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Influence of Reservoir Properties on the Velocity of Water Movement from Injection to Production Well

Author

Listed:
  • Vladimir Valerievych Poplygin

    (Mining and Oil Faculty, Perm National Research Polytechnic University, 614990 Perm, Russia)

  • Irina Sergeevna Poplygina

    (Directorate of Field Development Design and Monitoring, Branch of LLC LUKOIL-Engineering PermNIPIneft, 614066 Perm, Russia)

  • Viktor Antonovich Mordvinov

    (Mining and Oil Faculty, Perm National Research Polytechnic University, 614990 Perm, Russia)

Abstract

To maintain reservoir pressure, water is injected into oil reservoirs. In carbonate rock, water quickly breaks through fractures and highly permeable formations to production wells. This study analyzes the effect of the permeability, oil viscosity, pressure drop, and distance on the water velocity from an injection well to a production well. In the Tempest MORE hydrodynamic simulator (Roxar), a three-layer model of an oil reservoir was created, and water flow from an injection well to a production well was simulated with various values of the permeability, oil viscosity, and bottom hole pressure. The water velocity in the reservoir was estimated based on the mobility factor (k/µo). The results showed that at a mobility factor of less than 2 μm 2 /Pa s at a distance of 100 m in the reservoirs, the time of water migration from the injection well to the production well increased sharply, and at a mobility factor of more than 2 μm 2 /Pa s, it became shorter. An analysis of the time of water migration in fields with high-viscosity oil was conducted. The watering time turned out to be shorter than that predicted by the simulation. The permeability of the reservoir and the viscosity of the oil had the greatest influence on the water velocity. To a lesser extent, the time of water migration was affected by the distance between the wells and the difference in the bottomhole pressures. The average migration time for water with a mobility factor of more than 2 µm 2 /(Pa s) was 6.3 years. Based on the regression analysis of the field data, a linear equation for the time of water migration was obtained. The resulting equation makes it possible to predict the water cuts of wells and optimize oil production.

Suggested Citation

  • Vladimir Valerievych Poplygin & Irina Sergeevna Poplygina & Viktor Antonovich Mordvinov, 2022. "Influence of Reservoir Properties on the Velocity of Water Movement from Injection to Production Well," Energies, MDPI, vol. 15(20), pages 1-14, October.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:20:p:7797-:d:949449
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    References listed on IDEAS

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    1. Aleksei O. Malahov & Emil R. Saifullin & Mikhail A. Varfolomeev & Sergey A. Nazarychev & Aidar Z. Mustafin & Chengdong Yuan & Igor P. Novikov & Dmitrii A. Zharkov & Rustam N. Sagirov & Rail I. Kadyrov, 2022. "Screening of Surfactants for Flooding at High-Mineralization Conditions: Two Production Zones of Carbonate Reservoir," Energies, MDPI, vol. 15(2), pages 1-15, January.
    2. Congcong Li & Shuoliang Wang & Qing You & Chunlei Yu, 2021. "A New Measurement of Anisotropic Relative Permeability and Its Application in Numerical Simulation," Energies, MDPI, vol. 14(16), pages 1-18, August.
    3. Evgenii Vasilevich Kozhevnikov & Mikhail Sergeevich Turbakov & Evgenii Pavlovich Riabokon & Vladimir Valerevich Poplygin, 2021. "Effect of Effective Pressure on the Permeability of Rocks Based on Well Testing Results," Energies, MDPI, vol. 14(8), pages 1-20, April.
    4. Tao Ning & Meng Xi & Bingtao Hu & Le Wang & Chuanqing Huang & Junwei Su, 2021. "Effect of Viscosity Action and Capillarity on Pore-Scale Oil–Water Flowing Behaviors in a Low-Permeability Sandstone Waterflood," Energies, MDPI, vol. 14(24), pages 1-30, December.
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