DigiM two-phase and three-phase relative permeability computations are (to our knowledge) the first on tight rocks, cross-validated comprehensively on Niobrara and Bakken formations. It is actively used in guiding the reservoir models for both drilling and recovery estimation purposes.
Our computation is based on direct computational fluid dynamic simulation, not pore network models. Aside from the algorithmic barrier that we break, our relative perm calculations are fast. We are talking about a few weeks, not months to years. For special cases, we can obtain the first set of relative perm within the same week after we receive the sample.
Here is an example of two-phase pore flow in Berea Sandstone (YouTube movie).
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Application of integrated core and 3D image rock physics to characterize Niobrara chalk porosity, permeability, capillary pressure, and two- and three-phase relative permeability. Accepted to present and publish by URTec 2017. (Request a Copy)