Page 133 - Enhanced Oil Recovery in Shale and Tight Reservoirs

Optimization of huff-n-puff gas injection in shale and tight oil reservoirs 119

Figure 5.1 Schematic of the base model.

Table 5.1 Matrix and fracture properties.
Non-SRV SRV

Thickness, ft 50 50
Matrix permeability, mD 3.0E-04 3.0E-04
Matrix porosity, fraction 0.056 0.056
Fracture porosity, fraction 0.0022 0.0056
Fracture permeability, mD 2.16E-03 3.13E-02
Fracture spacing, ft 2.27 0.77
Hydraulic fracture porosity, fraction 0.9
Hydraulic fracture permeability, mD 100

The dual permeability model was used to simulate the matrix, natural frac-
tures and hydraulically stimulated reservoir volume. The shale matrix
permeability is 0.0003 mD. The natural fracture effective permeability is
0.0313 mD in the SRV and 0.00216 mD in the unstimulated reservoir
region.
The reservoir fluid composition and the Peng-Robinson EOS parame-
ters are from Yu et al. (2014b) as represented in Table 5.2. The binary