Offshore/subsea systems
This paper reviews best practices and learnings from floating-production-unit transportation and installation, hookup, and commissioning and discusses subsea flowlines, export pipelines, and subsea-equipment installations.
This paper addresses how close collaboration has enabled the development of a robust and cost-efficient solution for the Ormen Lange project by using carefully selected technology elements and an accelerated qualification process to mature them.
With the right infrastructure and interoperability, subsea resident robotics could unlock more frequent, cost-effective inspections—and a new standard for offshore efficiency.
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Emerging solutions could solve current subsea pain points, while a new taxonomy system could clarify the capabilities of the expanding domain of underwater vehicles. -
This paper discusses the journey of the Bonga North project, highlighting challenges and resolution strategies in a constantly changing deepwater environment.
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The Begonia and CLOV Phase 3 subsea tiebacks are each sending production to nearby FPSOs.
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Shell became the first international company to operate producing fields offshore Brazil and the first to navigate the country’s complex and detailed decommissioning permitting process, which involved extensive environmental assessments, regulatory approvals, and coordinated stakeholder engagement.
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North Sea tieback to the Troll C platform could begin production by the end of 2029.
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The field, which holds the first production license on the Norwegian Continental Shelf, sent oil to the Jotun FPSO on 23 June.
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Less than 3 months after going onstream, the Barents Sea project, the northernmost production offshore Norway, is producing 220,000 B/D.
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The company has installed an autonomous drone system on Aker BP’s Edvard Grieg platform in the North Sea, enabling frequent, remote inspections from shore.
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Updates about global exploration and production activities and developments.
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Once labeled “undrillable,” Brazil’s heavy-oil Atlanta field in the Santos Basin faced technical, financial, and logistical challenges. But through a phased approach, clever reuse of assets, and disciplined project execution, Brava Energia transformed a risky deepwater asset into a producing field with 172 million BOE in 2P reserves.
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