https://cyberleninka.org/article/n/22310.pdf

Pore-scale imaging and modelling

/pdf/high-resolution-x-ray-computed-tomography-in-geosciences-a-3sj7249knj.pdf

High-resolution X-ray computed tomography in geosciences: A review of the current technology and applications

http://research.engr.oregonstate.edu/immiscibles/sites/research.engr.oregonstate.edu.immiscibles/files/Papers/Wildenschild_Sheppard_AWR_2012.pdf

X-ray imaging and analysis techniques for quantifying pore-scale structure and processes in subsurface porous medium systems

In the last 3 years there has been a huge increase in the use of pore-scale modeling to study multiphase flow and transport in porous media. Starting from single pore models of fluid arrangements, computations of relative permeability, interfacial area, dissolution rate and many other physical properties have been made. Combined with a realistic description of the pore space, predictive modeling of a variety of processes, including waterflood relative permeability and mass transfer coefficients, is now possible. This review highlights some of the major advances, with an emphasis on models of wettability and three-phase flow.

Flow in porous media — pore-network models and multiphase flow

Detailed physics, predictive capabilities and macroscopic consequences for pore-network models of multiphase flow.

Transient performance of catalytic combustors for gas turbine applications

/pdf/spontaneous-imbibition-in-small-cores-27moh7uq48.pdf

Spontaneous Imbibition in Small Cores

Archie's exponents in complex lithologies derived from 3D digital core analysis

Image-based computations of relative permeability for capillary-dominated quasi-static displacements require a realistic description of the distribution of the fluids in the pore space. The fluid distributions are usually computed directly on the imaged pore space or on simplified representations of the pore space extracted from the images using a wide variety of models which capture the physics of pore-scale displacements. Currently this is only possible for uniform strongly wetting conditions where fluid–fluid and rock–fluid interactions at the pore-scale can be modelled with a degree of certainty. Recent advances in imaging technologies which make it possible to visualize the actual fluid distributions in the pore space have the potential to overcome this limitation by allowing relative permeabilities to be computed directly from the imaged fluid distributions. The present study explores the feasibility of doing this by comparing laboratory measured capillary-dominated drainage relative permeabilities with relative permeabilities computed from micro-CT images of the actual fluid distributions in the same rock. The agreement between the measurements and the fluid image-based computations is encouraging. The paper highlights a number of experimental difficulties encountered in the study which should serve as a useful guide for the design of future studies.

Wolf Val Pinczewski

Papers

Transient performance of catalytic combustors for gas turbine applications

Spontaneous Imbibition in Small Cores

Archie's exponents in complex lithologies derived from 3D digital core analysis

Computation of Relative Permeability from Imaged Fluid Distributions at the Pore Scale

Pore Scale Characterisation of Carbonates Using X-ray Microtomography