The Effect of Flow Parameters on Liquid Loading and Tubing Lift Performance in a Gas Condensate Well
|International Journal of Recent Engineering Science (IJRES)||
|© 2020 by IJRES Journal|
|Year of Publication : 2020|
|Authors : Godpower Abaku, Ifeanyi Samson Nwankwo , Bright Bariakpoa Kinate
|DOI : 10.14445/23497157/IJRES-V7I1P101|
MLA Style :Godpower Abaku, Ifeanyi Samson Nwankwo , Bright Bariakpoa Kinate "The Effect of Flow Parameters on Liquid Loading and Tubing Lift Performance in a Gas Condensate Well" International Journal of Recent Engineering Science 7.1(2020):1-8.
APA Style :Godpower Abaku, Ifeanyi Samson Nwankwo , Bright Bariakpoa Kinate. The Effect of Flow Parameters on Liquid Loading and Tubing Lift Performance in a Gas Condensate Well International Journal of Recent Engineering Science, 7(1),1-8.
Liquid loading of gas wells causes production difficulty and reduces ultimate recovery from these wells. Gas wells suffering from liquid loading are incapable of removing the liquid associated with produced gas from the wellbore. This phenomenon is initiated when the upward gas velocity in the well falls below a critical value, and the liquid accumulates at the bottom of the well. This accumulation of liquid decreases production rates and in severe cases kills the well. Several methods have been proposed to predict the onset of liquid loading in gas wells but understanding the influence of flow parameters is significant in solving this problem. In this work, flow parameters such as Tubing wellhead pressure, water-gas ratio(WGR), condensate-gas ratio(CGR), tubing size and the flow regimes are analyzed using PROSPER software to ascertain the effect of these parameters on liquid loading and how production from the gas well can be optimized through the proper selection and control of these flow parameters. Flow and PVT parameters were varied and inputted, and the result shows that an increase in the tubing wellhead pressure results in an increased tendency of liquid loading owning to the corresponding increase in the minimum unloading flowrate. Also, at a tubing wellhead pressure of 1200psig, the gas rate of the well was 90.652MMscf/day, and liquid loading will set in when production declines to 15.911MMscf/day (Turner`s rate). Whereas when the tubing wellhead pressure was increased to 1500psig, the production rate declines to 50.627MMscf/day and Turner`s limit set at 31.6721MMscf/day. Gases with high liquid contents (high GOR and WGR) also pose more significant tendencies of liquid load up. The sensitivity results of the tubing diameter (ranging from 2.5" to 7.5") show no remarkable effect on the tubing VLP. Hence, the tubing diameter has little or no effect on a gas well liquid load up. To ensure that liquid droplets are continuously and simultaneously transported to the surface, the mist flow regime should be desired and maintained at the wellbore
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Critical Rate, Flow Variables, Flow Regime, Load-up, Turner Limits