Effect of outer boundary condition, reservoir size, and CO 2 effective permeability on pressure and CO 2 saturation predictions under carbon sequestration conditions

Liwei Zhang, Robert M. Dilmore and Grant S. Bromhal

Greenhouse Gases: Science and Technology, 2016, vol. 6, issue 4, 546-560

Abstract: A TOUGH2 simulation was conducted to investigate how the change of key model parameters affects pressure and CO 2 saturation response to CO 2 injection into a deep CO 2 storage reservoir. Given a domain of 100 × 100 km and a formation permeability of 10-super-−13 m-super-2, outer boundary condition does not have a significant impact on pressure increase and CO 2 saturation results. In a simulation period of 30 years of CO 2 injection + 100 years of post CO 2 injection, with a total CO 2 injection volume of 6.3×10-super-7 m-super-3 at T = 47°C and P = 10.5 MPa (equivalent mass of 30 million tonnes of CO 2 ), there is no pressure difference between the no flow boundary case and the open boundary case given a domain size of 100 x 100 km (a total storage formation pore volume of 10-super-11 m-super-3 at T = 47°C and P = 10.5 MPa), and the maximum CO 2 plume radius difference is 0.5%. However, given a domain size of 10 × 10 km, outer boundary condition significantly affects pressure simulation results. At t = 130 years, the pressure increase in the no flow boundary case is 56.5 times of the pressure increase in the open boundary case at the cell 50 m away from the injection well. For the 10 × 10 km case, the impact of outer boundary condition on CO 2 saturation results is relatively small. The change in formation permeability significantly affects pressure increase results, while the change in CO 2 relative permeability model only affects pressure increase results at cells close to the CO 2 injector. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd

Date: 2016
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