Abstract
Prediction of reservoir petrophysical properties from well-logs data has evolved from the use of experts’ knowledge and statistics to the use of artificial intelligence (AI) models. Several AI models for this purpose are available in the literature; regrettably, most of them are multiple-inputs single-output (MISO) models. Meaning, these models used numerous well-logs to predict a single reservoir petrophysical property. In this study, multiple-inputs multiple-outputs (MIMO) artificial neural network (ANN) model to predict reservoir petrophysical properties: porosity (\(\varphi\)), permeability (\(k\)), and water saturation (\(S_{{\text{w}}}\)), was developed based on wireline logs (gamma ray, resistivity, density and depth interval logs) from 15 fields in the Niger Delta region. The developed ANN model is a feed-forward back-propagation (FFBP) network with 12 neurons in its hidden layer with the Levenberg–Marquardt algorithm as the best learning algorithm than Bayesian regularization and Scaled conjugate gradient. The performance of the developed model resulted in the overall correlation coefficient (R) and Mean Square Error (MSE) values of 0.9945 and 0.7310, respectively. Again, the generalization potential of the developed ANN model with new datasets was determined using five performance indicators: R, coefficient of determination (R2), MSE, root mean square error (RMSE) and average relative error (ARE). The results obtained showed that \(\varphi\) had R of 0.9243, R2 of 0.8544, MSE of 1.7243, RMSE of 1.3131 and ARE of 0.0652, while \(k\) had R of 0.9810, R2 of 0.9624, MSE of 0.0003, RMSE of 0.0173 and ARE of 0.0036. Also, \(S_{{\text{w}}}\) resulted in R, R2, MSE, RMSE and ARE values of 0.9631, 0.9276, 0.0049, 0.0700 and 0.0158, respectively. Furthermore, comparing the performance of the developed ANN model with some existing ones indicated that it performed better than some existing models. Additionally, the developed ANN model is replicable as its threshold weights and biases required to replicate the model are made available, unlike other models in the literature. Furthermore, average contribution factor analysis of the input variables depicted that resistivity log, density log, gamma-ray log and depth interval had the factor of 44.23%, 22.68%, 20.16% and 12.98%, respectively, on the developed ANN model. Hence, the developed ANN model is a more robust tool to predict reservoir’s porosity, permeability and water saturation in the Niger Delta region.
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Abbreviations
- AC:
-
Acoustic log
- ANFIS:
-
Artificial neuro-fuzzy interference system
- ARE:
-
Average relative error
- AI:
-
Artificial intelligence
- ANN:
-
Artificial neural network
- BR:
-
Bayesian regularization
- CAL:
-
Caliper log
- CEC:
-
Cation exchange capacity
- CNL:
-
Compensated neutron porosity log
- CT:
-
Conductivity log
- DEN:
-
Formation density log
- DT:
-
Sonic log
- FFBP:
-
Feed-forward back-propagation
- FL:
-
Fuzzy logic
- FN:
-
Functional network
- GA:
-
Genetic algorithm
- HGAPSO:
-
Hybrid GA and PSO
- I5FR:
-
Microspherical focus log
- ICA:
-
Imperialist competitive algorithm
- LLD:
-
Deep laterolog
- LLS:
-
Shallow laterolog
- LM:
-
Levenberg–Marquardt
- LSSVM:
-
Least square support vector machine
- MIMO:
-
Multiple-inputs multiple-outputs
- MISO:
-
Multiple-inputs single-output
- MSE:
-
Mean square error
- NMR:
-
Nuclear magnetic resonance
- NPHI:
-
Neutron-porosity log
- PEF:
-
Photoelastic factor
- PHID:
-
Density-porosity log
- PHIE:
-
Effective porosity
- PHIT:
-
Total porosity
- PSO:
-
Particle swarm optimization
- R:
-
Correlation coefficient
- R2 :
-
Coefficient of determination
- RHOB:
-
Deep density log
- RL:
-
Resistivity log
- RMSE:
-
Root mean square error
- SCG:
-
Scaled conjugate gradient
- SFL:
-
Spherically focused log
- SP:
-
Spontaneous potential
- SVM:
-
Support vector machine
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Okon, A.N., Adewole, S.E. & Uguma, E.M. Artificial neural network model for reservoir petrophysical properties: porosity, permeability and water saturation prediction. Model. Earth Syst. Environ. 7, 2373–2390 (2021). https://doi.org/10.1007/s40808-020-01012-4
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DOI: https://doi.org/10.1007/s40808-020-01012-4