1887

Abstract

Summary

In this work, we investigate the effect of alteration of fracture total permeability, relative permeability and capillary pressure with the change of normal net stress (due to fluid injection or depletion), on estimated oil recovery factor from fractured carbonate reservoir. The numerical experiments are performed in two steps: first, we predict two-phase fluid-flow properties of fracture for different levels of normal effective stress using our in-house geomechanical model; and second, we study the effect of normal net stress in the reservoir on oil recovery factor, using conceptual simulation models and a commercial simulator.

Our main conclusions of this study:

  • Oil recovery and water production in fractured carbonate reservoirs is controlled by, not only the fracture permeability (and other matrix related parameters), but also fracture rock curves.
  • Complex behavior of fluid flow in fractures cannot be captured only by varying fracture permeability. Shape of relative permeability and its dependence on the effective stress have a significant impact on flow of water vs. oil.

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/content/papers/10.3997/2214-4609.201702365
2017-10-04
2020-03-31
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References

  1. de la Porte, J. J., Kossack, C. A., & Zimmerman, R. W.
    (2005, January). The effect of fracture relative permeabilities and capillary pressures on the numerical simulation of naturally fractured reservoirs. In SPE annual technical conference and exhibition. Society of Petroleum Engineers.
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  3. Rozhko, A. Y., Wennberg, O.P., Jonoud, S.
    (2017, April). Modelling of normal net stress effect on two-phase relative permeability and capillary pressure of rough-walled fractures. In EAGE IOR– 19th European Symposium on Improved Oil Recovery, 24–27 April 2017, Stavanger, Norway
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