Fluid flow modelling is becoming increasingly more useful for elucidating exploration decision problems when hydrocarbon migration is one of the major uncertainties. Due to technology limitations, e.g. the speed and memory of existing computers, case studies that are routinely performed in the industry are usually quite limited in the spatial and temporal resolution of the models. We will in the following discuss inaccuracies in the present use of multiphase fluid flow models with respect to secondary migration. The industry's use of these models may easily result in errors in migration velocities, the hydrocarbon saturation during migration, and thus amounts of oil and gas trapped. We propose improvements to the techniques that can be incorporated into the fluid flow models and required improvements that explorationists should make before using existing programs.


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