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Potential suitors to acquire Chevron’s stake in the LNG project include co-owner and operator Woodside. This contract is for the development of the Lambert Deep and Phase 3 offshore Northwest Australia. The company announced both contract awards simultaneously. The new contract awards could be worth up to $800 million. The Australian company upped its forecast of initial oil production out of the field from 50,000 B/D to somewhere between 75,000 and 100,000 B/D.
Armada to install ROV launch and recovery system on its fleet of robotic ships. Delivery of the umbilicals is expected in Q4 2021. The King’s Quay FPS achieved FID in Q2 2019, and is expected to process up to 80,000 B/D of crude oil with first production in 2022. WFS Technologies’ collaboration is its second in as many months supporting its Seatooth technologies. Petrofac’s well management contract comes nearly a month after IOG received approval for phase 1. The contract also follows an EPC contract awarded to Subsea 7 in May.
The Hydrogen Offshore Production project identifies an alternative to decommissioning by providing reuse options for offshore infrastructure. It aims to prove the feasibility of decentralized hydrogen generation, storage, and distribution solutions to provide a bulk hydrogen solution. If we must reduce emissions to make our industry “greener,” what are some of the options that we can apply? Most crude exports coming out of the North Sea since March have been destined for Asia, where floating storage levels remain high. The inspection projects to assess water ingress will be done via remotely operated vehicle.
Each module has a duration of two days with emphasis on different aspects of reservoir characterisation, the ultimate goal being the preparation of optimal formation and rock property data from core analysis and other data sources for the purpose of static geological modelling and dynamic reservoir simulation. Seminar style lectures are typically given each morning and participants put their learning into practice in the afternoons, utilising real field data (including their own if desired). For this purpose, specialised spreadsheets are utilised. "Intelligent" spreadsheets will be made available to course participants for their use in practical exercises – putting theory into practice. Course participants may also bring their own data, which they may use with the spreadsheets.
This course on Gas Field Development Planning: Offshore Projects covers significant gas projects dealing with the three key physical elements: reservoir, wells and facilities. The first day emphasises geoscience and subsurface aspects, including wells; while the second day considers projects more from a macro-point of view, including commercial, project management and facilities concepts. This course will give participants an understanding of all major aspects of gas field development planning and project management. The course is illustrated by a series of case histories and examples that demonstrate novel solutions to various project challenges. Participants will also be involved in two group exercises followed by discussions.
With contracts canceled and pressures mounting, offshore oil drillers struggle to stay afloat. With contracts canceled and pressures mounting, offshore oil drillers struggle to stay afloat. Wind turbine substructures and anchors made of special concrete would float to a site from an onshore plant. The AI-driven tool will detect anomalies in subsea oil and gas infrastructure. The hunt for global alternatives to store crude oil includes offshore, global strategic reserves, pipelines, rail cars, and trucks.
Africa (Sub-Sahara) An initial drillstem test on the Mzia-2 well in Block 1 flowed at a maximum rate of 57 million ft3 of gas per day, increasing the estimated recoverable resources from the field to 4.5 trillion ft3. This is the first test carried out on a Cretaceous discovery in deepwater offshore Tanzania. BG (60%) is the operator in partnership with Ophir Energy (40%). Asia Pacific Production has begun from the Wei Zhou 6-12 oil field in the Beibu Gulf basin in the north part of the South China Sea. The project has 10 producing wells drilled at an average water depth of 29.2 m. CNOOC has a 51% operating interest in partnership with Roc Oil, Horizon Oil, and Oil Australia. Salamander Energy signed production-sharing contracts for the Northeast Bangkanai and West Bangkanai license areas, onshore central Kalimantan in Indonesia. Each area covers approximately 2,214 sq miles.
Africa (Sub-Sahara) Sahara Group discovered hydrocarbons in three wells drilled in Block OPL 274, located onshore in Nigeria's Edo State. Olugei-1 was drilled to a measured depth of 4537 m and encountered five hydrocarbon zones, with 33 m of net pay. Oki-Oziengbe South 4 was drilled to a measured depth of 3816 m and encountered 64.3 m of net pay in 13 hydrocarbon-bearing zones. Oki-Oziengbe South 5 was drilled to a measured depth of 3923 m and encountered 91 m of net pay in 19 reservoirs. Sahara Group (100%) is the operator. Asia Pacific Sino Gas & Energy Holdings (SGE) flowed gas (coalbed methane) from its first horizontal well in the Linxing production sharing contract (PSC) in China's Shanxi province.
Africa (Sub-Sahara) Vaalco Energy started oil production from the Etame 12-H development well offshore Gabon. The well was drilled to a measured depth of approximately 3450 m and was targeting the recently discovered lower lobe of the Gamba reservoir. It was brought on line at a rate of 2,000 BOPD with no indication of hydrogen sulfide. Vaalco (28.07%) is the operator with partners Addax Petroleum (31.63%), Sasol (27.75%), Asia Pacific KrisEnergy started drilling the Rossukon-2 exploration well on Block G6/48 in the Gulf of Thailand, using the Key Gibraltar jackup rig. The well will reach a total depth at 5,462 ft and will test Early Miocene stacked fluvial sandstones on a broad structural high. The well will also appraise the Rossukon-1 reservoir, which produced 850 BOPD during tests.
Africa (Sub-Sahara) Sound Energy identified significant gas shows at the first Tendrara well onshore Morocco. Drilled to a 2665-m measured vertical depth, the well hit a total gross pay interval of 89 m of gas. The full set of well logs are being processed before the startup of rigless mechanical reservoir stimulation operations, which will be followed by a well test. The company is the operator of the well with a 55% working interest. Office National de HydroCarbures et des Mines (25%) and (20%) are the other participants. Petroceltic reported that the AT-13 well in Algeria has penetrated a 240-ft gas- and condensate-bearing formation. The well will help establish and maintain the approved annual average wet gas plateau rate of 355 MMcf/D from the Ain Tsila field.