국내 대륙붕 고래V구조 대염수층에의CO₂ 저장 타당성 분석 연구
The feasibility study for CO₂ sequestration into deep saline aquifer at Gorae-V structure in Korea
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초록
This paper presents the numerical modelling study to investigate the feasibility of CO2 sequestion in deep saline aquifer at Gorae-V structure, Korea. This structure includes the Donghae-1 gas field which is the only one on producing in Korea and the CO2 injection simulation was conducted on B3/B4 layers which have relatively good values of both porosity and permeability in Gorae-V structure. The NE section of the formation is bounded by fault as a no-flow boundary, while SW boundary of the system is assigned as a constant pressure boundary representing the extension of the aquifer. A simulation for 30 years of injection and 2000 years of monitoring was conducted by using TOUGH2/ECO2N which can simulate the flow of the CO2-NaCl-water mixture to verify a major trapping mechanisms and injection/sequestration characteristics in this system. By a number of simulations in reservoir condition, the optimum injection rate was obtained within the limits of the rock fracturing pressure and a change of dominant trapping mechanism among structural, solubility and residual trapping mechanism with time was examined. Finally, if water pumping well is added beside the CO2 injection well, average pressure could be lowered and therefore injection rates can be increased in this system.
Abstract
This paper presents the numerical modelling study to investigate the feasibility of CO2 sequestion in deep saline aquifer at Gorae-V structure, Korea. This structure includes the Donghae-1 gas field which is the only one on producing in Korea and the CO2 injection simulation was conducted on B3/B4 layers which have relatively good values of both porosity and permeability in Gorae-V structure. The NE section of the formation is bounded by fault as a no-flow boundary, while SW boundary of the system is assigned as a constant pressure boundary representing the extension of the aquifer. A simulation for 30 years of injection and 2000 years of monitoring was conducted by using TOUGH2/ECO2N which can simulate the flow of the CO2-NaCl-water mixture to verify a major trapping mechanisms and injection/sequestration characteristics in this system. By a number of simulations in reservoir condition, the optimum injection rate was obtained within the limits of the rock fracturing pressure and a change of dominant trapping mechanism among structural, solubility and residual trapping mechanism with time was examined. Finally, if water pumping well is added beside the CO2 injection well, average pressure could be lowered and therefore injection rates can be increased in this system.
참고문헌 (12)
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