Time-dependent pore-network modelling of Ostwald ripening in porous media

TL;DR

This paper introduces a dynamic pore-network model that simulates Ostwald ripening in porous media, capturing gas cluster evolution and trapping during fluid displacement processes relevant to subsurface storage.

Contribution

The model couples transient mass transfer, capillary heterogeneity, and realistic geometries to improve understanding of gas cluster dynamics during Ostwald ripening in porous rocks.

Findings

Model reproduces experimental displacement and cluster rearrangement.

Rapid initial decline in average cluster pressure observed.

Persistent gas trapping in larger pore spaces confirmed.

Abstract

We present a time-dependent pore-network model that couples transient mass transfer in the aqueous phase, capillary pressure heterogeneity, and realistic pore-throat geometries to capture the dynamic evolution of gas clusters during Ostwald ripening in porous media. The model is applied to Bentheimer sandstone to study Ostwald ripening after imbibition to residual gas saturation. Both imbibition (shrinkage) and drainage (growth) events occur as the local capillary pressure in trapped gas clusters approaches equilibrium. The model tracks event statistics, capillary pressure equilibration, cluster volume distributions, and spatial saturation profiles over 48 hours. While the volume-weighted average capillary pressure is constant, there is a rapid initial decline in average number-weighted cluster pressure and a shift in cluster size distributions toward fewer, larger ganglia, consistent with pore-scale imaging studies. Pore and throat occupancy analysis reveal persistent gas trapping in larger pore spaces. Since growth is by drainage, the pore-scale configuration of fluid is different from that predicted by an equilibrium percolation-without-trapping model that only allows imbibition events. The model reproduces displacement and ganglion rearrangement during time-limited laboratory experiments, and can then provide predictions of trapped saturation, relative permeability and capillary pressure under field-scale conditions with application to hydrogen, natural gas and carbon dioxide storage in the subsurface.