Abstract

This paper develops a reliable deep-learning framework to extract latent features from spatial properties and investigates adaptive surrogate estimation to sequester CO2 into heterogeneous deep saline aquifers. Our deep-learning architecture includes a deep convolutional autoencoder (DCAE) and a fully-convolutional network to not only reduce computational costs but also to extract dimensionality-reduced features to conserve spatial characteristics. The workflow integrates two different spatial properties within a single convolutional system, and it also achieves accurate reconstruction performance. This approach significantly reduces the number of parameters to 4.3% of the original number required, e.g., the number of three-dimensional spatial properties needed decreases from 44,460 to 1920. The successful dimensionality reduction is accomplished by the DCAE system regarding all inputs as image channels from the initial stage of learning using the fully-convolutional network instead of fully-connected layers. The DCAE reconstructs spatial parameters such as permeability and porosity while conserving their statistical values, i.e., their mean and standard deviation, achieving R-squared values of over 0.972 with a mean absolute percentage error of their mean values of less than 1.79%. The adaptive surrogate model using the latent features extracted by DCAE, well operations, and modeling parameters is able to accurately estimate CO2 sequestration performances. The model shows R-squared values of over 0.892 for testing data not used in training and validation. The DCAE-based surrogate estimation exploits the reliable integration of various spatial data within the fully-convolutional network and allows us to evaluate flow behavior occurring in a subsurface domain.

Highlights

  • Data science has revolutionized engineering analytics in the oil and gas industry

  • This paper develops an adaptive surrogate model based on a deep convolutional autoencoder (DCAE) for CO2 sequestration into deep saline aquifers that conserves the spatial distribution of rock properties such as permeability and porosity

  • 22,230 (=38 × 45 × 13) permeability values are input; the DCAE reconstructed these for each geo-model, and thereby one mean and one standard deviation are evaluated for each geo-model

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Summary

Introduction

Data science has revolutionized engineering analytics in the oil and gas industry. Datadriven analyses are assisting the decision-making process making it more reliable as well as more efficient [1,2,3,4,5]. CNN was introduced to restore spatial features during image processing [17] It typically consists of one or more of pooling, convolutional, and fully-connected layers. Some researchers that have implemented autoencoders for modeling fluid flow have shown that dimensionality reduction (feature extraction) can improve computational efficiency, and, thereby, estimate oil-gas-water production behavior more accurately [18,21,22,23,24,25,26]. The autoencoder consists of a recognition network (encoder) and a generative network (decoder): The encoder uses the dimensionality reduction to compress the original inputs into a smaller set of parameters (the extracted features), while the decoder is used to reconstruct plausible outputs that correspond suitably with the inputs These systems are symmetric and typically have several hidden layers. Observation of the statistical distributions of rock properties, reconstructed by the decoding process, examines the reliability of conserving spatiotemporal values

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