Determination of Capillary Pressures and Relative Permeabilities with Well Logging Data

In oilfields development process it is necessary to determine attitude of fluidal contacts performedby the deposit area on the base of geological, geophysical and petrophysical data integration add‐in advanced well logging techniques. We propose new capillary model, controlled by a single parameter that is closely related to permeability. Developed model allows more accurate determination of the displaced fluid share at a given capillary pressure during drainage in comparison with analogues. Saturation estimation algorithm based on proposed model was proposed. The advantage of the algorithm is the possibility of hydrocarbon saturation reliable prediction in case of resistivity logging is non-informative due to the low vertical resolution in the layers of low width and anisotropic reservoirs. In practice, Burdine and Brooks-Corey model as the most common approximations of relative permeability curves are used. But these models describe laboratory core measurements data poor in low relative permeability area. New analytical approximations for more detailed and accurate description of relative permeability curves was obtained. Description results show that proposed model has better accuracy in comparison with known analogues. Relative permeabilities can be used for prediction of the brine share in production volume with Leverett function and have great practical importance for field development design.