Software for CO2 Storage in Natural Gas Reservoirs
The paper presents a simulation-based approach for optimizing CO2 injection into depleted gas reservoirs, with the goal of enhancing underground CO2 storage. The research employs a two-dimensional dynamic reservoir model, developed using Darcy’s law, to describe gas flow in a pressure-homogeneous po...
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| Vydáno v: | Energies (Basel) Ročník 17; číslo 19; s. 4984 |
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| Médium: | Journal Article |
| Jazyk: | angličtina |
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Basel
MDPI AG
01.10.2024
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| ISSN: | 1996-1073, 1996-1073 |
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| Abstract | The paper presents a simulation-based approach for optimizing CO2 injection into depleted gas reservoirs, with the goal of enhancing underground CO2 storage. The research employs a two-dimensional dynamic reservoir model, developed using Darcy’s law, to describe gas flow in a pressure-homogeneous porous medium, along with real gas equations. The model integrates the Du Fort–Frenkel and finite-difference methods to accurately simulate the behavior of CO2 during injection and storage. Real data from an operational gas storage facility were used to calibrate the model. CO2sim v1 software, specifically developed for this purpose, simulates CO2 injection cycles and quiescence phases, enabling the optimization of storage capacity and energy efficiency. The reservoir model, based on the engineering of the geological structure, is discretized into approximately 16,000 cells and solved using the finite-difference method, allowing for rapid simulation of CO2 injection and quiescence processes. The average computation time for a 150-day cycle is approximately 5 min. Simulation results indicate that increasing the number of injection wells and carefully controlling the injection rates significantly improves the distribution of CO2 within the reservoir, thereby enhancing storage efficiency. Additionally, appropriate well placement and prolonged quiescence periods lead to better CO2 dispersion, increasing the storage potential while reducing energy costs. The study concludes that further development of the software, along with comprehensive technical and economic assessments, is required to fully optimize CO2 storage on a commercial scale. |
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| AbstractList | The paper presents a simulation-based approach for optimizing CO2 injection into depleted gas reservoirs, with the goal of enhancing underground CO2 storage. The research employs a two-dimensional dynamic reservoir model, developed using Darcy’s law, to describe gas flow in a pressure-homogeneous porous medium, along with real gas equations. The model integrates the Du Fort–Frenkel and finite-difference methods to accurately simulate the behavior of CO2 during injection and storage. Real data from an operational gas storage facility were used to calibrate the model. CO2sim v1 software, specifically developed for this purpose, simulates CO2 injection cycles and quiescence phases, enabling the optimization of storage capacity and energy efficiency. The reservoir model, based on the engineering of the geological structure, is discretized into approximately 16,000 cells and solved using the finite-difference method, allowing for rapid simulation of CO2 injection and quiescence processes. The average computation time for a 150-day cycle is approximately 5 min. Simulation results indicate that increasing the number of injection wells and carefully controlling the injection rates significantly improves the distribution of CO2 within the reservoir, thereby enhancing storage efficiency. Additionally, appropriate well placement and prolonged quiescence periods lead to better CO2 dispersion, increasing the storage potential while reducing energy costs. The study concludes that further development of the software, along with comprehensive technical and economic assessments, is required to fully optimize CO2 storage on a commercial scale. |
| Author | Eparu, Cristian Nicolae Dumitrache, Liviu Doukeh, Rami Stoica, Doru Bogdan Prundurel, Alina Stan, Ioana Gabriela Suditu, Silvian Ghețiu, Iuliana Veronica |
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| Cites_doi | 10.1007/s12182-019-0340-8 10.1016/j.earscirev.2021.103895 10.1016/j.earscirev.2024.104793 10.3390/pr11030805 10.1016/j.cscee.2023.100422 10.1016/j.rser.2017.01.011 10.1016/j.petlm.2017.05.005 10.1016/j.oneear.2021.10.002 10.1016/j.fuel.2024.132411 10.1038/s41598-023-43773-9 10.1016/j.earscirev.2023.104672 10.1017/9781009157896 10.1016/j.egypro.2016.01.036 10.1017/9781009157940 10.1016/j.jhydrol.2024.130715 10.1016/B978-0-12-814934-8.00008-9 |
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| Copyright | 2024 by the authors. Licensee MDPI, Basel, Switzerland. This article is an open access article distributed under the terms and conditions of the Creative Commons Attribution (CC BY) license (https://creativecommons.org/licenses/by/4.0/). Notwithstanding the ProQuest Terms and Conditions, you may use this content in accordance with the terms of the License. |
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| SubjectTerms | Aquifers Boundary conditions Carbon sequestration Climate change CO2 storage dynamic numerical simulation Estimates Geology Global warming Greenhouse gases Paris Agreement reservoir Simulation Software |
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| Title | Software for CO2 Storage in Natural Gas Reservoirs |
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