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OTHER ARTIFICIAL LIFT METHODS 14/223
Centrilift-Hughes, Inc. Oilfield Centrilift-Hughes Submers- 8 cp. Gas-specific gravity is 0.75. The surface and
ible Pump Handbook. Claremore, Oaklahoma, 1998. bottom-hole temperatures are 70 and 160 8F, re-
cholet, h. Well Production Practical Handbook. Paris: spectively. The IPR of the well can be described by
Editions TECHNIP, 2000. Vogel’s model with a reservoir pressure 4,050 psia
foss, d.l. and gaul, r.b. Plunger lift performance criteria and AOF 12,000 stb/day. If the well is put in produc-
tion with an ESP to produce liquid at 7,000 stb/day
with operating experience: Ventura Avenue field. Dril- against a flowing well head pressure of 150 psia,
ling Production Practices API 1965:124–140. determine the required specifications for an ESP for
guo, b. and ghalambor, a. Natural Gas Engineering this application. Assume the minimum pump suction
Handbook. Houston, TX: Gulf Publishing Co., 2005. pressure is 220 psia.
guo, b. and ghalambor, a. Gas Volume Requirements for 14.2 A 9,000-ft-deep well has a potential to produce
Underbalanced Drilling Deviated Holes. PennWell 35 8API oil with GOR 120 scf/stb and 10% water
Books Tulsa, Oaklahoma, 2002. cut through a 2-in. (1.995-in. ID) tubing in a 7-in.
lea, j.f. Plunger lift vs velocity strings. Energy Sources casing with a pump installation. The oil has a forma-
tion volume factor of 1.25 and average viscosity of
Technology Conference & Exhibition (ETCE ’99), 1–2 5 cp. Gas- and water-specific gravities are 0.75 and
February 1999, Houston Sheraton Astrodome Hotel in 1.05, respectively. The surface and bottom-hole tem-
Houston, Texas. peratures are 70 and 170 8F, respectively. The
lea, j.f. Dynamic analysis of plunger lift operations. Pre- IPR of the well can be described by Vogel’s model
sented at the 56th Annual Fall Technical Conference with a reservoir pressure 2,000 psia and AOF
and Exhibition, 5–7 October 1981, San Antonio, 400 stb/day. If the well is to put in production with
Texas. Paper SPE 10253. a HPP at depth of 8,500 ft in an open power fluid
system to produce liquid at 210 stb/day against a
lebeaux, j.m. and sudduth, l.f. Theoretical and practical
flowing well head pressure of 65 psia, determine the
aspects of free piston operation. JPT September
required specifications for the HPP for this applica-
1955:33–35.
tion. Assume the overall efficiencies of the engine,
listiak, s.d. Plunger lift. In: Petroleum Engineering Hand-
HHP, and surface pump to be 0.90, 0.80, and 0.85,
book (Lake, L., ed.). Dallas: Society of Petroleum respectively.
Engineers, 2006. 14.3 Calculate required GLR, casing pressure, and plun-
mower, l.n., lea, j.f., beauregard, e., and ferguson, p.l. ger lift operating range for the following given well
Defining the characteristics and performance of gas-lift data:
plungers. Presented at the SPE Annual Technical Con- Gas rate: 250 Mcfd expected
ference and Exhibition held in 22–26 September 1985, when unloaded
Las Vegas, Nevada. SPE Paper 14344. Liquid rate: 12 bbl/day expected
rosina, l. A study of plunger lift dynamics [Masters when unloaded
Thesis], University of Tulsa, 1983. Liquid gradient: 0.40 psi/ft
turner, r.g., hubbard, m.g., and dukler, a.e. Analysis Tubing, ID: 1.995 in.
Tubing, OD: 2.375 in.
and prediction of minimum flow rate for the continu-
Casing, ID: 4.56 in.
ous removal of liquids from gas wells. J. Petroleum
Depth to plunger: 7,000 ft
Technol. November 1969.
Line pressure: 120 psi
Available casing pressure: 850 psi
Reservoir pressure: 1250 psi
Problems Average Z-factor: 0.99
Average temperature: 150 8F
14.1 A 9,000-ft-deep well produces 26 8API oil with GOR Plunger weight: 10 lb
50 scf/stb and zero water cut through a 3-in. (2.992- Plunger fall in gas: 750 fpm
in. ID) tubing in a 7-in. casing. The oil has a forma- Plunger fall in liquid: 150 fpm
tion volume factor of 1.20 and average viscosity of Plunger rise velocity: 1,000 fpm