Abstract
This research is based on the modelling of petrophysical parameters distribution of an onshore oil field in Niger Delta. The methodology involves the construction of 3-D grids that represent the reservoir geometry, accompany by property modeling where the 3-D grids were populated with petrophysical properties (porosity, water saturation, net to gross ratio, facies and permeability). The objective is to construct a 3D-dimensional reservoir model that characterizes and evaluate reservoirs in an onshore oil field, Niger delta. Three-dimensional grid and geophysical logs of 4 oil boreholes were used to characterize the delineated reservoirs. Two lithologies and two reservoirs were delineated from the logs. The lithologies are sandstone and mudstone which are arranged in alternation representing the Agbada Formation of the Niger Delta. The calculated petrophysical parameters for the two reservoirs in the four wells were used for estimating the properties distribution in the reservoirs. The petrophysical properties estimation and distribution was done with inverse distance weighting of deterministic techniques of modeling. The calculated porosity values for the two reservoirs range from 0.061 to 0.30 with an average of 0.185. The permeability of the two reservoirs ranged from 110 to 2394 mD. The calculated water saturation and net to gross ratio of the two reservoirs range from 0.23-0.57 with an average of 0.4 and 0.44-0.87 with an average of about 0.61 respectively. The porosity, permeability, water saturation and net to gross ratio and facies models show uniform distribution within the reservoirs. From the models, it can be inferred that the reservoir properties within the central part of the field are very good. It is, therefore, advisable that wells should be drilled in the central region to investigate the presence of oil. The results of this study have shown the effectiveness of 3D reservoir modeling as a tool for understanding the spatial distribution of reservoir properties. The results can be used as a guide for evaluating future performance and production behavior of the reservoirs.
Highlights
Porosity, permeability and water saturation are the main petrophysical properties of a reservoir rock and have a vital impact on hydrocarbon reservoir evaluation and characterization
The 3-D grid is followed by property modeling, in which the grid is populated with petrophysical properties such as porosity, water saturation and permeability
This modeling is based on the detailed analysis of subsurface data during reservoir characterization
Summary
Permeability and water saturation are the main petrophysical properties of a reservoir rock and have a vital impact on hydrocarbon reservoir evaluation and characterization. Reservoir characterization is the integration of different data in order to describe the reservoir properties of interest in inter-welllocations (Mehdipour et al, 2013; Ezekwe and Filler, 2005; Hadi et al, 2005). Various petrophysical properties such as porosity, net-to-gross and water saturation are used for reservoir modeling. Hydrocarbon reservoirs properties can be estimated by deterministic and probabilistic modeling (Godwill and Waburuko, 2016; Perevertailo et al, 2015; Kelka and Perez, 2002; Ezekwe and Filler, 2005; Başel et al, 2010). Porosity can be obtained from sonic, neutron or bulk density log while resistivity logs are used for the calculation of water
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