Physics-Guided Learning for Bottomhole Pressure Estimation During Gas Lift in Shale Reservoirs
This paper introduces a physics-guided learning (PGL) to predict flowing bottomhole pressure (FBHP) in shale oil wells undergoing gas-lift operations, overcoming the limitations of data-driven models. We analyze reservoirs, wells, and operational data from 21 Permian Basin shale wells. Several PVT and pipe-flow correlations are investigated to determine the calculation of the flowing bottomhole pressure. Then, FBHP is constrained by both the domain-knowledge item and the single-phase gas and liquid flow physics-based models, with their elevation and friction terms embedded as differentiable operators in the neural network's loss. The PGL is designed to map depth and well inputs, such as diameter, liquid/gas rates, and wellhead pressure, to FBHP. Training combined physics loss, domain knowledge, and gauge data penalties. Hyperparameters such as layers, neurons, activation functions, and learning rates were tuned using genetic algorithms, with 5-fold cross-validation to ensure generalization. The model's performance is benchmarked against empirical and data-driven models for blind wells. The analysis of operational, production, and reservoir parameters shows that hydrocarbon fluid properties, well depth, operating valve depth, wellhead and bottomhole temperatures, wellhead pressure, and liquid and gas rates are key factors influencing FBHP during gas-lift operations. The qualitative relationships are then embedded into the artificial neural network. The PGL hyperparameters are optimized, including the number of layers, the number of neurons, the activation function, and the optimizer. The comparison between PGL and data-driven ANN models showed that PGL outperformed conventional deep learning models in terms of accuracy and stability. Embedded physics acts as a powerful regularizer, preventing overfitting and ensuring the model's reliability, especially in long-term predictions where purely data-based models may fail. The model successfully captures the complex transient dynamics of the wellbore, yielding physically plausible results even with sparse field data. This reliable predictive capability enables continuous optimization of gas injection rates to maintain an ideal reservoir drawdown, a key factor in maximizing the well's ultimate oil recovery. The proposed PGL explicitly embeds the governing equations of well-established flow correlations and qualitative relationships. Unlike other hybrid models that infer physics implicitly from data patterns, our approach mathematically enforces proven engineering principles during training. This creates a tailored "grey-box" model that is more accurate and physically consistent for the specific challenge of dynamic gas-lift operations, providing practicing engineers with a more robust and reliable tool to optimize production and enhance oil recovery.
Read more