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.
Bridging the gap between foundational guidance and real-world application, SPE’s Oil and Gas Reserves Committee is advancing PRMS education with a new, peer-reviewed training initiative. This article highlights the evolution of the PRMS knowledge base and introduces the PRMS Training Master Slides—a modular, instructor-led framework designed to improve consistency, cl…
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Recently, a lot of discussion has revolved around the benefits of multilaterals in unconventional reservoirs, but is it truly the next breakthrough for the industry, or is it all hype? -
A carbon-dioxide (CO2) -foam enhanced-oil-recovery (EOR) pilot research program has been initiated to advance the technology of CO2 foam for mobility control in a heterogeneous carbonate reservoir.
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This paper presents an analysis of a CO2-foam-injection pilot in the Salt Creek Field, Natrona County, Wyoming.
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In my previous features, I discussed the challenges facing carbon dioxide (CO2), both technical and economic. By far the biggest use of CO2 is in enhanced oil recovery (EOR). In this feature, the focus is on overcoming the biggest challenges facing CO2 EOR—gravity override and mobility.
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This paper presents a saturation-modeling approach for fields and reservoirs with complex hydrocarbon-charging histories. The model resolves saturation-height functions for the primary-drainage, imbibition, and secondary-drainage equilibriums.
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This paper proposes a novel work flow for structural-features modeling that allows the introduction of faults and other structural and nonstructural features to any simulation grid without modification.
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Natural fractures can have a significant effect on fluid flow by creating permeability anisotropy in hydrocarbon reservoirs.
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A radical digital revolution is happening all around us (or so we are told). Applying this to reservoir simulation, we apparently need to understand better when and, more importantly, when not to use such technology—to appreciate its bounds, its limitations, its range of validity, and so on.
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The Norwegian operator’s disclosure marks the first time all subsurface and production data from a field on the NCS will be available for public viewing.
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Acquiring data from an abandoned subsea well has been done before, but never quite like this.
