Optimum Plunger Lift Operation

Abstract

Optimum Plunger Lift Operation J.O.A. Baruzzi; J.O.A. Baruzzi Petrobras Search for other works by this author on: This Site Google Scholar F.J.S. Alhanati F.J.S. Alhanati Petrobras Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Production Operations Symposium, Oklahoma City, Oklahoma, April 1995. Paper Number: SPE-29455-MS https://doi.org/10.2118/29455-MS Published: April 02 1995 Connected Content Related to: Plunger Lift Optimization Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Baruzzi, J.O.A., and F.J.S. Alhanati. "Optimum Plunger Lift Operation." Paper presented at the SPE Production Operations Symposium, Oklahoma City, Oklahoma, April 1995. doi: https://doi.org/10.2118/29455-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Oklahoma City Oil and Gas Symposium / Production and Operations Symposium Search Advanced Search SPE MembersAbstractOperational conditions for a plunger lift installation are analyzed based on qualitative observations on a reduced experimental facility and simulations with a simple hydrodynamic model.Despite many simplifications, model predictions for daily production and pressure behavior at the wellhead agreed well when compared with measurements in a real well.A method is described to predict when it is possible to have liquid accumulation only in the tubing during the buildup period. It is shown that there is a minimum GLR to reach this desirable condition.Sensitivity analysis for a typical well shows that for a given pressure there is an optimum afterflow time, and for a given afterflow time the smaller the pressure the greater the production.Practical recommendations are given on how to obtain optimum conditions for a typical installation.IntroductionAn oil well producing by conventional plunger lift (Fig. 1) operates cyclically. During the buildup period the flowline is kept closed. Liquid accumulates at the bottom of the well, and wellhead pressures continuously grow due to gas accumulation in tubing and annulus. After certain time, the flowline opens and a liquid slug is produced to the surface, driven by gas expansion below it. The main role of the plunger is to mitigate liquid fallback to the bottom of the well.Plunger lift is one of the best options for low productivity, high GLR wells. Advantages are zero input energy and efficient removal of paraffin and scale depositions. The main disadvantage is a greater requirement for continuous monitoring.Several electronic controllers for plunger lift wells are available on the market. Usually, their logic consists of adjusting the buildup time and the afterflow time based on the measurement of plunger rise velocity. However, this may not always be the best approach.Good estimates of possible well production rates are very important when considering lift alternatives for a certain well. Several prediction models have been suggested. None of them, however, has been able to accurately account for all the phenomena involved.P. 117 Keywords: casinghead pressure, plunger lift operation, buildup, plunger, production rate, artificial lift system, minimum glr, variation, spe 29455, afterflow time Subjects: Artificial Lift Systems, Plunger lift This content is only available via PDF. 1995. Society of Petroleum Engineers You can access this article if you purchase or spend a download.