Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir
Gas channeling treatment is a huge challenge for oil displacement and CO<sub>2</sub> sequestration in the practical CO<sub>2</sub> flooding process. The foaming agents can be used in the gas flooding process, which presents good application potential for gas channeling blocka...
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| author | Mei Tian Yi Wu Yuhua Shi Guohua Cao Yu Sun Maozhu Li Wei Wang Li Gao Zhipeng Wang Yiqiang Li |
| author_facet | Mei Tian Yi Wu Yuhua Shi Guohua Cao Yu Sun Maozhu Li Wei Wang Li Gao Zhipeng Wang Yiqiang Li |
| author_sort | Mei Tian |
| collection | DOAJ |
| description | Gas channeling treatment is a huge challenge for oil displacement and CO<sub>2</sub> sequestration in the practical CO<sub>2</sub> flooding process. The foaming agents can be used in the gas flooding process, which presents good application potential for gas channeling blockage. However, high temperature can affect surfactant foaming properties. This work takes a high-temperature heterogenous sandstone oil reservoir as an example; the foaming performance of different surfactants was evaluated via foamability, thermal stability, crude oil tolerance ability, and dynamic blocking capacity. The profile control performance of the optimized foaming agent was investigated via dual-core gas flooding experiments. (1) The results show that QPJ-c featured good foaming stability, which made it present the largest foam comprehensive index, although its foaming volume was slightly lower than that of QPJ-b. Its foaming volume retention rate was 83.2%, and its half-life retention rate remained 88.9% after 30 days aging at a temperature of 110 °C. (2) The foam resistance factor increased from 7 to 17 when the core permeability increased from 2 mD to 20 mD. This indicated that the high-permeability zone could be preferentially blocked by foam during the foam injection. (3) The dual-core flooding experiments verified that the fractional flow of the high-permeability core severely decreased due to the blockage of foam. The incremental oil recovery of the low-permeability core was 27.1% when the permeability ratio was 5. It increased to 40% when the permeability ratio was increased to 10. (4) Our work indicates that temperature-resistant CO<sub>2</sub> foam could be a good candidate for profile control during CO<sub>2</sub> flooding in the target reservoir. |
| format | Article |
| id | doaj-art-a798ad515e754cf884174b71b5772e40 |
| institution | Kabale University |
| issn | 1996-1073 |
| language | English |
| publishDate | 2024-12-01 |
| publisher | MDPI AG |
| record_format | Article |
| series | Energies |
| spelling | doaj-art-a798ad515e754cf884174b71b5772e402025-01-10T13:17:03ZengMDPI AGEnergies1996-10732024-12-011818910.3390/en18010089Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous ReservoirMei Tian0Yi Wu1Yuhua Shi2Guohua Cao3Yu Sun4Maozhu Li5Wei Wang6Li Gao7Zhipeng Wang8Yiqiang Li9Research Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaResearch Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaResearch Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaResearch Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaState Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing), Beijing 102249, ChinaState Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing), Beijing 102249, ChinaResearch Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaResearch Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin 124010, ChinaState Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing), Beijing 102249, ChinaState Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing), Beijing 102249, ChinaGas channeling treatment is a huge challenge for oil displacement and CO<sub>2</sub> sequestration in the practical CO<sub>2</sub> flooding process. The foaming agents can be used in the gas flooding process, which presents good application potential for gas channeling blockage. However, high temperature can affect surfactant foaming properties. This work takes a high-temperature heterogenous sandstone oil reservoir as an example; the foaming performance of different surfactants was evaluated via foamability, thermal stability, crude oil tolerance ability, and dynamic blocking capacity. The profile control performance of the optimized foaming agent was investigated via dual-core gas flooding experiments. (1) The results show that QPJ-c featured good foaming stability, which made it present the largest foam comprehensive index, although its foaming volume was slightly lower than that of QPJ-b. Its foaming volume retention rate was 83.2%, and its half-life retention rate remained 88.9% after 30 days aging at a temperature of 110 °C. (2) The foam resistance factor increased from 7 to 17 when the core permeability increased from 2 mD to 20 mD. This indicated that the high-permeability zone could be preferentially blocked by foam during the foam injection. (3) The dual-core flooding experiments verified that the fractional flow of the high-permeability core severely decreased due to the blockage of foam. The incremental oil recovery of the low-permeability core was 27.1% when the permeability ratio was 5. It increased to 40% when the permeability ratio was increased to 10. (4) Our work indicates that temperature-resistant CO<sub>2</sub> foam could be a good candidate for profile control during CO<sub>2</sub> flooding in the target reservoir.https://www.mdpi.com/1996-1073/18/1/89CO<sub>2</sub> floodinggas channelingCO<sub>2</sub> foamdual-core floodingfoam property evaluation |
| spellingShingle | Mei Tian Yi Wu Yuhua Shi Guohua Cao Yu Sun Maozhu Li Wei Wang Li Gao Zhipeng Wang Yiqiang Li Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir Energies CO<sub>2</sub> flooding gas channeling CO<sub>2</sub> foam dual-core flooding foam property evaluation |
| title | Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir |
| title_full | Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir |
| title_fullStr | Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir |
| title_full_unstemmed | Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir |
| title_short | Experimental Investigation on Temperature-Resistant CO<sub>2</sub> Foam Flooding in a Heterogenous Reservoir |
| title_sort | experimental investigation on temperature resistant co sub 2 sub foam flooding in a heterogenous reservoir |
| topic | CO<sub>2</sub> flooding gas channeling CO<sub>2</sub> foam dual-core flooding foam property evaluation |
| url | https://www.mdpi.com/1996-1073/18/1/89 |
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