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Guo, Boyun / Computer Assited Petroleum Production Engg 0750682701_chap13 Final Proof page 205 3.1.2007 9:07pm Compositor Name: SJoearun

GAS LIFT 13/205

Flow selection of installation methods. Optimization of existing
gas lift systems is left to Chapter 18.
References
Gas
brown, k.e. The Technology of Artificial Lift Methods,
Unloading Gas lift Vol. 1. Tulsa, OK: PennWell Books, 1977.
Valve brown, k.e. The Technology of Artificial Lift Methods,
Bottom unloading Vol. 2a. Tulsa, OK: Petroleum Publishing Co., 1980.
Gas lift Valve economides, m.j., hill, a.d., and ehig-economides, c.
Petroleum Production Systems. New Jersey: Prentice
Hanger Nipple for Dip Hall PTR, 1994.
tube gilbert, w.e. Flowing and gas-lift well performance. API
Operating Chamber Drill. Prod. Practice 1954.
Gas lift Valve guo, b. and ghalambor, a. Natural Gas Engineering
Handbook. Houston, TX: Gulf Publishing Co., 2005.
Packer katz, d.l., cornell, d., kobayashi, r., poettmann, f.h.,
vary, j.a., elenbaas, j.r., and weinaug, c.f. Handbook
Bleed Port or of Natural Gas Engineering. New York: McGraw-Hill
Valve Publishing Company, 1959.
weymouth, t.r. Problems in Natural Gas Engineering.
Standing Valve
Trans. ASME 1912;34:185.
Problems
Figure 13.24 A sketch of an insert chamber.
Figure 13.24 illustrates an insert chamber. It is normally 13.1 An oil well has a pay zone around the mid-perf depth
used in a long open hole or perforated interval where of 5,200 ft. The formation oil has a gravity of
squeezing of fluids back to formation by gas pressure is a 30 8API and GLR of 500 scf/stb. Water cut remains
concern. It takes the advantage of existing bottom-hole 10%. The IPR of the well is expressed as
pressure. The disadvantage of the installation is that the
p
chamber size is limited by casing diameter. q ¼ Jb p p wf c,
Shown in Fig. 13.25 is a reverse flow chamber. It ensures where
venting of all formation gas into the tubing string to empty J ¼ 0:5 stb=day=psi
the chamber for liquid accumulation. For wells with high- p p ¼ 2,000 psia.
formation GLR, this option appears to be an excellent
choice. A 2-in. tubing (1.995-in. ID) can be set with a
packerat200 ftabovethemid-perf.Whatisthemaximum
expectedoilproductionratefromthewellwithcontinuous
Summary
gas lift at a wellhead pressure of 200 psia if
This chapter presents the principles of gas lift systems and
illustrates a procedure for designing gas lift operations. a. unlimited amount of lift gas is available for the
Major tasks include calculations of well deliverability, well?
pressure and horsepower requirements for gas lift gas b. only 1.2 MMscf/day of lift gas is available for the
compression, gas lift valve selection and spacing, and well?
13.2 An oil well has a pay zone around the mid-perf depth
of 6,200 ft. The formation oil has a gravity of
30 8API and GLR of 500 scf/stb. Water cut remains
10%. The IPR of the well is expressed as
Unloading " 2 #
Valves p wf p wf
q ¼ q max 1 0:2 0:80:2 ,
p p p p
Gas
Operating where
q max ¼ 2,000 stb=day
Valve
p p ¼ 2,500 psia.
Stinger tube 1
A2 ⁄ 2 -in.tubing(2.259-in.ID)canbesetwithapacker
at 200 ft above the mid-perf. What is the maximum
Top Packer
expected oil production rate from the well with con-
Gas Perforated Nipple tinuous gas lift at a wellhead pressure of 150 psia if
Stinger Receiver
Liquids Perforated Nipple a. unlimited amount of lift gas is available for the
well?
b. only 1.0 MMscf/day of lift gas is available for the
Standing Valve
well?
Packer
13.3 An oil field has 24 oil wells defined in Problem 13.1.
The gas lift gas at the central compressor station is
first pumped to three injection manifolds with 6-in.
ID, 2-mile lines and then distributed to the well heads
Figure 13.25 A sketch of a reserve flow chamber. with 4 in. ID, 0.5-mile lines. Given the following