This paper describes the modeling procedure for a vertical well to determine the deliverability of the production system. The deliverability or performance of a gas production system is represented by the production rate, which depends on the reservoir’s deliverability to produce fluids at the sand face and the well’s vertical lift performance (VLP). While the reservoir’s deliverability (fluid flow through porous media) can be modeled with accuracy by a reservoir simulator, the VLP of a well can be predicted using a well model. A well model is an essential component of any production system analysis. This model requires a relationship that describes the inflow of fluid to the wellbore and the VLP curve to determine well deliverability.
For the analysis of Well -1 was a gas condensate reservoir located in the eastern part of Bangladesh, was selected as the case study. This well has been producing since 1983 and is a gas condensate producer with a condensate gas ratio (CGR) of 8 to 11 STB/MMscf and water gas ratio (WGR) of 0.1 to 0.4 STB/MMscf. It has the production rate of 20 MMscfd gas and producing well head pressure is 2680 psig with 4.5-inch tubing.
The production rate calculated by the model for a given wellhead and reservoir pressure is within 2.5% of the real field data. This study shows the optimum operating flow rate is 22 MMscfd, optimum separator condition is 700 psig, and optimum separator temperature 70o F with well head pressure is 2766 psig. This model can be used for predicting future well performance.
Contributors: Ahmed, T.; Akter, F.; Huque, M.M
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