Abstract
Hydrocarbon play assessment of any hydrocarbon reservoir unit depends on the porosity, permeability, hydrocarbon saturation and water saturation of petrophysical model distributions and seismic reflections of reservoir rocks. The objective of the study is to resolve the ambiguities that are associated with hydrocarbon play assessment of an X-field in the Niger Delta basin. This was achieved through the use of pre-conditioned attributes, fault delineating seismic attributes such as coherence, variance and quantitative definition of the reservoir units of petrophysical model distributions, through the adoption of an integrated methodology of 3D seismic and well log data. A quick look examination of the well log signatures revealed numerous reservoir sand units, but only three hydrocarbon-bearing reservoir sands were of interest to us (RS1, RS2 and RS3). From the quantitative interpretation of well logs, the three identified reservoir sands were evaluated in terms of porosity, permeability, hydrocarbon saturation, shale volume, movable hydrocarbon index and water saturation. Effective porosity values of 24.56, 23.01 and 24.00% were obtained for Well 1, Well 2 and Well 4, respectively. This supports the known or already established porosity range of Agbada Formation of Niger Delta with range 28–32%. The hydrocarbon saturation for RS2 is 68.51% for Well 4, for RS3 72.49% for Well 3 and for RS2 74.16% and for RS3 77.34% for Well 2. RS2 of 79.51% and RS3 of 80.99% for Well 1 were obtained. This shows how prolific the reservoir sand units are with hydrocarbon accumulation tendencies. Structural analysis revealed a highly faulted system that depicts a typical tectonic setting of the Niger Delta basin, and the computed attributes like coherence, and variance shows an optimum visualization of the faulting system. This implies that the trapping mechanism of the field is of both anticlinal and fault-assisted closure and also the viability of the reservoir units is high from the computed petrophysical parameters.
Highlights
Hydrocarbon play assessment of any hydrocarbon reservoir can depend on the porosity, permeability and water saturation of the petrophysical parameter distribution of reservoir rocks
From the quantitative interpretation of well logs, the three identified reservoir sands were evaluated in terms of porosity, permeability, hydrocarbon saturation, shale volume, movable hydrocarbon index and water saturation
Three reservoir sands were delineated based on gamma ray, neutron, density and resistivity log combination
Summary
Hydrocarbon play assessment of any hydrocarbon reservoir can depend on the porosity, permeability and water saturation of the petrophysical parameter distribution of reservoir rocks. Stochastic and deterministic modeling are the two methods that can evaluate the reservoir property, and it is always difficult to obtain the spatial distribution of the petrophysical properties using the deterministic approach (Emujakporue 2017; Miller et al 2000; Ma et al 2013; Adeoti et al 2014; Qihong et al 2000). This deterministic approach requires the inverse distance weighting method and it assumes a single value at a point (Emujakporue 2017). Identification of hydrocarbon reserves is the target of any oil and gas organization, since it serves as the economic growth indicator for the shareholders
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