Use of Two-Phase Pseudo Pressure Method to Calculate Condensate Bank Size and Well Deliverability in Gas Condensate Reservoirs

This paper introduces a novel approach in the use of two-phase pseudo pressures for the calculation of condensate bank radius and productivity index of wells and the interpretation of gas condensate well test data. It is shown that knowledge of the relationship between condensate saturation and pressure is necessary for the integration of pseudo pressure in all regions of the reservoir. In the region of the reservoir where immobile condensate saturation develops, an equation that is valid for the region far from the wellbore has been used. While for the region where condensate is considered to be mobile, an equation has been used based on the steady state method. This method is tested using a data set that was generated by a compositional simulator for radial homogenous. A set of real PVT data from a producing gas condensate field is used for simulation of the gas condensate reservoir. Using this approach, it is possible to calculate condensate bank radius and total skin, mechanical skin, and permeability of the reservoir, yielding answers that are extremely close to those of the simulator. It is also shown that the condensate saturation profile in the reservoir produced using this method is also similar to the one produced by the simulator. An inflow performance curve is calculated using two-phase pseudo pressures. In this curve, the impact of the presence of condensate around the wellbore on productivity is studied.