| Summary: | Once a field has been identified, and a general method of reservoir exploitation decided, there are several methods to achieve the reservoir management goal, but some ways may cost twice as much as others. The most critical operations to developing a field are drilling of wells, and it overemphasizes which in the early stages of field development. This study will cover challenges related to field development in the presence of a geological complication. In the Arabic Gulf area, most of the reservoirs are carbonate is distinguished by complex textural heterogeneity that corresponds to extreme permeability varieties which are the controlling factor in reservoir production. The uncertainty of information in the reservoir and rock mechanics properties have proven to be extremely challenging that faced oil and gas companies during the Appraisal and development phase. Numerous lost-time incidents including stuck pipe, pack - off, lost circulation and difficulties in running casing were experienced during drilling new wells. Moreover, Due to the significant differences between log-derived water saturation and capillary pressure model-derived water saturation profiles during the dynamic model, the lake of the original hydrocarbon amount will raise the associated risks and uncertainties of the model. That becomes necessary to perform the task of integrated reservoir characterization and geomechanics in order to find optimum field development plan, that is the objective of this study was to characterized reservoir rock by distributing petrophysical rock types, porosity, and permeability and applied rock typing among the transition zone to increase the certainty of oil in place. Moreover, design a new modify for mud window to mitigate drilling hazard was one of the primary outcomes in this study. The objective of this study applied in a case study in the Arabic Gulf area. Several approaches were performed to determine which method was more reliable for our case study to identification rock typing, FZI*showed a better result than other methods, it has created three petrophysical rock types, which depend on specific porosity and permeability trends. The distribution of petrophysical rock type, porosity, and permeability perform in the form of the 3D model by using geostatic model. In the geomechanical evaluation, there was a notable difference in geomechanical characteristics. The values for these properties rise at deeper depths, most possibly because of the degree of the overburden and increased compaction, as shown in the increasing sonic speeds. A result from integrated rock typing and geomechanics showed that PRT 3 identified as a best reservoir and highest lost circulation zone, according to a highly porosity and permeability values that varies from 0.17 to 0.25 and from 237 to 349 MD respectively .Integrated FZI* as an indicator of loss circulation zone that showed probability of mud loss increased with increased FZI* values, with median line principle guide us to design a new approach for optimum mud window design to reduce L.C and tight hole problem. The outcomes of this research can be utilized in the field industry to improved reservoir characterized and mitigate drilling problem by applying our new modify for mud window design.
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