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<p>Given the complexity of hydrocarbon exploration and exploitation, it is essential to include existing geology models for precise hydrocarbon prospecting and risk assessment. This study aims to determine the structural, facies, petrophysical, and volumetric parameters for reservoir evaluation within the Silah field. A suite of available well logs, including gamma-ray logs, deep resistivity, neutron, and density logs from five wells, was employed to characterize the petrophysical properties of the reservoirs. Seismic data were also used to generate the synthetic seismogram, depth structure maps, and fault model. A framework for predicting future reservoir performance and production behavior of the identified reservoirs has been made possible by the efficacy of the 3D static modeling technique as a tool for better understanding the geographical distribution of discrete and continuous reservoir features. The constructed 3D reservoir structural model shows half-graben and graben fault systems of different orientations, NE to ENE, E-W, and NW directions, and all are normal faults (synthetic and antithetic) and fold-related fault systems due to compressional stress events. The main trapping mechanisms are fault-assisted anticlines and normal faults with sufficient throw to create closure. Results from well log analysis and 3D petrophysical models reveal that the lower Cretaceous strata of the Silah wells consist of four main types of lithology: Carbonate, sand, shale, and siltstone. The reservoir’s facies and petrophysical models were combined to determine the ideal place for hydrocarbon production. The final results indicated that limestone and sandstone present in the Abu Roash (F), (G), and Upper Baharyia have the potential for hydrocarbon production. Geocellular model results showed that the central part of the Silah Field has the best petrophysical properties (low shale volume (10%-29%), Good effective Porosity (8%-17%), and low water saturation (20%-54%)), followed by the northeast part of the study area, particularly in the limestone of Abu Roash (F) and the sand bodies of the Abu Roash (G) and Upper Baharyia. According to the 3D facies model, shale beds dominate the Lower Cretaceous reservoirs (dispersed and laminated), which affected the reservoir’s ability to store and produce oil; its upper and lower zones have a good quality reservoir, whereas it has low distribution in Abu Roash (F), (G), and Upper Baharyia reservoirs. The center, western, and northwest sectors of the oilfield are the most prospective regions for the accumulation and production of hydrocarbons through the Lower Cretaceous reservoir. More vertical wells should be drilled to enhance reservoir optimization in the northwestern corner, western side, and central part of the study area.</p>

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Well logs and seismic data integration for 3D structural, facies, and petrophysical static modeling approach of the Albian–Cenomanian reservoirs in the Silah field, El Fayoum concession, Egypt

  • 期刊论文

  • 发表日期：

    2026年7月4日

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  • Ahmed Hosny Senosy,
  • Hamza Ahmed Ibrahim,
  • Mohamed Osman Ebraheem

摘要

Given the complexity of hydrocarbon exploration and exploitation, it is essential to include existing geology models for precise hydrocarbon prospecting and risk assessment. This study aims to determine the structural, facies, petrophysical, and volumetric parameters for reservoir evaluation within the Silah field. A suite of available well logs, including gamma-ray logs, deep resistivity, neutron, and density logs from five wells, was employed to characterize the petrophysical properties of the reservoirs. Seismic data were also used to generate the synthetic seismogram, depth structure maps, and fault model. A framework for predicting future reservoir performance and production behavior of the identified reservoirs has been made possible by the efficacy of the 3D static modeling technique as a tool for better understanding the geographical distribution of discrete and continuous reservoir features. The constructed 3D reservoir structural model shows half-graben and graben fault systems of different orientations, NE to ENE, E-W, and NW directions, and all are normal faults (synthetic and antithetic) and fold-related fault systems due to compressional stress events. The main trapping mechanisms are fault-assisted anticlines and normal faults with sufficient throw to create closure. Results from well log analysis and 3D petrophysical models reveal that the lower Cretaceous strata of the Silah wells consist of four main types of lithology: Carbonate, sand, shale, and siltstone. The reservoir’s facies and petrophysical models were combined to determine the ideal place for hydrocarbon production. The final results indicated that limestone and sandstone present in the Abu Roash (F), (G), and Upper Baharyia have the potential for hydrocarbon production. Geocellular model results showed that the central part of the Silah Field has the best petrophysical properties (low shale volume (10%-29%), Good effective Porosity (8%-17%), and low water saturation (20%-54%)), followed by the northeast part of the study area, particularly in the limestone of Abu Roash (F) and the sand bodies of the Abu Roash (G) and Upper Baharyia. According to the 3D facies model, shale beds dominate the Lower Cretaceous reservoirs (dispersed and laminated), which affected the reservoir’s ability to store and produce oil; its upper and lower zones have a good quality reservoir, whereas it has low distribution in Abu Roash (F), (G), and Upper Baharyia reservoirs. The center, western, and northwest sectors of the oilfield are the most prospective regions for the accumulation and production of hydrocarbons through the Lower Cretaceous reservoir. More vertical wells should be drilled to enhance reservoir optimization in the northwestern corner, western side, and central part of the study area.