TY - GEN
T1 - A New Coupled Approach to Simulating Fault Reactivation During CO2 Sequestration
AU - Saber, Erfan
AU - Qu, Qingdong
AU - Aminossadati, Saiied M.
AU - Li, Jimmy
AU - Chen, Zhongwei
N1 - Publisher Copyright:
© 2023, Society of Petroleum Engineers.
PY - 2023
Y1 - 2023
N2 - Carbon Capture and Storage (CCS) is considered an important means to reducing CO2 emissions. One of the key technical risks associated with large scale CCS implementation is the potentially induced fault reactivation. To assess this risk, a coupled numerical approach was established by integrating three different software packages over four steps. Firstly, a field-scale structural geological modelling was conducted using the JewelSuite based on available geological, geophysical, and logging data. Secondly, dynamic CO2 injection was simulated using the reservoir simulator IMEX to predict reservoir pressure build-up. Thirdly, the pressure build-up and the associated reservoir uplift were simulated in the Finite Element software Abaqus. Finally, the Finite Element output database was re-imported into the JewelSuite to delineate the risk areas of fault reactivation. The feasibility of this new approach was tested on a real geological site featuring two faults. The results suggest that, for a given fault setting, the horizontal well placement and bottom hole injection pressure (BHIP) are two critical factors in determining the risk of fault reactivation. To minimise the risk, horizontal wells should not be placed within the intermediate region between faults. Where the borehole placement cannot be optimised, the critical BHIP should be estimated and controlled during operation.
AB - Carbon Capture and Storage (CCS) is considered an important means to reducing CO2 emissions. One of the key technical risks associated with large scale CCS implementation is the potentially induced fault reactivation. To assess this risk, a coupled numerical approach was established by integrating three different software packages over four steps. Firstly, a field-scale structural geological modelling was conducted using the JewelSuite based on available geological, geophysical, and logging data. Secondly, dynamic CO2 injection was simulated using the reservoir simulator IMEX to predict reservoir pressure build-up. Thirdly, the pressure build-up and the associated reservoir uplift were simulated in the Finite Element software Abaqus. Finally, the Finite Element output database was re-imported into the JewelSuite to delineate the risk areas of fault reactivation. The feasibility of this new approach was tested on a real geological site featuring two faults. The results suggest that, for a given fault setting, the horizontal well placement and bottom hole injection pressure (BHIP) are two critical factors in determining the risk of fault reactivation. To minimise the risk, horizontal wells should not be placed within the intermediate region between faults. Where the borehole placement cannot be optimised, the critical BHIP should be estimated and controlled during operation.
KW - 3D geo-mechanical simulation
KW - Bottom hole injection pressure
KW - CO injection
KW - Fault reactivation
KW - well azimuth
UR - http://www.scopus.com/inward/record.url?scp=85179886511&partnerID=8YFLogxK
U2 - 10.2118/217287-MS
DO - 10.2118/217287-MS
M3 - 会议稿件
AN - SCOPUS:85179886511
T3 - Society of Petroleum Engineers - Asia Pacific Unconventional Resources Symposium, APUR 2023
BT - Society of Petroleum Engineers - Asia Pacific Unconventional Resources Symposium, APUR 2023
PB - Society of Petroleum Engineers
T2 - 2023 Asia Pacific Unconventional Resources Symposium, APUR 2023
Y2 - 14 November 2023 through 15 November 2023
ER -