Page 395 - Enhanced Oil Recovery in Shale and Tight Reservoirs

366 Enhanced Oil Recovery in Shale and Tight Reservoirs

Table 12.1 Parameter input for matrix, NF, and HF for history match.

Reservoir depth, ft 8000 NF half-length, ft 16
Reservoir thickness, ft 50 HF conductivity, mD-ft 250
Matrix porosity 0.056 HF porosity 0.6
Matrix permeability, nD 300 HF half-length, ft 215
NF conductivity, mD-ft 6.5 Initial reservoir pressure, psi 7800
NF porosity 0.8 Matrix S wi 0.4

Kazemi, 2012). Table 12.1 lists the parameters used in the base model.
An exponential stress-dependent-permeability (SDP) model (Raghavan
and Chin, 2002) is used:

k ¼ k 0 e bðs eff s effo Þ (12.5)
where k is the permeability (mD), k 0 is the permeability at the initial con-
dition (mD), s eff is the effective stress (psi), s effo is the effective stress at the
initial condition (psi), and b is the stress sensitivity index. Fig. 12.24 shows
how the permeabilities of the matrix, natural fractures (NF), and hydraulic
fracture (HF) change with the pore pressure during the injection and the
production stages. The natural fracture spacing is 2 ft.

Figure 12.24 Changes of the permeabilities of the matrix, NF, and (HF) with the pore
pressure during the injection and production stages.