The Characteristics of Relative Permeability Curves in Naturally Fractured Carbonate Reservoirs
- Peiqing Lian (China University of Petroleum) | Linsong Cheng (China University of Petroleum)
- Document ID
- Society of Petroleum Engineers
- Journal of Canadian Petroleum Technology
- Publication Date
- March 2012
- Document Type
- Journal Paper
- 137 - 142
- 2012. Society of Petroleum Engineers
- 5.3.4 Reduction of Residual Oil Saturation, 3 Production and Well Operations, 5.8.7 Carbonate Reservoir, 5.4.1 Waterflooding, 5.2.1 Phase Behavior and PVT Measurements, 5.8.6 Naturally Fractured Reservoir, 6.5.2 Water use, produced water discharge and disposal, 5.7.2 Recovery Factors
- Relative permeability curve, Artificial fracture, Naturally fractured reservoir, Recovery factor, Confining pressure
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In naturally fractured reservoirs, fractures are the main flowing channels, while matrix is the dominant storage space. The oil/water relative permeability curve for the fracture in this kind of reservoir is very important to water-injection field development. In this study, we conducted experiments on the oil/water relative permeability of carbonate cores from Kenkiyak oil field and compared the differences in relative permeability curves between natural matrix cores and artificial-fracture cores. After the fracturing process, the two-phase flow area of tested cores becomes narrower, the permeability of the equal-permeability point gets higher, the relative permeability curve rises or drops more rapidly, and the displacement recovery efficiency decreases. The stress-sensitivity characteristics of the relative permeability curves were also studied on the basis of experiments on naturally fractured cores. With increasing effective confining pressure, the irreducible water saturation increases, the residual-oil saturation changes slightly, the equal-permeability point moves downward, and the displacement recovery efficiency declines. Numerical-simulation results indicate that for a given recovery factor, the water cut would increase more slowly but ultimate recovery factor would decrease using the relative permeability curve under higher confining pressure. Therefore, the water injection should be operated when the reservoir pressure is relatively higher to maintain formation pressure during waterflooding and lower the impact of stress sensitivity accordingly.
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