A New Two Phase Pseudo Pressure Approach for the Interpretation of Gas Condensate Well Test in the Naturally Fracture Reservoir  (SPE94189)

Mazloom, Jalal; Kelly, R.T.; Mahani, Hassan

doi:10.3997/2214-4609-pdb.1.c037

Cited by 1 publication

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“…Gringarten et al (2000) showed that three regions exist with different liquid saturations when pressure falls below the dew point pressure. A novel approach was introduced in the use of twophase pseudo-pressure for the interpretation of gas condensate well test data in naturally fractured reservoirs (Mazloom et al, 2005). In addition, a method to characterize condensate bank was proposed by Bozorgzadeh et al (2006).…”

Section: A C C E P T E D Accepted Manuscriptmentioning

confidence: 99%

Integrated study of gas condensate reservoir characterization through pressure transient analysis

Zhao

Jia

et al. 2017

Journal of Natural Gas Science and Engineering

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This paper presents an alternative semi-analytical model which is able to integrate PVT properties of gas with dynamic pressure domain during production process. A modified three-region radial composite model is developed to evaluate the gas condensate reservoir, taking account of different gas flow behaviors and pressure dependent properties, such as the compressibility factor. The governing equation of the pressure diffusion process is highly nonlinear due to the complex dependence of coefficients on pressure. The linearization of the non-linear partial differential equation describing the complicated gas flowing in a reservoir is handled by application of reasonable definitions of pseudo-pressure and pseudo-time for each region, which is integrated into the reservoir system through physical continuity of changing phases with PVT properties. Modified forms of total compressibility factor are proposed by valid theoretical developments.Results show that gas compositions of a gas condensate reservoir have significant effects on the fluid flow behaviors. Different proportions of 5 C , 6 C and 7 + C are simulated with constant makeup of 2 CO , 2 N and 1 4 C , showing that small changes in composition of heavier components make distinct differences in the flow behaviors, as reflected on the liquids dropout curves. In addition, total compressibility factor varies with fluid compositions instead of remaining constant in a gas condensate reservoir.

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Section: A C C E P T E D Accepted Manuscriptmentioning

confidence: 99%