Production began from the PSVM development area of Block 31 offshore Angola. Initial volumes come from three wells in the Plutao field, targeting an initial 70,000 B/D of oil and a plateau rate of 150,000 B/D of oil this year. Sonangol EP (25%) is the concessionaire of the block operated by BP Exploration Angola (27.67%) in partnership with Sonangol P&P (20%), Statoil Angola (13.33%), Marathon International Petroleum Angola Block 31 (10%), and SSI 31 (5%).
Drilling began on the Semda 1 well in the Tajerouine production sharing license area of Tunisia. The prospect is 150 km southwest of Tunis, targeting primary objectives in the Cretaceous-aged Aptian Serdj Dolomites, the Barremian Bed Bars, and Sidi Aich Clastics, as well as deeper gas objectives. The planned depth is 3500 m. Oil Search Tunisia is the operator with a 100% interest.
Drilling began of the Spaoh-2 well in the Balai Cluster offshore Malaysia. It is the third well in the predevelopment appraisal program, with a target depth of 2710 m. The cluster comprises four fields: Balai, Bentara, West Acis, and Spaoh, and the operating consortium is BC Petroleum, consisting of ROC Oil (48%), Dialog Group (32%), and Petronas Carigali (20%).
The South Kecapi-1 well of the Bontang production sharing contract was completed offshore East Kalimantan, Indonesia. It is Salamander Energy’s first well in its multiwell North Kutei program. The well encountered 131 ft of net oil and gas pay in quality, stacked Pliocene channel sandstones. A drillstem test in Pliocene channel sandstone flowed light oil at 6,000 B/D and 8 MMsf/D of gas. Salamander owns 100% of the contract.
The Yulleroo 4 well in exploration permit 436 of Western Australia was the first drilled in the Buru Energy–Mitsubishi 2013 drilling program, 80 km east of Broome. It was cased to a measured depth of 888 m, with a total planned depth of 3800 m. Buru and Mitsubishi each have a 50% stake in both the well and the permit.
The Moonta 1 shale gas well in exploration license 218 in the Patchawarra formation of South Australia’s Cooper basin reached a maximum controlled flow rate of 2.6 MMsf/D, and is currently flowing at 1.6 MMsf/D through a 1.5-in. choke. The well was stimulated with a single stage in the uppermost part of the formation. The license is wholly owned and operated by Beach Energy.
Production has begun at the Valhall Redevelopment Project in the southern Norwegian North Sea, giving the field another 40-year design life with capacity to handle 120,000 B/D of oil and 143 MMsf/D of gas. The field is now fully powered from shore through a 294‑km direct current cable from the Lista field. BP Norway (35.9%) is the operator, partnered with Hess Norge (64.1%).
Production of 1.5 MMsf/D began at the Winna Gora gas facility in the 850,000‑acre Fences concession of Poland’s Permian basin. Polish Oil and Gas is drilling Mieczewo-1K exploratory well below 2000 m on the western part of the concession to test a Rotliegend structure at 3360 m. Polish O&G (51%) is the operator in partnership with FX Energy (49%).
The Kiyaktysai KN-E-201 well discovered oil at the Zharkamys West 1 Territory in Kazakhstan. The well encountered a 136-m stacked sand-shale interval while drilling to an intermediate casing setting depth of 1408 m. Wireline logs indicate the interval has 58 m of net hydrocarbon pay with a continuous 41-m light-oil column and a separate 17-m gas column. Condor Petroleum (100%) holds the exploration rights at Zharkamys.
Oil was discovered at the Rosa North IX well in the Meleiha concession of Egypt’s Western Desert. The well encountered a total oil pay of 80 m in multiple quality sandstones of the Bahariya, Alam El Bueib, Khatatba, and Ras Qattara reservoirs, and test flowed oil of 43 to 48 °API. Eni owns a 56% interest in the concession through its affiliate International Egyptian Oil Company (IEOC), in partnership with Lukoil (24%) and Mitsui (20%).
McMoRan Exploration set a production liner at the Blackbeard West-2 ultradeep well on Ship Shoal Block 188 in the Gulf of Mexico. The well was drilled to a total depth of 22,574 ft. Initial completion efforts are targeting 50 net ft of laminated sands in the Middle Miocene at 24,000 ft. McMoRan holds a 69.4% working interest in the block, partnered with EXXI (22.9%) and Moncrief Offshore (7.7%).
Incremental Oil and Gas spudded the Aurora 24-21 well in the Florence oil field in Colorado. The well is designed to target a seismically defined anomaly. The field is 100% owned by Incremental.
The PetroCarabobo joint venture in the Orinoco belt of Venezuela produced its first heavy oil from well CGO-0005, which is now flowing at about 350 BOPD. The well is projected to eventually yield 400,000 B/D of 8 °API oil, with an upgrader projected to yield 16 °API oil. The venture is controlled by Petroleo De Venezuela (60%) in partnership with Repsol YPF (11%), Petronas (11%), ONGC Videsh (11%), Indian Oil (3.5%), and Oil India (3.5%).
The Las Maracas-7 well in the Los Ocarros block of Colombia’s Llanos basin is now producing from the Basal Gacheta sand formation. The well struck potential net oil pay in the Mirador, Main Gacheta, and Basal Gacheta reservoirs. The Gacheta sands were production tested yielding maximum rates of 1,500 B/D and 2,050 B/D of oil for Main and Basal, respectively, and the interval produced 29 °API oil at a stabilized rate of 1,049 B/D. The operator of the block is Cepcolsa (50%) in partnership with Petroamerica Oil (50%).