Study on the Influential Factors of CO 2 Storage in Low Permeability Reservoir

Ping Yue, Rujie Zhang, James J. Sheng, Gaoming Yu and Feng Liu
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Ping Yue: State Key Laboratory of Reservoir Geology and Development, Southwest Petroleum University, Chengdu 610500, China
Rujie Zhang: State Key Laboratory of Reservoir Geology and Development, Southwest Petroleum University, Chengdu 610500, China
James J. Sheng: Institute of Petroleum Engineering, Texas Tech University, Broadway, Lubbock, TX 79409, USA
Gaoming Yu: Research Institute of Exploration and Development, Changqing Oilfield Company, PetroChina, Xi’an 710018, China
Feng Liu: School of Petroleum Engineering, Xi’an Shiyou University, Xi’an 710065, China

Energies, 2022, vol. 15, issue 1, 1-10

Abstract: As the demands of tight-oil Enhanced Oil Recovery (EOR) and the controlling of anthropogenic carbon emission have become global challenges, Carbon Capture Utilization and Sequestration (CCUS) has been recognized as an effective solution to resolve both needs. However, the influential factors of carbon dioxide (CO 2 ) geological storage in low permeability reservoirs have not been fully studied. Based on core samples from the Huang-3 area of the Ordos Basin, the feasibility and influential factors of geological CO 2 sequestration in the Huang-3 area are analyzed through caprock breakthrough tests and a CO 2 storage factor experiment. The results indicate that capillary trapping is the key mechanism of the sealing effect by the caprock. With the increase of caprock permeability, the breakthrough pressure and pressure difference decreased rapidly. A good exponential relationship between caprock breakthrough pressure and permeability can be summarized. The minimum breakthrough pressure of CO 2 in the caprock of the Huang-3 area is 22 MPa, and the breakthrough pressure gradient is greater than 100 MPa/m. Huang-3 area is suitable for the geological sequestration of CO 2 , and the risk of CO 2 breakthrough in the caprock is small. At the same storage percentage, the recovery factor of crude oil in larger permeability core is higher, and the storage percentage decreases with the increase of recovery factor. It turned out that a low permeability reservoir is easier to store CO 2 , and the storage percentage of carbon dioxide in the miscible phase is greater than that in the immiscible phase. This study can provide empirical reference for caprock selection and safety evaluation of CO 2 geological storage in low permeability reservoirs within Ordos Basin.

Keywords: carbon dioxide; storage capacity; oil recovery factor; low permeability reservoirs (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2022
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