Research Article
Analysis of Gas Flow Behavior for Highly Deviated Wells in Naturally Fractured-Vuggy Carbonate Gas Reservoirs
Table 2
The values of relevant parameters for verification and sensitivity analysis.
| | Parameters | Value |
| | Wellbore radius, (m) | 0.0889 | | Formation radius, (m) | 400 | | Formation thickness, h (m) | 30 | | Fracture permeability, (m) | 1 | | Interporosity flow coefficient between fractures and vugs, | | | Interporosity flow coefficient between fractures and matrix, | | | Fractures porosity, | 0.002 | | Matrix porosity, | 0.04 | | Vugs porosity, | 0.017 | | Inclination angle, (°) | 75 | | Length of the highly deviated well, (m) | 300 | | Initial reservoir pressure, (MPa) | 24 | | Bottom-hole pressure, (MPa) | 20 | | Reservoir temperature, T (K) | 381.15 | | Gas production rate, (m3/d) | 600,000 | | Gas viscosity, (mPa·s) | 0.02 | | Gas compressibility factor, Z (m3/m3) | 0.97 |
|
|
