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Publicado: 1 de julio de 2012
RESERVOIR IMPLICATIONS ON INJECTION CO2 ENHANCED OIL RECOVERY
Pressure
Geologically, reservoirs are physically huge in volume, well insulated from surface fluctuations in temperature andthus exhibit a constant temperature dictated by the local geothermal temperature gradient, nominally on the order of 1.5oF/100ft of depth, with some variation locale to locale.
Reservoir pressure, onthe other hand, is directly influenced by reservoir recovery practices. When hydrocarbons are withdrawn from a reservoir, it’s pressure declines. Depending on the results of the slim tube experimentsdescribed above, it is possible that reservoir pressure may be found to be below the MMP (Minimum Miscibility Pressure[->0]). If so, CO2 (Carbon Dioxide) can still be injected, but the efficiency ofthe recovery process is adversely impacted. Typically, this does not occur since, after primary depletion, water flooding operations commence which restore reservoir pressure to values above the MMP.CO2 Mobility and Reservoir Heterogeneity
In a CO2 EOR flood[->1], a variety of factors will influence process performance. Because the viscosity of CO2 at reservoir conditions is much lower than thatof most oils, viscous instability will limit the sweep efficiency of the displacement and, therefore, oil recovery. In addition, reservoir rock is extremely heterogeneous, exhibiting zones of highpermeability in close proximity to those of low permeability. These permeability differences may be innate, that is caused by differences in pore structure at the time of geological deposition, or aproduct of fractures, natural or man-made.
CO2 dispersion in reservoir
Reservoir heterogeneity and the adverse effects of CO2 viscosity must be contended with to optimize oil recovery. Two basicstrategies have been developed by the petroleum industry to cope with these conditions, namely:
1. Alternately inject cycles of CO2 and water in the so called WAG (water alternating gas) process. This...
Pressure
Geologically, reservoirs are physically huge in volume, well insulated from surface fluctuations in temperature andthus exhibit a constant temperature dictated by the local geothermal temperature gradient, nominally on the order of 1.5oF/100ft of depth, with some variation locale to locale.
Reservoir pressure, onthe other hand, is directly influenced by reservoir recovery practices. When hydrocarbons are withdrawn from a reservoir, it’s pressure declines. Depending on the results of the slim tube experimentsdescribed above, it is possible that reservoir pressure may be found to be below the MMP (Minimum Miscibility Pressure[->0]). If so, CO2 (Carbon Dioxide) can still be injected, but the efficiency ofthe recovery process is adversely impacted. Typically, this does not occur since, after primary depletion, water flooding operations commence which restore reservoir pressure to values above the MMP.CO2 Mobility and Reservoir Heterogeneity
In a CO2 EOR flood[->1], a variety of factors will influence process performance. Because the viscosity of CO2 at reservoir conditions is much lower than thatof most oils, viscous instability will limit the sweep efficiency of the displacement and, therefore, oil recovery. In addition, reservoir rock is extremely heterogeneous, exhibiting zones of highpermeability in close proximity to those of low permeability. These permeability differences may be innate, that is caused by differences in pore structure at the time of geological deposition, or aproduct of fractures, natural or man-made.
CO2 dispersion in reservoir
Reservoir heterogeneity and the adverse effects of CO2 viscosity must be contended with to optimize oil recovery. Two basicstrategies have been developed by the petroleum industry to cope with these conditions, namely:
1. Alternately inject cycles of CO2 and water in the so called WAG (water alternating gas) process. This...
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