin Baronang (90%), is the operator, with partner Nido Petroleum (10%).
Gas and condensate were discovered at the Ayesha-1 exploration well in the Badin IV South block in Pakistan. During testing, gas flowed at a rate of 11.34 MMcf/D through a 32/64-in. choke. Petroleum Exploration (47.5%) is the operator, with partners Jura Energy (27.5%) and Gulf Petroleum Exploration (25%).
Natural gas production has begun at the Damar field off the east coast of Peninsular Malaysia. ExxonMobil estimates field peak capacity at 200 MMcf/D of gas. ExxonMobil Exploration and Production Malaysia (50%), a subsidiary of ExxonMobil, is the operator, with partner Petronas Carigali (50%).
Drilling began on the Etty-1 well in ATP 855 in the Cooper-Eromanga basin, Queensland, Australia. The well, with a target depth of 3800 m, will further evaluate the basin-centered gas play in the Queensland portion of the Nappamerri trough. Beach Energy (46.9%) is the operator, with partners Icon Energy (35.1%) and Chevron Australia Exploration (18%).
The Caravel-1 exploration well was spudded in the Canterbury basin off the southeastern coast of New Zealand. The well has a target total depth of 2800 m in a water depth of 1105 m. Anadarko New Zealand (45%) is the operator, with partners Origin Energy (45%) and Discover Exploration Canterbury (10%).
Drilling began on the Pateke-4H development well, located in a water depth of 124 m in the offshore Taranaki basin, New Zealand. The well, with a planned total measured depth of 5361 m (including a 1272-m horizontal section), is targeting a mapped northern extension of the currently producing Pateke field. AWE (57.5%) is the operator, with partners New Zealand Oil & Gas (27.5%) and Pan Pacific Petroleum (15%).
From core samples, Det norske oljeselskap identified hydrocarbon shows in exploration well 7222/11-2 on the Langlitinden prospect in the Barents Sea. Det norske (20%) is the operator of Norwegian production license (PL) 659, with partners Petoro (30%), Lundin Norway (20%), Tullow Oil (15%), Atlantic Petroleum (10%), and Rocksource Exploration Norway (5%).
Norway will offer a proposed total of 61 blocks for oil and gas exploration in the 23rd licensing round for its continental shelf. Norway’s proposal includes 34 blocks in the southeast Barents Sea, 20 in the southern Barents Sea, and 7 in the Norwegian Sea.
Oil was discovered at the 25/5-9 wildcat well, located about 10 km east of the Heimdal field in the central North Sea. The well, targeting hydrocarbons in Paleocene reservoir rocks known as the Trell prospect, encountered a 21-m gross oil column of which 19 m were of good reservoir quality. Total (40%) is the operator of PL 102 F, with partners Petoro (30%), Lotos Exploration and Production Norge (10%), Det norske oljeselskap (10%), and Ithaca (10%).
The B4EW6 exploration well, drilled onshore Oman, has tested flows from the Lower Buah formation in excess of 2,200 BOPD on a 32/64-in. choke. CC Energy Development (50%) is the operator, with partners Tethys Oil Block 3 and 4 (30%) and Mitsui E&P Middle East (20%).
The SAGW-10 appraisal well in the Sagiz West field in Kazakhstan reached a depth of 1400 m, with electric logs indicating 52 ft of net oil pay over a 78-ft gross interval in the Triassic formation at vertical depths between 1225 m and 1249 m. Max Petroleum is the operator.
An 84-ft net oil column was encountered in the development section of the deepwater Cardona MC 29 #4 well, located in Mississippi Canyon 29 in the US Gulf of Mexico. Stone Energy (65%) is the operator, with partner Hunt Oil (35%).
Production began at the deepwater 9-SPS-77 well, located in the Sapinhoá field, Block BM-S-9, in the Santos basin presalt area offshore Brazil. The well, which is producing 33,000 BOPD, is connected to the floating production, storage, and offloading unit Cidade de São Paulo. Petrobras (45%) is the operator, with partners BG E&P Brasil (30%) and Repsol Sinopec Brasil (25%).