Abstract
Petrophysical-Modelling is indispensable in upstream Projects, considering the high cost, risks and uncertainties associated with this sector. Petrophysical qualities for Queen Field was modeled using Information obtained and analyzed from well-logs and 3-D Seismic data. Coarse-grain, Medium- grain and fine-grain Sands as well as Shale were all delineated by GR log. Results of petrophysical evaluation conducted on seven reservoir intervals correlated across the field showed that; Shale volume was below 35%, Total Porosity are > 20% Effective Porosity are >15% Permeability is > 380.00mD all of this conforms to excellent reservoir quantity. Seismic interpretation showed the presence of synthetic and antithetic faults. Two horizons were mapped on seismic data and utilized for modeling. These models were the framework for facies and petrophysical properties distribution. Facies models were generated using sequential indicator simulation while petrophysical properties were generated using sequential gaussian simulation algorithm. A comparison was further done between facies constrained and non-facies constrained models. It was found that for Porosity, Permeability, Water of Saturation and Shale Volume Models not constrained to facies all showed overestimated Models, in addition Stochastic STOIIP not constrained to facies gave an Over Estimated P50 value for Surface I and O Reservoir Interval as 624.028M, 76.28MM, when compared to Stochastic Hydrocarbon STOIIP when constrained to facies that showed Stochastic P50 value of 513,247 and 67.04MM for surface I and O and Deterministic STOIIP of 742.90M and 87.88MM. This study validates the practice of constraining Petrophysical model to facies available on the field as the best practice.
 Keywords: Queen Field, Onshore, Niger Delta, 3D Petrophysical.
Highlights
The Petroleum industry is saddled with the continuous growth in demand for hydrocarbon and subsequent intensity on oil/gas exploration to meet energy demands
The need to hasten the time needed for initial appraisal and reduction of uncertainties, risks and difficulty associated in exploring for the hydrocarbon, and to cut down cost of exploration cannot be over emphasized and has resulted in the search for a comprehensive method to characterize Petroleum Fields
Considering how important petrophysical studies is to exploration and developmental decisions and future interventions in hydrocarbon production from a field, several studies have been carried out to Model petrophysical properties and quantify hydrocarbon volumes. (Emujakporue, 2017) performed a petrophysical properties distributions modelling of an onshore field in Niger Delta
Summary
The Petroleum industry is saddled with the continuous growth in demand for hydrocarbon and subsequent intensity on oil/gas exploration to meet energy demands. (Emujakporue, 2017) performed a petrophysical properties distributions modelling of an onshore field in Niger Delta. All the properties modelled showed uniform distribution in the reservoirs, and it was inferred with help from the model that the onshore Niger-Delta field’s central portion was very good and production well was recommended. (Onyekuryu et al, 2017) analyzed Olu field onshore Niger Delta In the research both structural and stratigraphic structures where delineated. (Nwankwo et al, 2014) carried out petrophysical modelling of a siliciclastic hydrocarbon Sand in Niger-delta. Petrophysical parameters denoted across the field was porosity with values ranging from 0.22 to 0.31, Permeability had values ranging from 881.58 to 14425.01 and average hydrocarbon saturation of 41.44%, 20.29%, 30.82%, 37.92%, 51.20%, 91.97%, 85.11% across the 7 Reservoirs (A, B, C, D, E, F) Delineated. Porosity values ranged from 0.2 to 0.3 conformance to well sorted siliciclastic reservoirs having marginal cementation was inferred
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