formation evaluation of middle miocene reservoirs via petrophysical analysis of well logging data; case study from southern part of gulf of suez, egypt

The amal oil field is located in the southern part of the gulf of suez and produces hydrocarbons mainly from middle miocene reservoirs. it is marked by uncertainties in the southern part of the gulf of suez province because of the structural complexity, lateral facies change, different lithologies, and diverse reservoir quality. therefore, in this approach, different reservoir properties of the hammam faraun member of the belayim formation, the markha member of the kareem formation, and the upper rudies member are obtained and evaluated. the main reservoirs are composed of sand and shale intercalations. the wireline logging data (gamma ray, density, neutron, sonic, and resistivity logs) of four wells were used mainly for the petrophysical analyses of hydrocarbon reservoirs. the three most important parameters in petrophysical evaluation: shale content, porosity, and fluid saturation are calculated for the main reservoirs to construct the litho-saturation model for each well. each of these parameters is mapped to study their areal variation across the study area and estimate the appropriate locations for the new development wells. fluid saturations are estimated based on the indonesian formula due to shale presence. the study exhibited that hammam faraun, markha, and upper rudies formations have porosity of 0.15-0.17, 0.15-0.23, 0.12-0.27; shale volume of 0.3-0.36, 0.12-0.51, 0.19-0.37; and water saturation of 0.34-0.6, 0.33-0.51, 0.48-0.6, respectively. the results show an increasing trend toward the central part in porosity, sandy facies, and oil saturation. based on the petrophysical evaluation and the mapping, the central part of the field is very promising for development and production activities.

formation evaluation of middle miocene reservoirs via petrophysical analysis of well logging data; case study from southern part of gulf of suez, egypt

the amal oil field is located in the southern part of the gulf of suez and produces hydrocarbons mainly from middle miocene reservoirs. it is marked by uncertainties in the southern part of the gulf of suez province because of the structural complexity, lateral facies change, different lithologies, and diverse reservoir quality. therefore, in this approach, different reservoir properties of the hammam faraun member of the belayim formation, the markha member of the kareem formation, and the upper rudies member are obtained and evaluated. the main reservoirs are composed of sand and shale intercalations. the wireline logging data (gamma ray, density, neutron, sonic, and resistivity logs) of four wells were used mainly for the petrophysical analyses of hydrocarbon reservoirs. the three most important parameters in petrophysical evaluation: shale content, porosity, and fluid saturation are calculated for the main reservoirs to construct the litho-saturation model for each well. each of these parameters is mapped to study their areal variation across the study area and estimate the appropriate locations for the new development wells. fluid saturations are estimated based on the indonesian formula due to shale presence. the study exhibited that hammam faraun, markha, and upper rudies formations have porosity of 0.15-0.17, 0.15-0.23, 0.12-0.27; shale volume of 0.3-0.36, 0.12-0.51, 0.19-0.37; and water saturation of 0.34-0.6, 0.33-0.51, 0.48-0.6, respectively. the results show an increasing trend toward the central part in porosity, sandy facies, and oil saturation. based on the petrophysical evaluation and the mapping, the central part of the field is very promising for development and production activities.