Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas
The techniques of pressurized mining and hydraulic fracturing are often used to improve gas well productivity at the later development stage of low-permeability carbonate gas reservoirs, but reservoirs are watered out and a great number of micro fractures are produced. Therefore, one of the key fact...
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| Format: | Article |
| Language: | English |
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KeAi Communications Co., Ltd.
2016-11-01
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| Series: | Natural Gas Industry B |
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| Online Access: | http://www.sciencedirect.com/science/article/pii/S235285401730013X |
| _version_ | 1797284062658822144 |
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| author | Yufei Tan Chuankai Niu |
| author_facet | Yufei Tan Chuankai Niu |
| author_sort | Yufei Tan |
| collection | DOAJ |
| description | The techniques of pressurized mining and hydraulic fracturing are often used to improve gas well productivity at the later development stage of low-permeability carbonate gas reservoirs, but reservoirs are watered out and a great number of micro fractures are produced. Therefore, one of the key factors for underground gas storages (UGS) rebuilt from low-permeability fractured gas reservoirs with CO2 as the cushion gas is how to expand storage capacity effectively by injecting CO2 to displace water and to develop control strategies for the stable migration of gas–water interface. In this paper, a mathematical model was established to simulate the gas–water flow when CO2 was injected into dual porosity reservoirs to displace water. Then, the gas–water interface migration rules while CO2 was injected in the peripheral gas wells for water displacement were analyzed with one domestic UGS rebuilt from fractured gas reservoirs as the research object. And finally, discussion was made on how CO2 dissolution, bottom hole flowing pressure (BHFP), CO2 injection rate and micro fracture parameters affect the stability of gas–water interface in the process of storage capacity expansion. It is shown that the speed of capacity expansion reaches the maximum value at the fifth cycle and then decreases gradually when UGS capacity is expanded in the pattern of more injection and less withdrawal. Gas–water interface during UGS capacity expansion is made stable due to that the solubility of CO2 in water varies with the reservoir pressure. When the UGS capacity is expanded at constant BHFP and the flow rate, the expansion speed can be increased effectively by increasing the BHFP and the injection flow rate of gas wells in the central areas appropriately. In the reservoir areas with high permeability and fracture-matrix permeability ratio, the injection flow rate should be reduced properly to prevent gas–water interface fingering caused by a high-speed flow. Furthermore, it is necessary to monitor strictly the migration of gas–water interface by using observation wells to prevent gas escape through the edge water or water breakthrough at high-permeability zones. These research results provide a technical and theoretical support for water displacement and capacity expansion of UGS rebuilt from low-permeability fractured gas reservoirs with CO2 as the cushion gas. |
| first_indexed | 2024-03-07T17:43:00Z |
| format | Article |
| id | doaj.art-83ef301f1cd04fb4b6d0d24dc0b3a534 |
| institution | Directory Open Access Journal |
| issn | 2352-8540 |
| language | English |
| last_indexed | 2024-03-07T17:43:00Z |
| publishDate | 2016-11-01 |
| publisher | KeAi Communications Co., Ltd. |
| record_format | Article |
| series | Natural Gas Industry B |
| spelling | doaj.art-83ef301f1cd04fb4b6d0d24dc0b3a5342024-03-02T15:49:34ZengKeAi Communications Co., Ltd.Natural Gas Industry B2352-85402016-11-013545245910.1016/j.ngib.2017.02.006Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gasYufei TanChuankai NiuThe techniques of pressurized mining and hydraulic fracturing are often used to improve gas well productivity at the later development stage of low-permeability carbonate gas reservoirs, but reservoirs are watered out and a great number of micro fractures are produced. Therefore, one of the key factors for underground gas storages (UGS) rebuilt from low-permeability fractured gas reservoirs with CO2 as the cushion gas is how to expand storage capacity effectively by injecting CO2 to displace water and to develop control strategies for the stable migration of gas–water interface. In this paper, a mathematical model was established to simulate the gas–water flow when CO2 was injected into dual porosity reservoirs to displace water. Then, the gas–water interface migration rules while CO2 was injected in the peripheral gas wells for water displacement were analyzed with one domestic UGS rebuilt from fractured gas reservoirs as the research object. And finally, discussion was made on how CO2 dissolution, bottom hole flowing pressure (BHFP), CO2 injection rate and micro fracture parameters affect the stability of gas–water interface in the process of storage capacity expansion. It is shown that the speed of capacity expansion reaches the maximum value at the fifth cycle and then decreases gradually when UGS capacity is expanded in the pattern of more injection and less withdrawal. Gas–water interface during UGS capacity expansion is made stable due to that the solubility of CO2 in water varies with the reservoir pressure. When the UGS capacity is expanded at constant BHFP and the flow rate, the expansion speed can be increased effectively by increasing the BHFP and the injection flow rate of gas wells in the central areas appropriately. In the reservoir areas with high permeability and fracture-matrix permeability ratio, the injection flow rate should be reduced properly to prevent gas–water interface fingering caused by a high-speed flow. Furthermore, it is necessary to monitor strictly the migration of gas–water interface by using observation wells to prevent gas escape through the edge water or water breakthrough at high-permeability zones. These research results provide a technical and theoretical support for water displacement and capacity expansion of UGS rebuilt from low-permeability fractured gas reservoirs with CO2 as the cushion gas.http://www.sciencedirect.com/science/article/pii/S235285401730013XLow-permeability carbonate gas reservoirFractured reservoirUnderground gas storage (UGS)Dual porosity mediaCO2 cushion gasCapacity expansion analysisInterface control strategy |
| spellingShingle | Yufei Tan Chuankai Niu Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas Natural Gas Industry B Low-permeability carbonate gas reservoir Fractured reservoir Underground gas storage (UGS) Dual porosity media CO2 cushion gas Capacity expansion analysis Interface control strategy |
| title | Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas |
| title_full | Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas |
| title_fullStr | Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas |
| title_full_unstemmed | Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas |
| title_short | Capacity expansion analysis of UGSs rebuilt from low-permeability fractured gas reservoirs with CO2 as cushion gas |
| title_sort | capacity expansion analysis of ugss rebuilt from low permeability fractured gas reservoirs with co2 as cushion gas |
| topic | Low-permeability carbonate gas reservoir Fractured reservoir Underground gas storage (UGS) Dual porosity media CO2 cushion gas Capacity expansion analysis Interface control strategy |
| url | http://www.sciencedirect.com/science/article/pii/S235285401730013X |
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