Reservoir
A report commissioned by Havtil, the Norwegian Ocean Industry Authority, calls for better dialogue regarding pore-pressure uncertainty and higher-end drilling techniques like managed pressure drilling as methods to reduce the risk of well-control events.
The events will be co-located 3–5 May 2027 at Reliant Park in Houston, Texas.
This work describes a study in which distributed data parallel training, paired with a node-local caching pipeline, enabled efficient multigraphics-processing-unit scaling for a CO₂-storage graph-neural-network surrogate while maintaining generalization.
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This paper presents results from the analysis of the effect of in-fill drilling on parent-well performance, and describes a simplistic approach to understanding the effect of the quest for operational efficiencies and economic cycles on development strategies. -
Reservoir-simulation-model inputs are numerous, and uncertainty is pervasive—before, during, and after development. With the pressure to deliver results quickly, how do we find the right balance?
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In upstream oil and gas, cloud computing is very immature because the industry has always been challenged by storage and computational capability. However, high-performance cloud computing may create an opportunity for smaller companies lacking infrastructure for scientific applications.
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There remain a number of challenges with CO2 EOR. These include gravity override, poor sweep efficiency, and economic factors.
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In this study, detailed petrophysical and geological field models focusing on the middle and lower members of the Bakken Formation were developed.
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Carbon dioxide (CO2)/water foams are of interest for mobility control in CO2 enhanced oil recovery (EOR) and as energized fracture fluids or as hybrid processes that combine aspects of both processes.
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Because the uncertainty analysis is complex and time consuming, in this paper, a stochastic representation of the computer model, called an emulator, was constructed to quantify the reduction in the parameter input space.
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With the easy conventional oil in Argentina having been produced, one remaining way to find new oil in existing fields is to convert fields from primary or secondary production to secondary or tertiary production, respectively.
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The low recovery rates observed in most shale reservoirs has prompted a number of research projects to develop new enhanced oil recovery methods.
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Part of what makes DME an intriguing EOR technology is that it is soluble in both water and oil—with a preference for the latter. Shell’s plan is to add DME to the waterflooding stream to reach a concentration of about 16%, the upper limit of its dissolvability.
