Onshore/Offshore Facilities
This work introduces a novel predictive methodology combining historical metocean data with real-time riser analysis for shallow water dynamically positioned rig operations.
This paper documents the testing, integration, and field deployment of a metal expandable packer used as an openhole toe isolation plug in a deepwater well under high-pressure, high-temperature conditions.
This paper presents an approach for safe, efficient, and cost-effective legacy well reabandonment.
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IOGP JIP33 plans to publish more than 30 specifications by the end of the year. -
The paper describes options for hydrate and integrity management and the required modifications to both subsea and topside facilities to enable an operational philosophy change.
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In 2015, the world’s first subsea multiphase gas compression system was installed offshore Norway. The system comprises two-off 5-MW machines configurable for serial or parallel compression. This system has now gained considerable and valuable operational experience.
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Both operational experience and studies of future offshore gas-field developments are showing that subsea gas-compression systems not only reduce investment costs but also increase recovery significantly.
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While it remains today only an idea, there are but a few barriers keeping an unmanned floater from being realized, according to one of the world’s leading offshore engineering firms.
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Often it is too difficult to create the fault conditions necessary for training a predictive maintenance algorithm on the actual machine. A digital twin generates simulated failure data, which can then be used to design a fault-detection algorithm.
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A multizone water-injection project has ultimately proved a method of using intelligent completion interval-control valves in place of traditional sand-control completions in soft sand reservoirs.
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Repair work on the Gorgon LNG plant’s propane heat exchangers is underway. Planned maintenance on the Gorgon Train 2 was expected to end in July.
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Production of paraffinic crude presents challenges due to depressurization and cooling of crude oil during production.
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The original technology selected in 2015 and 2016 for Rio Grande LNG has since evolved. With five trains instead of six, Rio Grande LNG will still produce 27 mtpa.
