Retracted: Sequestration and Enhanced Shale Gas Recovery by Injection: Numerical Simulation Method
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VIEW CORRECTIONThis article has been corrected.
VIEW CORRECTIONPublication: Journal of Energy Engineering
Volume 148, Issue 2
Abstract
In previous decades, shale gas production has been given special attention as a clean source of energy. Technological advancements in multi-well especially horizontal drilling and hydraulic fracturing, have raised more research on how to produce shale gas commercially while studying its challenges. gas production by using injection is a combination of several parameters, including both fracking and geologic parameters. This paper investigated the influence of aligned and staggered multiwell placement patterns to enhance gas recovery and sequestration. A three-dimensional reservoir model was built and simulated, and the influence of reservoir and fracking parameters was analyzed. The results revealed that the staggered well pattern is the best pattern for gas recovery during continuous injection, with a 37% increase of recovery with late breakthrough, compared with the aligned well pattern, which had 31% increase recovery, associated with early breakthrough. In terms of gas storage, the aligned well pattern had a significant amount of storage during continuous injection and huff and puff injection by storing 4% more carbon dioxide during continuous injection and 7% more during huff and puff injection than that in the staggered well pattern. Different injection timings of 1, 2, and 3 years, and injection cycles of one, three, and five cycles were analyzed during huff and puff injection. The results showed that five cycles of injection had the highest methane gas recovery, 23% and 21%, in aligned and staggered well patterns, respectively. Furthermore, the influence of injection start time also was analyzed, and results showed that injection after 10 years of production produced higher methane gas recovery and storage in both aligned and staggered well patterns, followed by injection after 5 years of production, after 3 years of production, and during the first year of production. Sensitivity analysis revealed that horizontal matrix permeability, vertical matrix permeability, initial reservoir pressure, reservoir temperature, injection pressure, injection rate, fracture porosity, and fracture spacing played a vital role in both methane gas recovery and carbon dioxide gas storage in both well patterns. In addition, results showed that methane recovered during continuous injection is higher than during huff and puff injection in both aligned and staggered well patterns. Results obtained from this paper can help to improve shale gas production in multiwell placements, and save time and cost. This paper should motivate more research into the mitigation of global warming through geosequestration.
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Data Availability Statement
Some or all data, models, or code generated or used during the study are proprietary or confidential in nature and may be provided only with restrictions. Confidential data which can be shared with restriction are effective Knudsen diffusion coefficient, surface diffusion coefficient, adsorption gas concentration, intrinsic permeability of bedrock, pore pressure in the bedrock, gas concentration in porous media, adsorption gas concentration, effective molecular diffusion coefficients of gas components, and the dimensional molecular constant. Other data can be shared without restriction.
Acknowledgments
The authors give special appreciation to the Chinese Scholarship Council for providing funds during the study time at which this paper was written. The authors appreciate the scholarship provided by the Chinese scholarship council (2019GBJ002437).
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Journal of Energy Engineering
Volume 148 • Issue 2 • April 2022
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© 2022 American Society of Civil Engineers.
History
Received: Jul 20, 2021
Accepted: Dec 15, 2021
Published online: Feb 15, 2022
Published in print: Apr 1, 2022
Discussion open until: Jul 15, 2022
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