Numerical Simulations of Carbon Dioxide Storage Efficiency in Heterogeneous Reservoir Models
Table 2
Model parameters and injection scenarios.
Mesh size and model dimensions
Length
5,000 m
Thickness
55 and 75 m
Mesh size
and
Number of elements
1,470 and 2,170
Rock properties
Porosity
Heterogeneous
Permeability
Heterogeneous
Number of geostatistical realizations
9
Relative permeability
CO2BRA database
Capillary pressure
Lithology-sensitive
Initial conditions
Initial pressure
GASIS database
Pressure gradient
10.14 kPa/m
Initial temperature
GASIS database
Temperature gradient
0.02°C/m
Brine concentration
8 wt.%
Pore compressibility
4.5-10 Pa-1
Injection scenarios
Injection rate
400 and 800 tons/day
Injection period
30 years
Perforation
Reservoir thickness
For sandstone reservoir models, the Brooks-Corey capillary pressure function was used using the parameters from Refs. [49, 50], and for limestone and dolomite reservoir models, the van Genuchten capillary pressure function was utilized using the parameters from Ref. [51]. Leverett scaling of capillary pressure was invoked since heterogeneous porosity and permeability fields were used.
