scholarly journals Integration of Well Logs and Seismic Data for Prospects Evaluation of an X Field, Onshore Niger Delta, Nigeria

2012 ◽  
Vol 03 (04) ◽  
pp. 872-877 ◽  
Author(s):  
Godwin Emujakporue ◽  
Cyril Nwankwo ◽  
Leonard Nwosu
Keyword(s):  
Seismic Data ◽  
Niger Delta ◽  
Well Logs

scholarly journals Transition zones analysis using empirical capillary pressure model from well logs and 3D seismic data on ‘Stephs’ field, onshore, Niger Delta, Nigeria

2019 ◽  
Vol 10 (3) ◽  
pp. 1227-1242
Author(s):  
O. Abiola ◽  
F. O. Obasuyi
Keyword(s):  
Capillary Pressure ◽  
Seismic Data ◽  
Niger Delta ◽  
Time Structure ◽  
Well Logs ◽  
3D Seismic ◽  
Seismic Section ◽  
Transition Zones ◽  
Mobile Water ◽  
3D Seismic Data

AbstractCapillary pressure is an important characteristic that indicates the zones of interaction between two-phase fluids or fluid and rock occurring in the subsurface. The analysis of transition zones (TZs) using Goda (Sam) et al.’s empirical capillary pressure from well logs and 3D seismic data in ‘Stephs’ field, Niger Delta, was carried out to remove the effect of mobile water above the oil–water contact in reservoirs in the absence of core data/information. Two reservoirs (RES B and C) were utilized for this study with net thicknesses (NTG) ranging from 194.14 to 209.08 m. Petrophysical parameters computed from well logs indicate that the reservoirs’ effective porosity ranges from 10 to 30% and the permeability ranges from 100 to > 1000 mD, which are important characteristics of good hydrocarbon bearing zone. Checkshot data were used to tie the well to the seismic section. Faults and horizons were mapped on the seismic section. Time structure maps were generated, and a velocity model was used to convert the time structure maps to its depth equivalent. A total of six faults were mapped, three of which are major growth faults (F1, F4 and F5) and cut across the study area. Reservoir properties were modelled using SIS and SGS. The capillary pressure log, curves and models generated were useful in identifying the impact of mobile water in the reservoir as they show the trend of saturating and interacting fluids. The volume of oil estimated from reservoirs B and C without taking TZ into consideration was 273 × 106 and 406 × 106 mmbbls, respectively, and was found to be higher than the volume of oil estimated from the two reservoirs while taking TZ into consideration which was 242 × 106 and 256 × 106 mmbbls, respectively. The results have indicated the presence of mobile water, which have further established that conventionally recoverable hydrocarbon (RHC) is usually overestimated; hence, TZ analysis has to be performed for enhancing RHC for cost-effective extraction and profit maximization.

scholarly journals Prediction of pore pressure using well logs and seismic data in Fabi Field, Onshore Niger delta, Nigeria

2016 ◽  
Vol 4 (2) ◽  
pp. 76 ◽  
Author(s):  
Aniwetalu Emmanuel ◽  
Anakwuba Emmanuel ◽  
Ilechukwu Juliet N ◽  
Chidozie Okoye
Keyword(s):  
Pore Pressure ◽  
Seismic Data ◽  
Niger Delta ◽  
Control Point ◽  
Well Logs ◽  
Depth Level ◽  
Well Control ◽  
High Impedance ◽  
Impedance Inversion ◽  
Elastic Impedance

The variations of pore pressure in Fabi Field Onshore Niger delta have been investigated using well log and seismic data. The both data were calibrated to ensure reasonable match in depth. Zones of overpressure were predicted from the well logs based on the deviations of petrophysical measurement from normal compaction trends. The lateral variations of the overpressure were delineated from seismic data through elastic impedance inversion. Overpressure cube was delineated from the inverted volumes through points of picked horizons. The results of the study revealed overpressure occurrence in well logs at depth level of 8625ft to 9000ft. The elastic impedance inversion presents overpressure variations beyond well control point at the depth level of about 1940-1140ms corresponding to very high impedance value of about 25540-27067ft/s*g/cc. The area extents of the positive anomalies (increase in elastic impedance) are mostly consistent with overpressure zones. Overpressure zones were also estimated from the seismic data between 1560ms -1600ms within the TRK-1 and TRK-2 horizon which also correspond to the well control points (8625ft to nearly 9000ft). The velocity and density crossplots revealed that undercompaction is the main overpressure generating mechanism in Fabi Field, although other parts of the field revealed unloading mechanism.

scholarly journals Reservoir Characterization of Buma Field Reservoirs, Niger Delta using Seismic and Well Log Data

2019 ◽  
Vol 2 (4) ◽  
Keyword(s):  
Seismic Data ◽  
Pore Volume ◽  
Niger Delta ◽  
Reservoir Characterization ◽  
Well Logs ◽  
Well Log ◽  
Average Thickness ◽  
Bulk Volume ◽  
Volumetric Estimation

The reservoir characterization of Buma Field, Niger Delta using seismic and well log data is the focus of this research. Seismic data in SEG-Y format and suites of well logs have been used to achieve the aim and objectives of the research. Methodologies used in this work are standard methods used in this kind of research. Results of the analysis seismic data shows fifteen faults have been identified, nine trend NW-SE and are antithetic faults whereas the six trend NESW and are synthetic faults. These faults formed closures and could act as trapping mechanisms for hydrocarbon in the identified horizons/reservoirs. Two hydrocarbon bearing horizons D and F have been mapped on the seismic and analysis of the well logs showed that sand and shale are major lithologies in the studied wells. Well correlation showed similarities in geological properties such as lithology, reservoir tops and petrophysical properties. Volumetric estimation carried out on the two reservoirs showed Reservoir D having average thickness of 26.73 ft., area of 3784.89 acres, bulk volume of 4407x106 ft3 , net volume of 4226x106 ft3 , pore volume of 216 x106 RB, hydrocarbon pore volume (oil) of 143x106 RB and STOIIP of 77 MMSTB. Reservoir F has an average thickness of 41.55 ft., area of 2790.63 acres, bulk volume of 5051x106 ft3, net volume of 4769x10106 ft3 , pore volume of 248x10106 RB, hydrocarbon pore volume (oil) of 167x10106 RB and STOIIP of 88 MMSTB. Integrating results of structural interpretation, well log analysis, petrophysical properties and volumetric estimation it is evident that both reservoirs have very good porosities and excellent permeability, good thicknesses of productive sand and reduced water saturation as to aid storage and easy flow of hydrocarbon pore fluids. Therefore, the two Buma Field Reservoirs D and F are prolific with hydrocarbon pore fluids (oil) which can be exploited economically

Full Wave and Down-Going Elastic Inversion of Deepwater OBN Seismic Data: Example from Niger Delta

2020 ◽  
Author(s):  
S. Amoyedo ◽  
E. Tawile ◽  
S. Pou-Palome ◽  
P. Kakaire ◽  
O. Olagundoye ◽  
...  
Keyword(s):  
Seismic Data ◽  
Niger Delta ◽  
Full Wave ◽  
Elastic Inversion

Stochastic discrete fracture network modeling in shale reservoirs via integration of seismic attributes and petrophysical data

2021 ◽  
pp. 1-50
Author(s):  
Yongchae Cho
Keyword(s):  
Seismic Data ◽  
Stochastic Approach ◽  
Fracture Network ◽  
Natural Fracture ◽  
Well Logs ◽  
Fracture Model ◽  
Well Log ◽  
Discrete Fracture ◽  
Discrete Fracture Network Modeling ◽  
Fracture Network Modeling

The prediction of natural fracture networks and their geomechanical properties remains a challenge for unconventional reservoir characterization. Since natural fractures are highly heterogeneous and sub-seismic scale, integrating petrophysical data (i.e., cores, well logs) with seismic data is important for building a reliable natural fracture model. Therefore, I introduce an integrated and stochastic approach for discrete fracture network modeling with field data demonstration. In the proposed method, I first perform a seismic attribute analysis to highlight the discontinuity in the seismic data. Then, I extrapolate the well log data which includes localized but high-confidence information. By using the fracture intensity model including both seismic and well logs, I build the final natural fracture model which can be used as a background model for the subsequent geomechanical analysis such as simulation of hydraulic fractures propagation. As a result, the proposed workflow combining multiscale data in a stochastic approach constructs a reliable natural fracture model. I validate the constructed fracture distribution by its good agreement with the well log data.

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