الفهرس 
IntroductionOnly 14 pages are availabe for public view
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Abstract
JG filed is one of the main oil producing fields in the NEAG concession at the northeast of Abu Gharadig basin in the northern Western Desert of Egypt. This study aims to identify the all prospective reflectors to evaluate the petroleum system and hydrocarbon potentialities of the study area. This study was achieved by seismic interpretations of forty 3D seismic sections, study the petrophysical parameters of complete log sets of eight exploratory wells in the study area, and make the geochemical analysis of two cores available in this area. The results of this study indicate, many reflectors of the study area are picked and mapped as (TWT) maps and depth maps., These reflectors are arranged from the youngest to the oldest as; Apollonia, Intra Apollonia D, Alamein dolomite, Alam El Bueib, Masajid, Khatatba, Kabrit and Lower Safa. These maps indicate, the structure of JG filed is an elongated E-W fault dip closure bounded to the South by the Cretaceous Abu Gharadig basin bounding fault. The prospect is bisected by a series of smaller ENE-WSW, and NW-SE trending faults. The JG reservoir structurally is a three-way dip closure sealed vertically and laterally. The top seal is provided by the Middle Jurassic Khatatba shales and the carbonate interval of Masajid formation. These shales and limestone can act also as intra-formational seals. The petrophysical parameters of Khatatba reservoir members are computed to identify the hydrocarbon bearing zones and to study the reservoir properties based on the data derived from 8 wells with in JG and JD fields. The results of the reservoir rocks are represented by a number of iso-parametric maps, which include the volume of shale, effective porosity and net-pay thicknesses. Mapping of these parameters represent the thickness and quality variation of the reservoir. The northwest and southeast parts of the area show a considerable reservoir thickening of Upper Safa A, while the distribution of Upper Safa B reservoir is eastward. Lower Safa A Member shows a considerable reservoir thickening westward, while the westward parts of the area show a considerable reservoir thickening of Lower Safa B Member. The maximum distribution of the Lower Safa C Member is northeastward. The sandstone porosities of these members are varied from 12% to 27.4%. the hydrocarbons are oil and a condensate rich gas. Geomechanical model is achieved by defining the geotechnical characteristics of the adjacent rock units across JG5-ST well vertically, as a measure of the well stability during the drilling of this well, in relation to the geomechanics of the surrounding section. The source rock evaluation is defined by calculating the organic carbon content (TOC wt %). These TOC values were determined within the six rock units, namely Upper Safa A, Upper Safa B, Kabrit, Lower Safa A, Lower Safa B and Lower Safa C Members. The maturity of a source rock is defined by vitrinite reflectance (Ro). By the integration of the lithologic, petrophysical, fluid parameters, structural and modeling parameters, the hydrocarbon potentialities of the study area are attained.