Methodology is presented and proven for determination of the best estimate parameter values affecting the matrix-to-fracture interface fluid transfer in naturally fractured reservoirs. Improved matrix-fracture-transfer models are applied based on presumed matrix block shapes. Fracture surface hindered interface fluid transfer is considered between the matrix blocks and surrounding natural fractures. Analytical solutions developed for special boundary conditions are applied for the typical laboratory tests for rectangular and cylindrical shape rock samples. The workable equations and straight-line data plotting schemes are developed for effective analysis and interpretation of laboratory data obtained from various shape oil-saturated reservoir rock samples immersed into brine. This allows the rapid determination of the characteristic parameters of the matrix-fracture transfer models for various shape matrix blocks, which are essential for prediction of petroleum recovery from naturally fractured reservoirs by computer simulation. The methodology is verified using various experimental data concerning water imbibition into oil-bearing rock, and the values of the characteristic parameters, such as the diffusion coefficient, and skin coefficient and thickness, are determined.