Abstract Hassi Messaoud field heterogeneous and tight reservoir modeling has for decades been a challenge. While the matrix contains most of the fluid and the fractures contribute most to the fluid flow, conductivity is the result a complex network of fissures and fractures. The challenge here is to simulate naturally fractured reservoirs from both a reservoir description and numerical computation standpoint. Current commercial numerical simulators are capable of handling flow in such complex reservoirs; the correct application of those simulators for representative reservoir models is yet another challenge. The capability of numerical simulators to model reservoir performance is dependent on the quality of reservoir description. Thus the main task of any reservoir description technique is to divide the reservoir into subunits such as layers and grid block and to assign representative values of all petrophysical parameters to each unit. This paper discusses parametric ways to improve construction of representative reservoir models of a sector of the largest field in North Africa. Discussion will focus on transition from single porosity representation to dual porosity models and the process employed in between. The study is categorized within the following three segments First, the petrophysical model construction for zone fourteen of the Hassi Messaoud field. Here an effective technique is used to uniquely describe all the petrophysical properties of naturally fractured reservoirs in terms of matrix porosity, fracture porosity, and cementation exponent at formation in-situ. Secondly the identification and characterization of the reservoir via through integration of core analysis, well log interpretation, and pressure transient analysis. Thirdly the validation of the generated model after up scaling of calculated reservoir properties, then the simulation and history matching of each well individually.