Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition
Imbibition and flowback of fracturing fluid usually occur in the shale matrix after hydraulic fracturing, which significantly impacts shale gas production and environmental protection. The rocks of deep shale gas reservoirs are under high-temperature and high-temperature conditions. There are rich m...
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| Format: | Article |
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Frontiers Media S.A.
2023-03-01
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| Series: | Frontiers in Earth Science |
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| Online Access: | https://www.frontiersin.org/articles/10.3389/feart.2023.1138938/full |
| _version_ | 1811158316454248448 |
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| author | Shuai Wu Shuai Wu Jianfa Wu Jianfa Wu Yong Liu Xuefeng Yang Xuefeng Yang Juan Zhang Jian Zhang Jian Zhang Deliang Zhang Deliang Zhang Bing Zhong Dongchen Liu Dongchen Liu |
| author_facet | Shuai Wu Shuai Wu Jianfa Wu Jianfa Wu Yong Liu Xuefeng Yang Xuefeng Yang Juan Zhang Jian Zhang Jian Zhang Deliang Zhang Deliang Zhang Bing Zhong Dongchen Liu Dongchen Liu |
| author_sort | Shuai Wu |
| collection | DOAJ |
| description | Imbibition and flowback of fracturing fluid usually occur in the shale matrix after hydraulic fracturing, which significantly impacts shale gas production and environmental protection. The rocks of deep shale gas reservoirs are under high-temperature and high-temperature conditions. There are rich micro-nano pores with various pore structures in deep shale. In addition, the flowback behavior is significantly affected by the imbibition behavior because the flowback begins after the end of the imbibition. Therefore, an accurate pore-scale description of the coupled imbibition-flowback behavior is crucial to understand the flowback mechanism and its impacts. In this paper, a pseudo-potential lattice Boltzmann method is employed to simulate the coupled imbibition-flowback behavior in a digital shale core, where the digital core is reconstructed by Markov Chain-Monte Carlo method based on scanning microscope images of deep shale cores. The microcosmic mechanism of the imbibition and flowback is studied under deep shale conditions. The influence of some factors, such as pore structure, fluid viscosity, wettability, and flowback pressure difference, on the flowback behavior of fracturing fluid is investigated. It is found that the fracturing fluid advances almost uniformly throughout the pore space during the imbibition process. The fracturing fluid is easy to adsorb on the pore wall, and the shale gas is located in the middle of the pore space. The viscous fingering is clearly observed during the flowback process, where shale gas flows through large pores to form a flow channel, and the fracturing fluid stays in tiny pores. The flowback rate increases gradually with the flowback time and eventually tends to be almost constant. The wettability, flowback pressure difference, and pore structure significantly influence the flowback behavior, while the fracturing fluid viscosity has a smaller effect on the flowback process. |
| first_indexed | 2024-04-10T05:22:27Z |
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| institution | Directory Open Access Journal |
| issn | 2296-6463 |
| language | English |
| last_indexed | 2024-04-10T05:22:27Z |
| publishDate | 2023-03-01 |
| publisher | Frontiers Media S.A. |
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| series | Frontiers in Earth Science |
| spelling | doaj.art-7224b8b32e0849888558c554410e86a92023-03-08T06:30:39ZengFrontiers Media S.A.Frontiers in Earth Science2296-64632023-03-011110.3389/feart.2023.11389381138938Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir conditionShuai Wu0Shuai Wu1Jianfa Wu2Jianfa Wu3Yong Liu4Xuefeng Yang5Xuefeng Yang6Juan Zhang7Jian Zhang8Jian Zhang9Deliang Zhang10Deliang Zhang11Bing Zhong12Dongchen Liu13Dongchen Liu14Shale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaShale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaGas Field Development Management Department, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaShale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaExploration and Development Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaShale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaShale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaTechnical Consulting Center, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaShale Gas Research Institute, PetroChina Southwest Oil and Gasfield Company, Chengdu, Sichuan, ChinaKey Laboratory of Shale Gas Evaluation and Production in Sichuan Province, Chengdu, Sichuan, ChinaImbibition and flowback of fracturing fluid usually occur in the shale matrix after hydraulic fracturing, which significantly impacts shale gas production and environmental protection. The rocks of deep shale gas reservoirs are under high-temperature and high-temperature conditions. There are rich micro-nano pores with various pore structures in deep shale. In addition, the flowback behavior is significantly affected by the imbibition behavior because the flowback begins after the end of the imbibition. Therefore, an accurate pore-scale description of the coupled imbibition-flowback behavior is crucial to understand the flowback mechanism and its impacts. In this paper, a pseudo-potential lattice Boltzmann method is employed to simulate the coupled imbibition-flowback behavior in a digital shale core, where the digital core is reconstructed by Markov Chain-Monte Carlo method based on scanning microscope images of deep shale cores. The microcosmic mechanism of the imbibition and flowback is studied under deep shale conditions. The influence of some factors, such as pore structure, fluid viscosity, wettability, and flowback pressure difference, on the flowback behavior of fracturing fluid is investigated. It is found that the fracturing fluid advances almost uniformly throughout the pore space during the imbibition process. The fracturing fluid is easy to adsorb on the pore wall, and the shale gas is located in the middle of the pore space. The viscous fingering is clearly observed during the flowback process, where shale gas flows through large pores to form a flow channel, and the fracturing fluid stays in tiny pores. The flowback rate increases gradually with the flowback time and eventually tends to be almost constant. The wettability, flowback pressure difference, and pore structure significantly influence the flowback behavior, while the fracturing fluid viscosity has a smaller effect on the flowback process.https://www.frontiersin.org/articles/10.3389/feart.2023.1138938/fullimbibition and flowbacklattice Boltzmann methoddeep shaledigital coremicrocosmic mechanism |
| spellingShingle | Shuai Wu Shuai Wu Jianfa Wu Jianfa Wu Yong Liu Xuefeng Yang Xuefeng Yang Juan Zhang Jian Zhang Jian Zhang Deliang Zhang Deliang Zhang Bing Zhong Dongchen Liu Dongchen Liu Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition Frontiers in Earth Science imbibition and flowback lattice Boltzmann method deep shale digital core microcosmic mechanism |
| title | Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition |
| title_full | Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition |
| title_fullStr | Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition |
| title_full_unstemmed | Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition |
| title_short | Lattice Boltzmann modeling of the coupled imbibition-flowback behavior in a 3D shale pore structure under reservoir condition |
| title_sort | lattice boltzmann modeling of the coupled imbibition flowback behavior in a 3d shale pore structure under reservoir condition |
| topic | imbibition and flowback lattice Boltzmann method deep shale digital core microcosmic mechanism |
| url | https://www.frontiersin.org/articles/10.3389/feart.2023.1138938/full |
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