Eni started production from the Nené Marine field, which sits in the Marine XII block in 28 m of water, 17 km offshore the Republic of the Congo. The first phase of the field produces from the Djeno pre-salt formation, 2.5 km below the ocean floor at a rate of 7,500 BOEPD. Future development will take place in several stages and will involve the installation of more production platforms and the drilling of at least 30 wells. Eni (65%) is the operator with partners New Age (25%), and Société Nationale des Pétroles du Congo (10%).
Cooper Energy spudded the vertical, onshore Bunian-3 well in Indonesia’s Sukananti license. The well’s primary target is the Bunian structure: a four-way, fault-bounded anticline, which was defined by a 3D seismic survey. It will be drilled to a total depth of 1682 m. Cooper (55%) operates the license with partner Mega Adhyaksa Pratama Sukananti (45%).
Senex Energy drilled the Sheerkhan-1 exploration well on PEL 182 in Australia’s south Cooper-Eromanga basin to a total depth of 7,720 ft and encountered good oil shows in the Birkhead formation. The well will be plugged and abandoned. Senex (57%) is the operator with partner Drillsearch Energy (43%).
Lundin Norway began production from the Brynhild field, which is located on PL 148 in the Norwegian sector of the North Sea. The field flows more than 12,000 BOPD and is connected by subsea tieback to the Pierce field, which lies in the UK sector of the North Sea and is operated by Enterprise Oil. Both fields are being serviced by the Haewene Brim floating production, storage, and offloading vessel. Lundin (90%) operates Brynhild with partner Talisman Energy Norge (10%).
Statoil’s 30/11-10 well encountered an 80-m oil column in the Tabert formation and a 20-m oil column in the Etive formation at the Krafla North prospect on PL 035 in Block 30/11 in the North Sea. The well was drilled in 105 m of water to a total depth of 4054 m below sea level and was completed in the Dunlin group. Movable hydrocarbons were also encountered in the Ness formation, which was a secondary target. Statoil (50%) operates the block with partners Det Norske (25%) and Svenska Exploration (25%).
Total started gas and condensate production from the West Franklin Phase 2 project in the Central Graben area of the UK North Sea. The project includes the drilling of three new production wells and the installation of two new platforms. West Franklin will supply as much as 40,000 BOEPD to the Elgin/Franklin hub at peak production. Total (46.2%) is the operator, with partners Eni (21.9%), the BG Group (14.1%), E.ON (5.2%), ExxonMobil (4.3%), Chevron (3.9%), Summit (2.2%), and Dyas (2.2%).
ConocoPhillips’ Eldfisk II project was brought on stream in the Norwegian North Sea. The development program includes plans for 40 new production and injection wells and is intended to improve recovery at the aging Eldfisk field, which has been producing since 1979. Eldfisk II, along with Ekofisk South and other projects offshore Norway, are expected to add approximately 60,000 BOEPD to the company’s production by 2017. ConocoPhillips (35.1%) is the operator with partners Total (39.9%), Eni (12.4%), Statoil (7.6%), and Petoro (5%).
Exxon Neftegas began producing oil from the Sakhalin-1 project’s Arkutun-Dagi field, located off the east-northeast coast of Sakhalin Island, offshore eastern Russia. Peak production is expected to reach 90,000 BOPD. Oil is being routed through the Chayvo onshore processing facility on the island and delivered by pipelines to the De-Kastri export terminal in Khabarovsk Krai, Russia. Exxon Neftegas (30%) operates the consortium with partners Sakhalin Oil and Gas Development (30%), RN-Astra (8.5%), Sakhalinmorneftegas-Shelf (11.5%), and OGNC Videsh (20%).
Kuwait Energy made a second discovery in Block 9 in northern Basra, Iraq, with its Faihaa-1 exploration well. Preliminary tests of the Yamama formation, located at a depth of 4000 m, showed flow rates of 5,000 and 8,000 B/D of 35 °API gravity oil, through 32/64-in. and 64/64-in. chokes, respectively. Kuwait (70%) is the operator with partner Dragon Oil (30%).
Chevron discovered oil at the Anchor prospect in the US Gulf of Mexico (GOM), 140 km offshore Louisiana. Drilled to a total depth of 33,794 ft in 5,183 ft of water, Well No. 2 in Green Canyon Block 807 encountered oil pay in multiple Lower Tertiary Wilcox Sands intervals. Anchor is Chevron’s second deepwater discovery in the GOM in less than a year. Chevron (55%) is the operator with partners Cobalt International Energy (20%), Samson Offshore Anchor (12.5%), and Venari Resources (12.5%).
Anadarko started production of oil and gas from the deepwater Lucius field in the GOM’s Keathley Canyon Block 875. Production from the field is processed by the Lucius truss spar, which has the capacity to handle 80,000 B/D of oil and 450 Mcf/D of natural gas. Anadarko (27.8%) is the operator with partners Plains Exploration and Production (23.3%), ExxonMobil (15%), Apache (11.7%), Petrobas (9.6%), Teikoku Oil (7.2%), and Eni (5.4%).
Petrobras confirmed the commercial potential of three fields in the Iara area of the Santos basin, 250 km offshore Rio de Janeiro, Brazil. The area lies in 2270 m of water and contains good quality oil of 24 °API to 30 °API gravity. The fields have been named Berbigão, Sururu, and Atapú West and will be subject to unitization agreements. Petrobras (65%) operates BM-S-11 with partners BG Group (25%) and Petrogal (10%).
Pacific Stratus Energy Colombia finished a production test of the Langur-1X well on Block LLA19, in Colombia’s Llanos basin. The well flowed 24 °API gravity crude oil for 24 hours at a stabilized rate of 760 B/D, with a 27% water cut. After an initial test, the well was fitted with an electrical submersible pump and is expected to flow at rates in excess of 1,000 BOPD during an extended production test. Pacific (50%) is the operator with state-owned partner ANH (50%).