This article presents a method for simulation of continuous and discrete fracture parameters distributions in hydrocarbon
reservoirs using Sequential Indicator Simulation (SIS) and Sequential Gaussian Simulation (SGS) methods.
Fracture parameters including azimuth, dip and density are integrated with the porosity and permeability values determined
in the models. Based on this study we have identified stylolites, occluded fractures, vugs (isolated pores) and open
fractures using core data from 13 wells in one of the southern Iranian gas fields. A model is constructed using SIS that
contains fractures. This enables us to evaluate the role of fractures in the model enhancing permeability and their predictability
in reservoirs. For this purpose, only the fractured blocks of the mentioned model were selected for fractures density,
azimuth and dip modeling. Afterward, a novel function named Fracture Effect Factor (FEF) is introduced to calculate
the effect of fractures on permeability model in the fractured blocks. For porosity modeling, fractures type model is used
as an aid for increasing the accuracy of the modeling so that for the mentioned four fracture types, individual variograms
are constructed and porosity estimation in each block is performed based on its related variogram. The proposed model is
compared with dual porosity model on a fractured reservoir in South of Iran for a period of 18 years. The results of this
research indicate that this method can visualize a more real estimation of dynamic and static behavior of the reservoir.