Abstract: This paper presents the model for well test interpretation of triple porosity media reservoir composed of matrix, fracture and vug, in which wellbore storage and skin effect are considered by fully implicit difference format, and related numerical solutions are given. The comparisons of this model with models for vug to wellbore connection and fracture-vug to wellbore connection are made in pressure response, including analyses of interporosity flow coefficient, storativity ratio, permeability ratio and the effect of outer boundaries on pressure response. The results show that this mode contains these two connection models, where interporosity flow coefficients (λfv and λmv)are used to determine the time of transition interval emergence; storativity ratio (ωv and ωf)to affect the depth and width of sag-like curves of pressure derivative, permeability ratio (K0 v)to influence the shape of interporosity flow transition curve, and sealed boundary and isopressure boundary to result in late curve "up" and "down" in pressure derivative.

Key words: triple porosity media, well test, interporosity coefficient, elastic storativity ratio