Total started production from the deepwater Dalia Phase 1A development, 135 km offshore Angola. The Dalia floating, production, storage, and offloading vessel came on stream in Block 17 in 2009 and is now expected to reach 200,000 B/D with the new development. The seven infill wells will contribute approximately 30,000 B/D to the block’s overall production. Total (40%) operates the block with partners Statoil (23.33%), Esso Exploration Angola Block 17 (20%), and BP Exploration Angola (16.67%).
China National Offshore Oil Co. (CNOOC) has started oil production at its Luda 10-1 comprehensive adjustment project in the Liaodong Bay of Bohai. The project called for the construction of one wellhead platform. The field has an average water depth of 30 m and has 13 wells on stream producing 3,300 BOPD. Luda 10-1 is expected to reach a peak production rate of 6,000 BOPD next year. CNOOC is the operator of the field and holds 100% interest.
Oil and Natural Gas Corp. (ONGC) has started oil production at the Mukta-B (MB) unmanned wellhead platform in the offshore Bombay basin. Pipelines leading to the MB and Mukta-A (MA) platforms were worked on as part of the project, enabling a restart of production from the MA platform, which had been shut in because of pipeline integrity issues for the past 2½ years. ONGC (40%), BG India (30%), and Reliance Industries (30%) share operatorship of the field.
Triple Energy spudded Niaoshan-1, the first of two wells planned for the Bird Mountain area of China’s Heilongjiang province. Located 2 km from the Xian Xian‑1 well drilled in 2013, Niaoshan-1 is targeting several major coal seams for coring and desorption analysis. The well will be drilled to a depth of 1300 m. Triple Energy (80%) is the operator with state-owned partner Longmay Coal Mining Co. (20%).
Origin Energy spudded the Kalala S-1 well in the Northern Territory’s Beetaloo basin, 500 km southeast of Darwin, Australia. The well is the first of three planned onshore wells to be drilled in the area and will target the Middle Velkerri formation to assess hydrocarbon saturation and reservoir quality. The well will be drilled to a total depth of approximately 2800 m. Origin (35%) is the operator with partners Sasol Petroleum Australia (35%) and Falcon Oil and Gas (30%).
Buru Energy has started its 2015 exploration program of the Ungani trend in Western Australia with the spudding of the Praslin 1 well. Located 15 km west of the company’s Ungani oil field, the well will reach a planned total depth of 2600 m. Target formations include the Ungani dolomite and Laurel clastic reservoirs and Devonian-aged carbonates. Buru (50%) is the operator with partner Mitsubishi (50%).
Statoil made a minor oil and gas discovery near the Gina Krog field in the North Sea, 250 km west of Stavanger. The find is estimated to contain between 1 and 2 MMscfe of recoverable oil equivalents in the Hugin formation. Statoil (58.7%) is the operator of the license with Total (30%), PGNiG (8%) and Det Norske (3.3%).
Iran has accelerated its development of the Azadegan oil field, which it shares with Iraq, in order to catch up with its western neighbor in production, said an Iranian energy official. The National Iranian Drilling Company has completed the drilling of six wells in the field since taking over from China National Petroleum Corp., which had its contract canceled last year because of repeated delays.
Eni discovered natural gas at the Nooros exploration prospect in the Abu Madi West license, 120 km northeast of Alexandria, Egypt. The Nidoco NW2 Dir NFW well reached a total depth of 3600 m and encountered a 60-m gas-bearing sandstone interval of Messianian age. The discovery will be put on production through a tie-in to the existing Abu Madi gas treatment plant, which is 25 km southeast of Nooros. Eni subsidiary Ieoc Production holds 75% working interest in the West Abu Madi development lease with partner BP (25%). Petrobel, which is equally owned by Ieoc and Egyptian General Petroleum Corp., is the operator of the concession.
Yuma Energy has completed and tested its Talbot 23-1 well in Jefferson Davis Parish, Louisiana. The well had an initial gross production rate of approximately 7 MMcf/D of gas and 180 B/D of 55 °API condensate through a 13/64-in. choke. It was perforated in a lower portion of the main Hackberry sand and has additional uphole Hackberry sand perforations in the main Hackberry section, and in the Marg-Tex sands. Yuma holds 45% interest in the block with an unnamed operator.
Eni started production from the Perla giant gas field located in the Gulf of Venezuela, 50 km offshore. Consisting of Mio-Oligocene carbonates with excellent characteristics, the reservoir is approximately 3000 m below sea level and lies at a water depth of 60 m. The best wells are estimated to produce more than 150 MMscf/D of gas each. The development plan includes 21 producing wells and four light offshore platforms linked by a 30-in. pipeline to a central processing facility in Punto Fijo on the Paraguaná Peninsula. Two treatment trains have been installed at the facility, each capable of handling 150 Mscf/D and 300 Mscf/D of natural gas. The field is operated by Cardón IV, a company jointly owned by Eni (50%) and Repsol (50%).
LGO Energy discovered the presence of hydrocarbons in the Goudron field onshore Trinidad. Well GY-675 was drilled to a total depth of approximately 3,660 ft and intersected an estimated 260 ft of net pay in the C-sand intervals, according to electric logs. The well has been cased for future production. LGO has also begun drilling nearby another well, which is targeting the C-sand interval and the top of the Gros Morne sandstone reservoir. LGO is the operator and holds 100% interest in the field.