Abstract
Gas condensate well has unique reservoir characteristics and ups and downs in well behaviour affect the production rate significantly. A proper optimization can reduce the operating cost, maximize the hydrocarbon recovery and increase the net present value. Well level optimization can be achieved through optimizing well parameters, such as wellhead, tubing size, and skin factor. All of these factors have been investigated using a real field of Thrace Basin and PROSPER simulation program. The history matching data are validated to identify the future performance prediction for the same reservoir deliverability following the period changes. Therefore, predicted results are compared and validated with measured field data to provide the best production practices. Moreover, the results show that the skin factor has a large influence on the production rate by 45% reduction. The reduction in the reservoir pressure declines the production rate dramatically resulted in 70% decline. While manipulating the wellhead pressure shows minor decline compare to tubing size that does not show any significant change to production rate.
Highlights
Inconsiderable fraction of the hydrocarbon can be produced by the natural drive of the reservoir
Well level optimization can be achieved through optimizing well parameters, such as wellhead, tubing size, and skin factor
While manipulating the wellhead pressure shows minor decline compare to tubing size that does not show any significant change to production rate
Summary
Inconsiderable fraction of the hydrocarbon can be produced by the natural drive of the reservoir. While Retrograde gas fields always exist beyond the critical temperature (as shown in figure 1) In this type of reservoir, the pressure is the main factor to yield any liquid and this would influence the production rate at surface. Dynamic Nodal Analysis The estimation of the relationship between the bottomhole pressure and the flowrate is very important as it assists to analyze and to predict the individual well performance This type of flow process is known as the inflow performance relationship (IPR). In 1954, Gilbert presented the same concept of inflow performance relationship (IPR) for the purpose of enhancing oil field production rate and flowing bottomhole pressures. By analysing the VLP/IPR relationships, running some sensitivity tests and calculate the gas mandrel depth via nodal analysis results in positive changes to the well, which produces 170 BOPD tend to improve the production up to 323 BOPD. An educational software known as PROSPER is used for this study to perform history matching and conduct appropriate sensitivity analysis
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