Comparison of relative permeability–saturation–capillary pressure models for simulation of reservoir CO2 injection

Abstract

the S k r  relations are obtained by fitting to experimental data using either an 10 endpoint power law or a modified Corey approach. The six models were tested 11 using data from four well-characterized sandstones (Berea, Paaratte, Tuscaloosa, 12Mt. Simon) for two radial injection test cases. The results show a large variation 13 in plume extent and saturation distribution for each of the sandstones, 14 depending on the used model. The VG-Mualem model predicts plumes that are 15 considerably larger than for the other models due to the overestimation of the 16 gas relative permeability. On the other hand, the predicted plume sizes are the 17 smallest for the VG-Corey model due to the underestimation of the aqueous 18 phase relative permeability. Of the four models that do not use fits to 19 experimental relative permeability data, the hybrid model with Mualem aqueous 20 phase and Corey gas phase relative permeabilities provide the best fits to the 21 experimental data and produce results close to the model with fits to the 22 capillary pressure and relative permeability data. The model with the endpoint 23 power law resulted in very low, uniform gas saturations outside the dry-out 24 zone for the Tuscaloosa sandstone, as the result of a rapidly declining aqueous 25 3 phase relative permeability. This observed behavior illustrates the need to obtain 1 reliable relative permeability relations for a potential reservoir, beyond 2 permeability and porosity data. 3 4

Development of quantitative metrics of plume migration at geologic CO2 storage sites

“…We used linear relative permeability and capillary pressure models in these simulations. It has long been recognized that relative permeability and capillary pressure models influence plume migration . While the metrics presented here can help investigate this issue, this is beyond the scope of the current paper.…”

“…It has long been recognized that relative permeability and capillary pressure models influence plume migration. [23][24][25] While the metrics presented here can help investigate this issue, this is beyond the scope of the current paper. The mesh is composed of 201 by 201 cells in the horizontal direction and 11 cells in the vertical direction (444,411 50 × 50 × 10 m cells).…”

Characterization and design of the FutureGen 2.0 carbon storage site

“…The simulations have been used for estimating CO2 injectivity, CO2 plume extent, pressure distribution, thermal impact of the injection, and for the design of CO2 injection operations. They are detailed in several papers by Nguyen et al (submitted), Oostrom et al (2016), White et al (submitted), and Zhang et al (2015Zhang et al ( , 2016.…”

Response surface modeling of CO2dynamic storage efficiency factor in high permeability thick sandstones

“…Some unique aspects of mechanisms involved in the underground displacement of injected CO 2 for high permeability zones have been addressed in the literature. Oostrom et al . qualitatively studied the influence of relative permeability on CO 2 plume distribution and observed that for high permeability zones, the influence of relative permeability on plume shape is not as significant as is in lower permeability zones.…”

“…Some unique aspects of mechanisms involved in the underground displacement of injected CO 2 for high permeability zones have been addressed in the literature. Oostrom et al 3 qualitatively studied the influence of relative permeability on CO 2 plume distribution and observed that for high permeability zones, the influence of relative permeability on plume shape is not as significant as is in lower permeability zones. Mathias et al 4 also studied the effect of uncertainty in relative permeability data on CO 2 injectivity in brine formations and showed that uncertainty in the relative permeability data should be captured in simulations to have a reasonable representation of the system under consideration.…”