Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield
The flow mechanism of the injected fluid was studied by the constant pressure core displacement experiments in the paper. It is assumed under condition of the constant pressure gradient in deep formation based on the characteristic of pressure gradient distribution between the injection and producti...
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| Main Authors: | , , , , |
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| Format: | Article |
| Language: | English |
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Wiley
2015-01-01
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| Series: | Advances in Materials Science and Engineering |
| Online Access: | http://dx.doi.org/10.1155/2015/139284 |
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| author | Qing Fang Jinfeng Chen Chunnan Lu Dandan Yin Yiqiang Li |
| author_facet | Qing Fang Jinfeng Chen Chunnan Lu Dandan Yin Yiqiang Li |
| author_sort | Qing Fang |
| collection | DOAJ |
| description | The flow mechanism of the injected fluid was studied by the constant pressure core displacement experiments in the paper. It is assumed under condition of the constant pressure gradient in deep formation based on the characteristic of pressure gradient distribution between the injection and production wells and the mobility of different polymer systems in deep reservoir. Moreover, the flow rate of steady stream was quantitatively analyzed and the critical flow pressure gradient of different injection parameters polymer solutions in different permeability cores was measured. The result showed that polymer hydrodynamic feature size increases with the increasing molecular weight. If the concentration of polymer solutions overlaps beyond critical concentration, then molecular chains entanglement will be occur and cause the augment of its hydrodynamic feature size. The polymer hydrodynamic feature size decreased as the salinity of the dilution water increased. When the median radius of the core pore and throat was 5–10 times of the polymer system hydrodynamic feature size, the polymer solution had a better compatibility with the microscopic pore structure of the reservoir. The estimation of polymer solutions mobility in the porous media can be used to guide the polymer displacement plan and select the optimum injection parameters. |
| format | Article |
| id | doaj-art-724bd3d67b3e43a2a3a2daff7c49e9e6 |
| institution | OA Journals |
| issn | 1687-8434 1687-8442 |
| language | English |
| publishDate | 2015-01-01 |
| publisher | Wiley |
| record_format | Article |
| series | Advances in Materials Science and Engineering |
| spelling | doaj-art-724bd3d67b3e43a2a3a2daff7c49e9e62025-08-20T02:06:27ZengWileyAdvances in Materials Science and Engineering1687-84341687-84422015-01-01201510.1155/2015/139284139284Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing OilfieldQing Fang0Jinfeng Chen1Chunnan Lu2Dandan Yin3Yiqiang Li4Northeast Petroleum University, Daqing, Heilongjiang 163318, ChinaOil Recovery Plant No. 2, Daqing Oilfield Corp. Ltd., Daqing, Heilongjiang 163256, ChinaOil Recovery Plant No. 2, Daqing Oilfield Corp. Ltd., Daqing, Heilongjiang 163256, ChinaEOR Research Institute, China University of Petroleum-Beijing, Beijing 102249, ChinaEOR Research Institute, China University of Petroleum-Beijing, Beijing 102249, ChinaThe flow mechanism of the injected fluid was studied by the constant pressure core displacement experiments in the paper. It is assumed under condition of the constant pressure gradient in deep formation based on the characteristic of pressure gradient distribution between the injection and production wells and the mobility of different polymer systems in deep reservoir. Moreover, the flow rate of steady stream was quantitatively analyzed and the critical flow pressure gradient of different injection parameters polymer solutions in different permeability cores was measured. The result showed that polymer hydrodynamic feature size increases with the increasing molecular weight. If the concentration of polymer solutions overlaps beyond critical concentration, then molecular chains entanglement will be occur and cause the augment of its hydrodynamic feature size. The polymer hydrodynamic feature size decreased as the salinity of the dilution water increased. When the median radius of the core pore and throat was 5–10 times of the polymer system hydrodynamic feature size, the polymer solution had a better compatibility with the microscopic pore structure of the reservoir. The estimation of polymer solutions mobility in the porous media can be used to guide the polymer displacement plan and select the optimum injection parameters.http://dx.doi.org/10.1155/2015/139284 |
| spellingShingle | Qing Fang Jinfeng Chen Chunnan Lu Dandan Yin Yiqiang Li Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield Advances in Materials Science and Engineering |
| title | Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield |
| title_full | Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield |
| title_fullStr | Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield |
| title_full_unstemmed | Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield |
| title_short | Study on Relation between Hydrodynamic Feature Size of HPAM and Pore Size of Reservoir Rock in Daqing Oilfield |
| title_sort | study on relation between hydrodynamic feature size of hpam and pore size of reservoir rock in daqing oilfield |
| url | http://dx.doi.org/10.1155/2015/139284 |
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