scholarly journals Determination of Geothermal Gradient from Bore Hole Temperature data in Some Parts of the Eastern Niger Delta Basin

2021 ◽  
pp. 39-46
Author(s):  
E. D. Uko ◽  
M. A. Alabraba ◽  
I. Tamunoberetonari ◽  
A. O. Oki
Keyword(s):  
Niger Delta ◽  
Good Reason ◽  
Geothermal Gradient ◽  
Temperature Data ◽  
Oil Fields ◽  
Basin Evolution ◽  
Geothermal Gradients ◽  
Oil Hydrocarbons ◽  
Niger Delta Basin

An analysis of Geothermal Gradients in the Eastern Niger Delta basin was done using Bore Hole Temperature (BHT) data from three (3) adjacent oil fields. BHT data was converted to static formation temperature by using the conventional method of increasing measured BHT data by 10% and Geothermal Gradient computed using its simple linear relationship with depth, surface temperature and static temperature at depth. Projections were then made for change in Geothermal gradients at 1km intervals to a depth of 4 km. Results obtained showed significant variations across Idama, Inda and Robertkiri fields with average geothermal gradients of 17.3⁰C/Km, 22.6⁰C/Km and 23.1⁰C/Km respectively. Variation in the geothermal gradients in the area is attributed to lithological control and differential rates of sedimentation during basin evolution. Also, results showed that the Geothermal Gradient in the area are generally moderate and could be a good reason for the occurrence of more oil hydrocarbons than gas in the area.

scholarly journals Modeling the Chance of Commerciality of Petroleum Assets for Economic Development

2021 ◽  
pp. 40-61
Author(s):  
U. Georgeson Victor ◽  
Omowumi O. Iledare ◽  
Joseph A. Ajienka
Keyword(s):  
Economic Development ◽  
Case Studies ◽  
Building Block ◽  
Niger Delta ◽  
Petroleum Resources ◽  
Niger Delta Basin ◽  
Cost Implications ◽  
The Cost ◽  
New Framework

The chance to discover hydrocarbon volumes of economic quantity diminishes with progressive discovery in explored basins. Given the preponderance of smaller deposits in extensively explored basins and the cost implications of discovering deposits less than the required Minimum Economic Reserves (MER), explorationists and investors in exploration activities need a framework to evaluate the chance of a successful petroleum resources discovery to minimize the risk of unsuccessful exploration. This study develops a new framework to evaluate the chance of discovery of at least a minimum economic reserves volume in an extensively explored basin. It leverages on the postulation for the determination of probability of hydrocarbon economic success as a building block for the new framework. The model combines the concepts of Minimum Economic Reserves, Discovery Efficiency and Probability to derive an explicit analytical function for discovery efficiency and hydrocarbon probability for a commercial discovery. It digitalizes existing Risk Table to ease the complexity to obtain geological chance of success and hydrocarbon asset evaluation for commerciality. Nine Case studies from the prolific Niger Delta basin of Nigeria are used to validate the model. The result of the semi-digital solution of the model shows that three of the studied cases are commercial whereas the remaining six cases are sub-commercial. The study recommends the application of the new framework for hydrocarbon asset evaluation for chance of commerciality to complement models like the cream off curve to predict chance of commercial discovery of hydrocarbon assets.

scholarly journals Curie depth and heat flow analysis of Ikot Ekpene and environs, Eastern Niger Delta Basin, using airborne magnetic data

2020 ◽  
Vol 8 (2) ◽  
pp. 263
Author(s):  
Uche Iduma ◽  
Stephen Stephen Onyejiuwaka ◽  
Nwokeabia Charity Nkiru
Keyword(s):  
Heat Flow ◽  
Spatial Data ◽  
Niger Delta ◽  
Average Power ◽  
Hydrocarbon Exploration ◽  
Computational Method ◽  
Magnetic Data ◽  
Geothermal Gradients ◽  
Curie Depth ◽  
Niger Delta Basin

Aeromagnetic dataset over Ikot Ekpene and environs, Eastern Niger Delta Basin, was processed to compute the basement depth, Curie isotherm depth, geothermal gradient and heat flow within the area in order to investigate the depth to magnetic sources, geothermal prospect and the hydrocarbon potential of the place. The adopted computational method transformed the spatial data into frequency domain and provided a relationship between radially average power spectrum of the magnetic anomalies and the depths to respective sources.  The results of the analysis showed that the depths to centroids and top boundaries range from 7.84 to 13.38 km and 0.233 to 0.459 km respectively. Curie depths within the basin undulate and vary between 15.42 and 26.49 km. The geothermal gradients range between 20.758 and 35.649 ⁰C/km while the corresponding heat flow is about 51.896 mWm⁻² within east of Ikono, north of Mbak and west of Abak Areas and 89.124 mWm⁻² within Amawum, Ndoro, Isiala, Ogbuebule and east of Uyo Areas. Based on the computed sedimentary thicknesses, high geothermal gradients and delineated major faults and fractures which could serve as migratory pathway for hydrocarbon or hydrothermal fluid, some parts of the study area have been demarcated for geothermal prospect and detail hydrocarbon exploration.  

scholarly journals Distribution of Some Diamondoids in Crude Oils from Niger Delta Basin

2019 ◽  
Vol 2 (2) ◽  
Keyword(s):  
Niger Delta ◽  
Oil Fields ◽  
Crude Oils ◽  
Good For ◽  
Niger Delta Basin

Some Niger Delta oils were studied for the presence of diamondoids in the oils. Oils were obtained from a well each from their respective oil fields. The objectives of the study include identification of diamondoids in the oils, use of parametric ratios to delineate biodegradation and maturity of the oils. The m/z 136 show the presence of Adamantane and the m/z135 showed the presence of 1-Methyladamantane, 2–Methyladamantane, 1–Ethyladamantane and 2-Ethyladamantanein the oils. The nC17/Pr and nC17+nC18/(Pr+Ph) showed good biodegradation trend for the oils. 1MA/nC11 and nC17+nC18/(Pr+Ph plot did not show a good biodegradation gradient though of similar trend. 1MA/ nC11 showed a restricted spread. The plot 1MA/nC11 and 1MA+2MA/A showed a better spread for 1MA+2MA/A. The1MA/1MA+2MA (Methyladamantane index) showed a better maturity gradient and is good for the Nigerian oils but the 1EA/1EA+2EA (Ethyladamantane index) showed restricted spread for a good maturity gradient and may be better for higher matured oils than the Niger delta Oils.

scholarly journals THE EFFECT OF DENSITY-VELOCITY RELATION PARAMETERS ON DENSITY CURVES IN TAU (τ) FIELD, NIGER DELTA BASIN

2020 ◽  
Vol 4 (2) ◽  
pp. 54-58
Author(s):  
Atat, J. G. ◽  
Akankpo, A. O. ◽  
Umoren, E. B. ◽  
Horsfall, O. I. ◽  
Ekpo, S. S
Keyword(s):  
Density Estimation ◽  
Niger Delta ◽  
Accurate Result ◽  
Oil Field ◽  
Well Log ◽  
Velocity Relation ◽  
Density Values ◽  
Niger Delta Basin

We considered the constants obtained for tau (𝜏)Field in the Niger Delta basin from well-log data of three wells (A,B,C) to investigate the effect of inclusion of these constants on density-velocity relation using Hampson Russell Software to generate density curve in tau field. The curves were compared to those generated from Gardner and Lindseth constants and in-situ density curves. Many researchers have worked on constants for density-velocity equations for different Fields; their results always differ from Gardner and Lindseth constants including the constants of Atat et al., 2020 which are considered in this investigation as Tau Field local fit constants. Our findings support the results of these researchers. Results indicate over estimation of density curves when using Gardner and Lindseth constants. The challenge is that in-situ density curves are not accurate due to sand-shale overlap of density values. The most improved and accurate result is given by the density curves obtained using the constants for specific sand and shale lithologies (local fits). This verifies the need for the determination of constants for local fit of the oil field under investigation. The pink curves truly indicate the density estimation for the tau field which is very reliable in the characterisation of reservoir.

scholarly journals Quantitative prediction of overburden pressure and overpressure zones using well logs - a case study of an x-field in the Niger-delta basin, Nigeria

2018 ◽  
Vol 6 (1) ◽  
pp. 65
Author(s):  
Chidozie Opara ◽  
Michael Ohakwereze ◽  
Okechukwu Adizua
Keyword(s):  
Bulk Density ◽  
Niger Delta ◽  
Quantitative Prediction ◽  
Overburden Pressure ◽  
Exploration And Production ◽  
Vertical Effective Stress ◽  
Niger Delta Basin ◽  
Sonic Logs

Prediction and evaluation of overburden pressure are critical for the exploration and production of hydrocarbon reservoirs. Overburden pressure was estimated using well log (density and sonic) data obtained from two wells (B1 and B2) of an X - Field within the Niger Delta basin. Overburden pressure depends primarily on the bulk density data. Bulk density was extracted from density and sonic logs based on the log signatures. The bulk density was then used to determine overburden pressure using Eaton’s equation. The results reveal that overburden pressure increases linearly with depth, and an overburden gradient of 1.0 psi/Ft. was obtained. The overburden pressure was used to estimate pore pressure and vertical effective stress and thus enabled the determination of overpressure zones within the well.

scholarly journals Hydrocarbon prospectively determination of “eagle field”, coastal swamp ii Niger delta.

2019 ◽  
Vol 7 (1) ◽  
pp. 52
Author(s):  
Olowokere M T ◽  
Amadou Hassane ◽  
Alonge M. A ◽  
Adekola E. Ajibade
Keyword(s):  
Niger Delta ◽  
Hanging Wall ◽  
Geothermal Gradient ◽  
Data Interpretation ◽  
Seismic Interpretation ◽  
Well Log ◽  
Reservoir Development ◽  
Seismic Lines ◽  
Reserve Estimates

Seismic and well log data were collected from onshore depobelt of Nigeria with a total of 1000 seismic lines and 3 wells. The main objective of the study was to determine hydrocarbon prospectivity and reserve estimates of the field. The evaluation centred on seismic interpretation and 3D visualisation (DHI detection) of the “Ejanla Field” 3D in total, Four horizons have been interpreted regionally for correlation purposes and three as prospect specific horizons. Four prospects and some, more speculative leads were identified in the area of which most are conventional three way dip/fault closures and some hanging wall closures. The potential for stratigraphic trapping was also recognized. The study showed that the small closure areas and limited hydrocarbon column lengths affected the number of prospects and at the shallow levels.The main risk to oil prospectivity in the area as revelled by the data interpretation is gas which may have resulted from the observed higher geothermal gradient in the deeper depth. Reservoir development and retention (overpressure) for prospects and leads in the deeper and more distal sedimentological settings form additional risks.    

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