Technical Brief

Effective Method to Predict Installation of Plunger in a Gas Well

[+] Author and Article Information
Shu Luo

McDougall School of Petroleum Engineering,
The University of Tulsa,
800 South Tucker Drive,
Tulsa, OK 74104
e-mail: shu-luo@utulsa.edu

Mohan Kelkar

e-mail: mohan@utulsa.edu
McDougall School of Petroleum Engineering,
The University of Tulsa,
800 South Tucker Drive,
Tulsa, OK 74104

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received August 23, 2013; final manuscript received October 21, 2013; published online November 26, 2013. Assoc. Editor: Tayfun Babadagli.

J. Energy Resour. Technol 136(2), 024501 (Nov 26, 2013) (4 pages) Paper No: JERT-13-1250; doi: 10.1115/1.4025799 History: Received August 23, 2013; Revised October 21, 2013

Liquid loading is a common problem for most of the mature gas wells. Over years, many methods have been developed to solve this problem. One of the widely used methods is plunger lift, which requires shut-in of the gas well for a period of time. Then, the well is reopened, and it is expected that the natural energy of the well will push the plunger to the surface carrying the liquid with it. Optimization of the plunger lift requires that the well be shut-in for a period of time as short as possible, followed by production of gas for as long as possible. This note examines the requirement for a successful shut-in of a well so that the well can sustain the production for a longer time. The note also discusses the condition under which the well will not sustain the production and the plunger lift will not be effective. The analysis is confirmed with several field examples, which will be shown in this note.

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Grahic Jump Location
Fig. 1

Gas well before and during shut-in

Grahic Jump Location
Fig. 2

Field example case 1

Grahic Jump Location
Fig. 3

Field example case 2

Grahic Jump Location
Fig. 4

Field example case 3

Grahic Jump Location
Fig. 5

Field example case 4



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