Effect of Matrix-Wellbore Flow and Porosity on Pressure Transient Response in Shale Formation Modeling by Dual Porosity and Dual Permeability System

Table 1

Data used in validation.

Name	Value	Unit
Reservoir size	810 × 810	m
Boundary condition	Closed
Initial pressure	20	MPa
Reservoir thickness	30	m
Rock compressibility	0.0000145	1/MPa
Temperature	122	°F
Gas gravity	0.7
Half of hydraulic fracture	75	m
Natural fracture space	10	m
Fracture
Permeability	700	mD
Porosity	0.05
Matrix
Permeability	0.1	mD
Porosity	0.25
Horizontal well
Skin factor	0
Well storage	0	m^3/MPa
Constant rate (STC)	12000	m^3/day
Production time	200	Day
Deviation factor	Dranchuk-Abou-Kassem equation
Gas viscosity	Lee equation