Abstract
The authors consider the concept of liquid blockage in a gas wellbore and how it can be prevented by adequately predicting the fluid mixtures' (gas, oil, water and condensates) behavior as it travels along the wellbore to the surface using the IPM packages MBAL, PROSPER, and GAP to model the flowrate and tubing size performance. The central objective of the modeling work was to determine the best tubing size needed for optimum delivery of the gas well in focus. The results from the analysis show 0.1397 m (5.500″) tubing as the best size for flowing the gas well.
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