Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation
Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the co...
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| Format: | Article |
| Language: | English |
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MDPI AG
2021-07-01
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| Series: | Energies |
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| Online Access: | https://www.mdpi.com/1996-1073/14/15/4580 |
| _version_ | 1827686607508996096 |
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| author | Yongchao Wang Yanqing Xia Zihui Feng Hongmei Shao Junli Qiu Suping Ma Jiaqiang Zhang Haoyuan Jiang Jiyong Li Bo Gao Lingling Li |
| author_facet | Yongchao Wang Yanqing Xia Zihui Feng Hongmei Shao Junli Qiu Suping Ma Jiaqiang Zhang Haoyuan Jiang Jiyong Li Bo Gao Lingling Li |
| author_sort | Yongchao Wang |
| collection | DOAJ |
| description | Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens. |
| first_indexed | 2024-03-10T09:16:19Z |
| format | Article |
| id | doaj.art-c7dfec68a6e74c99a54514c6b5ed9452 |
| institution | Directory Open Access Journal |
| issn | 1996-1073 |
| language | English |
| last_indexed | 2024-03-10T09:16:19Z |
| publishDate | 2021-07-01 |
| publisher | MDPI AG |
| record_format | Article |
| series | Energies |
| spelling | doaj.art-c7dfec68a6e74c99a54514c6b5ed94522023-11-22T05:34:59ZengMDPI AGEnergies1996-10732021-07-011415458010.3390/en14154580Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network SimulationYongchao Wang0Yanqing Xia1Zihui Feng2Hongmei Shao3Junli Qiu4Suping Ma5Jiaqiang Zhang6Haoyuan Jiang7Jiyong Li8Bo Gao9Lingling Li10Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaResearch Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, ChinaResearch Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaNorthwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, ChinaResearch Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, ChinaResearch Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, ChinaPore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens.https://www.mdpi.com/1996-1073/14/15/4580shale oilmobilitypore network modelrelative permeability |
| spellingShingle | Yongchao Wang Yanqing Xia Zihui Feng Hongmei Shao Junli Qiu Suping Ma Jiaqiang Zhang Haoyuan Jiang Jiyong Li Bo Gao Lingling Li Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation Energies shale oil mobility pore network model relative permeability |
| title | Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation |
| title_full | Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation |
| title_fullStr | Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation |
| title_full_unstemmed | Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation |
| title_short | Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation |
| title_sort | microscale evaluation of tight oil mobility insights from pore network simulation |
| topic | shale oil mobility pore network model relative permeability |
| url | https://www.mdpi.com/1996-1073/14/15/4580 |
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