Gas condensate reservoirs with a bottom-hole flowing pressure (BHFP) below the dew point pressure (DPP) suffer from productivity loss of both gas and condensate due to the accumulation of condensate in the near the wellbore. Methods used to restore the productivity, including solvent treatment and hydraulic fracturing, suffer from various limitations and may be effective only temporarily. A recently proposed method to restore well productivity in retrograde condensate wells is chemical wettability alteration in the near-wellbore zone using adsorbed polymers or surfactants. In this paper the gas condensate studies are critically reviewed and the potential of wettability alteration evaluated using reservoir simulations. Radial flow in a prototypical gas condensate reservoir is simulated using the compositional simulator GEM of the CMG suite. The simulations are done in two parts: first several years of production without chemical treatment are considered. Then a new relative permeability set is defined for the treated area around the wellbore. The modified relative permeabilities are developed based on existing experimental studies, by inserting new residual saturations in Honarpour's relative permeability model. A detailed discussion of the assumptions and limitations of this model is offered. The simulation is also run for three different permeabilities. High permeable rocks show smaller amount of condensate trapping in the models run. The flow rate is higher in treated reservoirs due to smaller residual liquid saturation.

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