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In order to parameterize hydrodynamic models and optimize hydrocarbon production one needs to obtain as detailed information on flow properties of reservoir rocks as possible. The most critical petrophysical properties such as permeability are obtained from core measurements. Such core samples are usually subdrilled from full-size core material along a number of different directions, which not necessarily coincide with the directions of the major fluid filtration. It is believed that the most accurate data is obtained if subdrilling occurs parallel or perpendicular to bedding within the full-size core material. In this work we calculate the permeability tensor based on pore-scale flow simulations within pore geometries of the carbonate sample obtained using X-ray microtomography imaging. This allowed us to obtain the full tensor and flow directions without any sample orientation knowledge. The technique is promising for any petrophysical studies, as it allows to obtain tensorial petrophysical properties, and can be especially useful in case the original orientation of the core material is not known. We found the simulated permeability tensor to be highly non-symmetrical, which is in agreement with other published results and can be explained by the boundary conditions used for simulations. Additional research is needed to elucidate the influence of boundary conditions on the simulated permeability tensor.

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