In recent years, the recent developments in data science (including machine learning) have attracted increased attention from researchers and practitioners from both academia and industry, for its proven ability to construct useful predictive models from large numbers of data. In comparison to data science, inverse and optimization theories have a relatively longer history within earth science. While various inverse and optimization methods have been well established and successfully applied to real-world problems, there is still room to further improve and strengthen their performance and applicability in terms of e.g. accuracy, computational efficiency, and uncertainty representation. The papers in this topic address various challenges in earth sciences, combining data science, inverse and/or optimization theories. Gao et al. present an extension of the distributed Gauss-Newton method to optimization problems that allows for large numbers of controls by use of a limited-memory BFGS scheme. In the distributed optimization approach, multiple parameter or control solutions are simultaneously updated in an iterative manner. The updates exploit information gathered in a growing database of intermediate solutions that allows for learning from distributed data. In contrast to ensemble methods, by selecting data based on distance, solutions are able to converge towards different modes, resulting in multiple distinct solutions.The presence of multiple modes in the posterior distribution is addressed in the context of inverse problems by Conjard and Omre. They define a selection Kalman model (SKM) as an extension of the traditional Kalman model for Gaussian distributions towards (spatially) multimodal distributions for linear-Gaussian forward models. In synthetic experiments, the SKM is found to outperform the traditional Kalman model, which tends to produce blurred distributions because of its tendency towards Gaussianity. The new approach could be the initial step towards an ensemble version that supports nonlinear forward models.Coutinho et al. consider the reduction of computational cost for expensive model-based workflows by use of proxy models. The idea here is to replace the large online cost associated with applying iterative procedures to many model realizations by a single offline training stage in which fast models are trained using machine learning techniques. The authors consider an extension of the socalled Embed to Control (E2C) approach, introduced into the geosciences for the purpose of simulating reservoir flow by Jin et al. (2020). In particular, various options for prediction and conditioning to well data are compared and the authors demonstrate that improved predictions can be obtained relative to those obtained with previously proposed reduced-order model approaches.Nasir et al. combine fast proxy models based on convolutional neural networks with deepreinforcement learning techniques to inform improved solutions for optimization problems that involve decisions on where to place wells to develop subsurface reservoir systems. By considering a very large training database constructed from randomly sampled model parameters, operational constraints and economic conditions, it is expected that valid optimized results can be generated almost instantly for new scenarios within the range of training data.Nezhadali et al. consider the use of reduced models obtained by multiple levels of domain coarsening in ensemble inversion workflows. The loss of accuracy associated with the models of multilevel fidelities could be balanced by an increased ensemble size, leading to lower Monte Carlo errors. A scheme is introduced to estimate and (approximately) account for the multilevel modelling error. The resulting workflow is applied to experiments with synthetic reservoir flow models, which suggest that the multilevel approach with error correction outperforms the conventional approach.Fablet et al. consider the challenges associated with the sparse sampling of observation data by earth-orbiting satellites. In particular, they investigate if it is possible to learn a representation of the processes underlying the observed data that could be used to interpolate to times that are not directly observed. The interpolation problem can be formulated as an optimization problem where parameters of a model is estimated such that some measure of the variance (or energy) in the interpolated model state is minimized. The authors consider neural network representations of an energy state and apply their proposed methodology to interpolate sea surface temperature and height data.Jiang et al. present a study in which the recently developed data-space inversion (DSI) method is extended with a parameterization technique based on a recurrent autoencoder (RAE). The DSI method enables fast updates of predictions based on new data without the need for explicit forward modelling. Instead, prior forecasts are added to the state vector and updated directly. The proposed parameterization enables a low-dimensional representation of the time series forecast data that can be seen as an alternative to more traditional PCA representations. The methodology is applied to a complex fractured reservoir system, which is operated with a detailed management logic that results in frequent changes to the wells in the reservoir.Lin et al. investigate the impact of ensemble-based inversion on forecast degradation caused by the introduction of shocks through the update of the dynamic model state. They propose an incremental update solution, as also adopted in stochastic ensemble smoothers that are frequently applied to parameter estimation problems, but in this case for the class of deterministic filter methods such as the Ensemble Transform Kalman Filter (ETKF). The new scheme is tested with a shallow-water model.The papers in this research topic cover a diverse range of application domains, fundamental and applied research, workflows (interpolation, inversion, optimization), and methods. They demonstrate that the earth sciences remain a fertile ground for exciting and promising new developments in advanced computational methods.
Editorial03 September 2021
Editorial: Data Science Applications to Inverse and Optimization Problems in Earth ScienceData-driven methods have been revolutionizing the way physicists and engineers handle complex and challenging problems even when the physics is not fully understood. However, these models very often lack interpretability. Physics-aware machine learning (ML) techniques have been used to endow proxy models with features closely related to the ones encountered in nature; examples span from material balance to conservation laws. In this paper, we proposed a hybrid-based approach that incorporates physical constraints (physics-based) and yet is driven by input/output data (data-driven), leading to fast, reliable, and interpretable reservoir simulation models. To this end, we built on a recently developed deep-learning-based reduced-order modeling framework by adding a new step related to information of the input-output behavior (e.g., well rates) of the reservoir and not only the states (e.g., pressure and saturation) matching. A deep-neural network (DNN) architecture is used to predict the state variables evolution after training an autoencoder coupled with a control system approach (Embed to Control - E2C) along with the addition of some physical components (Loss functions) to the neural network training procedure. Here, we extend this idea by adding the simulation model output, e.g., well bottom-hole pressure and well flowrates, as data to be used in the training procedure. Additionally, we introduce a new architecture to the E2C transition model by adding a new neural network component to handle the connections between state variables and model outputs. By doing this, it is possible to estimate the evolution in time of both the state and output variables simultaneously. Such a non-intrusive data-driven method does not need to have access to the reservoir simulation internal structure, so it can be easily applied to commercial reservoir simulators. The proposed method is applied to an oil-water model with heterogeneous permeability, including 4 injectors and 5 producer wells. We used 300 sampled well control sets to train the autoencoder and another set to validate the obtained autoencoder parameters. We show our proxy's accuracy and robustness by running two different neural network architectures (propositions 2 and 3), and we compare our results with the original E2C framework developed for reservoir simulation.
Oil and gas field development optimization, which involves the determination of the optimal number of wells, their drilling sequence and locations while satisfying operational and economic constraints, represents a challenging computational problem. In this work, we present a deep reinforcement learning-based artificial intelligence agent that could provide optimized development plans given a basic description of the reservoir and rock/fluid properties with minimal computational cost. This artificial intelligence agent, comprising of a convolutional neural network, provides a mapping from a given state of the reservoir model, constraints, and economic condition to the optimal decision (drill/do not drill and well location) to be taken in the next stage of the defined sequential field development planning process. The state of the reservoir model is defined using parameters that appear in the governing equations of the two-phase flow (such as well index, transmissibility, fluid mobility, and accumulation, etc.).
A feedback loop training process referred to as deep reinforcement learning is used to train an artificial intelligence agent with such a capability. The training entails millions of flow simulations (of order thousands of equivalent distributed simulations) with varying reservoir model descriptions (structural, rock and fluid properties), operational constraints (maximum liquid production, drilling duration, and water-cut limit), and economic conditions. The parameters that define the reservoir model, operational constraints, and economic conditions are randomly sampled from a defined range of applicability. Several algorithmic treatments are introduced to enhance the training of the artificial intelligence agent. After appropriate training, the artificial intelligence agent provides an optimized field development plan instantly for new scenarios within the defined range of applicability. This approach has advantages over traditional optimization algorithms (e.g., particle swarm optimization, genetic algorithm) that are generally used to find a solution for a specific field development scenario and typically not generalizable to different scenarios. The performance of the artificial intelligence agents for two- and three-dimensional subsurface flow are compared to well-pattern agents. Optimization results using the new procedure are shown to significantly outperform those from the well pattern agents.


