  Liquid dropout and retention in gas-condensate reservoirs, specially in the
near wellbore region, obstruct gas flowing paths and impact negatively the
produced fluid volume and composition. Yet, condensate banking forecasting is
commonly inaccurate, as experiments seldom reproduce reservoir extreme
conditions and complex fluid composition, while most pore-scale models
oversimplify the physics of phase transitions between gas and condensate. To
address this gap, a fully implicit isothermal compositional pore-network model
for gas and condensate flow is presented. The proposed pore-networks consist of
3D structures of pores connected by constricted circular capillaries. Hydraulic
conductances are calculated for the capillaries, which can exhibit single-phase
flow or two-phase annular flow, according to local gas and liquid saturations,
or be blocked by a liquid bridge, when capillary forces overcome viscous
forces. A PT-flash based on the Peng-Robinson EoS is performed at control
volumes defined for the pores at each time step, updating the phases
properties. Flow analyses were carried based on coreflooding experiments
reported in the literature, with matching fluid composition and flow
conditions, and approximated pore-space geometry. Predicted and measured
relative permeability curves showed good quantitative agreement, for two values
of interfacial tension and three values of gas flow velocity.
