Artificial neural network prediction models for Montney shale gas production profile based on reservoir and fracture network parameters

• Published in: Energy (Oxford) Vol. 244; p. 123150
• Main Authors: Nguyen-Le, Viet, Shin, Hyundon
• Format: Journal Article
• Language: English
• Published: Oxford Elsevier Ltd 01.04.2022; Elsevier BV
• Subjects: Artificial neural network; Artificial neural networks; Decline parameter; Design parameters; Economic models; Feasibility studies; Fracture network; Gas production; Gas wells; Hydraulic fracturing; Mathematical models; Neural networks; Oil and gas production; Parameter estimation; Peak production rate; Prediction model; Prediction models; Predictions; Project feasibility; Reservoirs; Shale; Shale gas; Shales; Simulation; Peak production rate; Artificial neural network; Fracture network; Prediction model; Shale gas; Decline parameter
• ISSN: 0360-5442; 1873-6785
• DOI: 10.1016/j.energy.2022.123150

The prediction of shale gas production is necessary to evaluate the project's economical feasibility. Some studies suggested prediction models for predicting shale gas production. However, the model-based planar fracture assumption may not apply to a naturally fractured shale gas reservoir which induces a complex fracture network. This paper proposes three ANN architectures for predicting the peak production and Arps's hyperbolic decline parameters (Di and b) of a shale gas well in the Montney formation with an existing natural fracture system. A production profile can be reconstructed using the Arps' hyperbolic decline model and the predicted parameters. The ANN architectures were developed based on 370 simulation data of the reservoir, hydraulic fracture design parameters, and the fracture network properties, including fracture spacing and fracture conductivity, which remarkably affect shale gas production. The testing results, using another set of 92 simulation data, confirmed the high correlation between the input and objective functions with R2 > 0.86. Moreover, good agreement was observed between the measured and predicted cumulative gas production at one-, five-, ten-, fifteen-, and twenty-years of production with R2 > 0.94, and percentage errors were lower than 15.6%. This suggests that the shale gas production can be predicted efficiently and reliably using the Arps' hyperbolic model and the predicted parameters. The estimated production profiles can be used to continuously update the field development plans and calculate the project's NPV. Furthermore, the proposed method is applicable for predicting the production of newly produced reservoirs with limited production history. •ANN prediction models based on shale reservoir and network fracture parameters.•A production profile can be estimated using a DCA model and decline parameters.•The predicted production profile yields continuous field development plan updates.•The proposed prediction models can be applied to newly produced reservoirs.