Pore-scale analysis of gas injection in gas-condensate reservoirs

Condensate banking around wellbores can significantly shorten the production from gas-condensate reservoirs. Several approaches to mitigate this issue have been proposed in literature, among which gas injection comes out with promising results. This method’s efficiency has largely investigated at core and field scales, but underlying flow phenomena taking place pore-scale are still poorly understood. In order address gap, a compositional pore-network model was used reproduce sandstone sample following condensate accumulation. C1, C2, CO2, N2 produced were tested as candidates for remediation different pressure levels. After flooding, saturation, heavy component recovery relative permeability quantified appraise achieved improvement. The results indicated that C2 CO2 were, overall, most effective gases clear accumulated re-establish flow. At high pressures, their reduced liquid saturation porous medium least 80%, restored permeabilities values close unity. low however, no composition could reduce content more than 30%, contradicting estimates based solely on dropout curves. With presented analyses, work sets pioneer efforts towards an accurate modeling of miscible