An agreement was reached for the separate yet coordinated development of gas reservoirs on Mozambique’s Anadarko-operated Offshore Area 1 and Eni-operated Offshore Area 4, including the joint planning and construction of common onshore gas liquefaction facilities in the Cabo Delgado Province of northern Mozambique. Partners in Area 1 are Anadarko (36.5%), Mitsui E&P Mozambique (20%), BPRL Ventures Mozambique (10%), Videocon Mozambique Rovuma I (10%), and PTT E&P (8.5%); Empresa’s Nacional de Hidrocarbonetos’ (ENH) 15% is carried through the exploration phase. Partners in Area 2 are Eni (70%), GalpEnergia (10%), Korea Gas (10%), and ENH (10% carried through exploration phase).
Chariot Oil and Gas completed 3500 km2 of 3D seismic in Block C19 offshore Mauritania. The survey was carried out by Fugro-Geoteam, targeting an area in the block’s southwest section. Chariot (90%) is the operator, with Mauritania-owned Société Mauritanienne de Hydrocarbures (10%).
The Balai-2 well, located in the Balai Cluster Risk Service Contract offshore Malaysia, reached total depth of 2266 m, striking 87 m of net pay in multiple sandstone and limestone zones. The Balai Cluster consists of the Balai, Bentara, West Acis, and Spaoh fields. The well is operated by the BC Petroleum joint venture, comprising operator ROC Oil (48%), Dialog Group (32%), and Petronas Carigali (20%).
Chevron China Energy entered into a production sharing contract with China National Offshore Oil Corporation for two shallow-water exploration blocks covering 5782 km2 in the South China Sea’s Pearl River Mouth Basin. Chevron (100%) is the operator of blocks 15/10 and 15/28 during the exploration phase.
The Mira 2 well at the ATP 337P Mahalo asset was spudded by Comet Ridge in the Bowen Basin of central Queensland. It is the central well in the project and the last of four pilot wells to be drilled in the field, which is about 250 km west of Gladstone. The well is expected to reach a total depth of 310 m, and is about 290 m away from the other three recently drilled wells. Comet Ridge Mahalo (35%) is operator, with Stanwell (5%), Australia Pacific LNG (30%), and Santos QNT (30%).
The Pinhoe-1 exploration well struck about 60 m of net gas pay in the Barrow and Mungaroo Sands in the Carnarvon Basin, about 200 km north of Exmouth off the coast of Western Australia. The well was drilled in the WA-383-P permit area, in 929 m of water to a total depth of 4083 m. Chevron Australia (50%) is the operator, with Shell Development Australia (50%).
First oil was achieved from the 211/22a Contender block of the Cormorant East field in the northern North Sea. Initial production rate is about 5,500 BOPD with no water. TAQA Bratani (60%) operates the block, with Dana Petroleum (20%), Antrim Energy (8.4%), First Oil Expro (7.6%), and Bridge Energy Enterprises (4%).
Canada’s Lundin Petroleum spudded exploration well 8/5-1 in PL453S, targeting the Ogna prospect about 65 km from the Ula field offshore Norway in the North Sea. The well’s main objective is to prove the presence of hydrocarbons in the Upper to Middle Jurassic reservoirs. Lundin (35%) is the operator, with Det Norske Oljeselskap (25%), Noreco (25%), and VNG Norge (15%).
Drilling commenced at the initial exploration well, Giremir-1, on the Sinan license in Turkey. The well will be drilled to a depth of 1250 m, at its deepest point reaching the Upper Sinan formation. Turkish Petroleum (50%) is the operator, with Anatolia Energy partner Calik Enerji (50%).
The Taza 1 ST1 well on the Taza prospect in Iraqi Kurdistan reached a depth of 3238 m, and drilling continues into the Euphrates formation. The primary objectives are the Miocene and Oligocene carbonates of the Jeribe and Euphrates formations. The prospect is 80 km southwest of Sulaymaniyah. Well participants are operator Oil Search Iraq (60%), Total E&P Kurdistan Region of Iraq (20%), and the Kurdistan Regional Government (20%).
Buccaneer Energy’s Kenai Loop 4 well on the east side of Alaska’s Cook Inlet tested gas to the surface at 3 million ft3/D on a 12/64-in. choke at a flowing tubing pressure of 3,365 psi with no water detected. A 10-ft section of the uppermost sand at the 10,300-ft measured depth was perforated, and the sand correlates to the 9,700-ft sand in the Kenai Loop 1 well. The well flowed uninterrupted for 24 hours before being shut-in to conduct a second pressure buildup test. Gas was flared at the location. Buccanner is the operator (100%).
Miller Energy Resources tested the CPP-H-1 well in Tennessee at a restricted rate of 487 BOED on a ¾-in. choke. The initial production test comprised 365 B/D oil, 730 million ft3/D gas, with no produced water. The well is in the Mississippian Fort Payne limestone, and the lateral exposed 2,300 ft of pay zone. The well is expected to produce up to 225 BOE/D after reinjection is begun. Miller also recently spudded its second Fort Payne well.
Petrobras started commercial production at well 1-SPS-55 in the Sapinhoá field, located on Block BM-S-9 in the Santos Basin pre-salt. Production is through the floating production, storage, and offloading platform Cidade de São Paulo. The block is operated by Petrobras (45%), with BG E&P Brasil (30%) and Repsol Sinopec Brasil (25%).
Gran Tierra Energy’s PMN-117 horizontal well in the Loma Montosa reservoir of the Puesto Morales Block in Argentina’s Neuquen Basin is currently flowing naturally at a choke-restricted rate of 212 B/D of 33.8 °API oil with 0% water cut. The initial flow test was 840 B/D of oil. The well reached a total depth of about 2130 m, with a true vertical depth of 1408 m, with a 483-m horizontal section and multistage fracture stimulation. Gran Tierra (100%) is the operator.