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Numerical Simulation of two Phase Flow Around Gas- Condensate Wells With Compositional Model

Heidary, Hadi | 2009

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  1. Type of Document: M.Sc. Thesis
  2. Language: Farsi
  3. Document No: 39810 (08)
  4. University: Sharif University of Technology
  5. Department: Mechanical Engineering
  6. Advisor(s): Taghizadeh Manzari, Mehrdad; Seif, Mohammad Saeid; Kazemzade Hannani, Siamak
  7. Abstract:
  8. If the reservoir temperature lies between the critical temperature and cricondentherm of the reservoir fluid, the reservoir is classified as a retrograde gas-condensate reservoir. When the pressure is decreased on these mixtures, instead of expanding or vaporizing as might be expected, they vaporize instead of condensing. If the reservoir pressure is above the upper dew-point pressure, the hydrocarbon system exists as a single phase in the reservoir (region 3). As the reservoir pressure declines isothermally during production from the initial pressure to the upper dew-point pressure, the attraction between the molecules of the light and heavy components move further apart. As this occurs, attraction between the heavy component molecules becomes more effective; therefore, liquid begins to condense and region 2 makes up. In this region, only gas phase flows and liquid phase is immobile. With growth of condensate, as liquid saturation reaches to critical condensate saturation, liquid phase flows and either a gas or liquid phase are mobile (region 1). Characterization of gas condensate reservoirs is a difficult task, since multiphase flow in the reservoir and change of the mixture composition as fluid flows towards the well complicates the interpretation of well tests considerably. Many reservoirs of in South Pars gas field located in Iran are Gas-condensate reservoirs. Simulation studies were conducted using a finite volume, sequential method with compositional model. The Peng-Robinson equation of state is utilized to model fluid PVT behavior and fluid equilibria. In this study, we examine the flowing well response of a well producing a three zone gas condensate reservoir at either a constant molar rate or at a constant bottom hole pressure. Effect of some of parameters like skin factor, relative permeability, production rates, well pressure value, condensate saturation (Scc) have been studied on reservoir pressure, accumulation of condensates and composition change of hydrocarbon components. The flowing gas becomes leaner and leaner, dropping the intermediate and heavy components in the reservoir. Consequently, the oil in Regions 1 and 2 becomes heavier as the pressure decreases.

  9. Keywords:
  10. Gas Condensate Reservoirs ; Integrated Model ; Numerical Simulation ; Two Phase Flow

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