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Vol.2 , No. 5, Publication Date: Oct. 10, 2015, Page: 113-123
. The estimated thicknesses of the two reservoirs are 45m and 23m for A1000 and A2000 respectively. The average porosity for reservoir A1000 and A2000 are 0.26 and 0.25. The quality of the porosity is very good. The computed average water saturation is 0.33. This shows that the hydrocarbon saturation is 0.63. These sands units were further evaluated using seismic interpretation. Horizons and faults interpretation were carried out to produce subsurface structure maps from seismic data to study the field’s subsurface structures serving as traps to hydrocarbon and estimate the prospect area of the reservoirs. The fault interpretations revealed three listric faults labeled F1, F2, and F3, and two antithetic faults F4 and F5. The estimated hydrocarbon in place for the two reservoirs (A1000, and A2000) are13646986.97 bbl and 6914317.50 bbl respectively. The antithetic and synthetic faults act as good traps for the hydrocarbon accumulation in the study area.&picture=http://www.aascit.org/aascit/decorators/img/journal/899.jpg)
| [1] | Emujakporue Godwin O., Department of Physics, Faculty of Science, University of Port Harcourt, Choba, Rivers state, Nigeria. |
| [2] | Faluyi Timothy Oluwaseun, Department of Physics, Faculty of Science, University of Port Harcourt, Choba, Rivers state, Nigeria. |
TRH field is an oil field located in Niger Delta, Nigeria and the study was aimed at reservoir evaluation of the field. The research methodology involved integration of seismic and geophysical well log data for the identification of hydrocarbon bearing reservoirs, computing reservoir petro physical parameters and estimation of initial hydrocarbon in place. Four wells were correlated across the field to delineate the lithology and established the continuity of reservoir sands as well as the general stratigraphy of the area. The well analysis carried out on the sand bodies indicates two sand units that are hydrocarbon bearing reservoirs (A1000, and A2000). The estimated thicknesses of the two reservoirs are 45m and 23m for A1000 and A2000 respectively. The average porosity for reservoir A1000 and A2000 are 0.26 and 0.25. The quality of the porosity is very good. The computed average water saturation is 0.33. This shows that the hydrocarbon saturation is 0.63. These sands units were further evaluated using seismic interpretation. Horizons and faults interpretation were carried out to produce subsurface structure maps from seismic data to study the field’s subsurface structures serving as traps to hydrocarbon and estimate the prospect area of the reservoirs. The fault interpretations revealed three listric faults labeled F1, F2, and F3, and two antithetic faults F4 and F5. The estimated hydrocarbon in place for the two reservoirs (A1000, and A2000) are13646986.97 bbl and 6914317.50 bbl respectively. The antithetic and synthetic faults act as good traps for the hydrocarbon accumulation in the study area.
Keywords
Petrophysics, Reservoir, Hydrocarbon, Seismic, Well Logs
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