The Albian/Cenomanian reservoir is one of the two main reservoirs composing the petroleum system in the Komombo Basin. However, these reservoirs have not previously been studied in detail. Therefore, a detailed study of the reservoirs is performed. Six boreholes, three vertical seismic profiles and twenty 2D seismic lines are integrated in the Petrel Schlumberger modeling software to build a 3D structural model for the Albian/Cenomanian reservoir. This model represents a framework for the subsequent 3D facies and petrophysical models of the studied reservoir. The interpretation of the created maps and 3D models shows two normal fault directions: NW–SE and NE–SW, where the NW–SE direction is dominant, creating a major half-graben system. Conventional well log analyses are performed for the available wells. The results are used in subsequent facies and petrophysical modeling. The thickness of the Albian/Cenomanian reservoir ranges from about 137 to 411.5 m. Petrographic analyses were conducted on two cores retrieved from the Albian/ Cenomanian cycles covering the depth interval of 1323–1352 m in well AB-5. Most of the samples consist of quartz arenite and feldspathic arenite. The 3D facies model of the reservoir shows that the sandstone has a large probability distribution in the study area compared to the shale and siltstone. The 3D petrophysical models imply that the Albian/ Cenomanian reservoir has good to very good reservoir quality. The main issue for the reservoir is the high water saturation values. In contrast, the hydrocarbon saturation is restricted to some parts of the basin.

The Albian/Cenomanian reservoir is one of the two main reservoirs composing the petroleum system in the Komombo Basin. However, these reservoirs have not previously been studied in detail. Therefore, a detailed study of the reservoirs is performed. Six boreholes, three vertical seismic profiles and twenty 2D seismic lines are integrated in the Petrel Schlumberger modeling software to build a 3D structural model for the Albian/Cenomanian reservoir. This model represents a framework for the subsequent 3D facies and petrophysical models of the studied reservoir. The interpretation of the created maps and 3D models shows two normal fault directions: NW–SE and NE–SW, where the NW–SE direction is dominant, creating a major half-graben system. Conventional well log analyses are performed for the available wells. The results are used in subsequent facies and petrophysical modeling. The thickness of the Albian/Cenomanian reservoir ranges from about 137 to 411.5 m. Petrographic analyses were conducted on two cores retrieved from the Albian/ Cenomanian cycles covering the depth interval of 1323–1352 m in well AB-5. Most of the samples consist of quartz arenite and feldspathic arenite. The 3D facies model of the reservoir shows that the sandstone has a large probability distribution in the study area compared to the shale and siltstone. The 3D petrophysical models imply that the Albian/ Cenomanian reservoir has good to very good reservoir quality. The main issue for the reservoir is the high water saturation values. In contrast, the hydrocarbon saturation is restricted to some parts of the basin.

The Albian/Cenomanian reservoir is one of the two main reservoirs composing the petroleum system in the Komombo Basin. However, these reservoirs have not previously been studied in detail. Therefore, a detailed study of the reservoirs is performed. Six boreholes, three vertical seismic profiles and twenty 2D seismic lines are integrated in the Petrel Schlumberger modeling software to build a 3D structural model for the Albian/Cenomanian reservoir. This model represents a framework for the subsequent 3D facies and petrophysical models of the studied reservoir. The interpretation of the created maps and 3D models shows two normal fault directions: NW–SE and NE–SW, where the NW–SE direction is dominant, creating a major half-graben system. Conventional well log analyses are performed for the available wells. The results are used in subsequent facies and petrophysical modeling. The thickness of the Albian/Cenomanian reservoir ranges from about 137 to 411.5 m. Petrographic analyses were conducted on two cores retrieved from the Albian/ Cenomanian cycles covering the depth interval of 1323–1352 m in well AB-5. Most of the samples consist of quartz arenite and feldspathic arenite. The 3D facies model of the reservoir shows that the sandstone has a large probability distribution in the study area compared to the shale and siltstone. The 3D petrophysical models imply that the Albian/ Cenomanian reservoir has good to very good reservoir quality. The main issue for the reservoir is the high water saturation values. In contrast, the hydrocarbon saturation is restricted to some parts of the basin.

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