A new method to diagnose and estimate secondary porosity and absolute permeability of fractured and vuggy carbonate formations based on the numerical simulation of the process of matrix solution technique developed and validated. The method includes the geological characterization of core laboratory data and their integration with well logs and rock production measurements. The new method to the interpretation of data acquired in a tertiary reservoir in Bai Hassan oil field applied. Cretaceous reservoir behaves as a triple-porosity petrophysical system which exhibits inter-crystalline, intra-crystalline, moldic, vuggy (connected and non-connected) and fractured porosity. Rockcore data and well tests indicate that vugs are the mayor component of secondary porosity while fractures and interconnected vugs account for most of the permeability. The initial phase of our interpretation method consists of integrating core measurements with well logs and well tests to calculate static and dynamic petrophysical properties via standard carbonate evaluation procedures. This procedure tested on several key wells with and without core measurements and well-testing measurements. Final estimates of porosity and permeability are in good agreement with the properties of the global petrophysical system been founded.