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• W2283679507 abstract "Abstract We provide a comprehensive experimental study of steady state, drainage relative permeability curves with CO 2 ‐brine and N 2 ‐deionized water, on a single Bentheimer sandstone core with a simple two‐layer heterogeneity. We demonstrate that, if measured in the viscous limit, relative permeability is invariant with changing reservoir conditions, and is consistent with the continuum‐scale multiphase flow theory for water wet systems. Furthermore, we show that under capillary limited conditions, the CO 2 ‐brine system is very sensitive to heterogeneity in capillary pressure, and by performing core floods under capillary limited conditions, we produce effective relative permeability curves that are flow rate and fluid parameter dependent. We suggest that the major uncertainty in past observations of CO 2 ‐brine relative permeability curves is due to the interaction of CO 2 flow with pore space heterogeneity under capillary limited conditions and is not due to the effects of changing reservoir conditions. We show that the appropriate conditions for measuring intrinsic or effective relative permeability curves can be selected simply by scaling the driving force for flow by a quantification of capillary heterogeneity. Measuring one or two effective curves on a core with capillary heterogeneity that is representative of the reservoir will be sufficient for reservoir simulation." @default.
• W2283679507 created "2016-06-24" @default.
• W2283679507 creator A5061821949 @default.
• W2283679507 creator A5072227280 @default.
• W2283679507 date "2015-12-01" @default.
• W2283679507 modified "2023-10-14" @default.
• W2283679507 title "Characterizing flow behavior for gas injection: Relative permeability of CO₂‐brine and N₂‐water in heterogeneous rocks" @default.
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• W2283679507 doi "https://doi.org/10.1002/2015wr018046" @default.
• W2283679507 hasPublicationYear "2015" @default.
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