Page 93 - Petroleum Production Engineering, A Computer-Assisted Approach

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WELL DELIVERABILITY 6/85
References 6.3 For the data given in the following table, predict the
operating point using the bottom-hole as the solution
chen, w., zhu, d., and hill, a.d. A comprehensive model node:
of multilateral well deliverability. Presented at the SPE
International Oil and Gas Conference and Exhibition
held 7–10 November 2000 in Beijing, China. Paper
SPE 64751. Reservoir pressure: 3,500 psia
greene, w.r. Analyzing the performance of gas wells. Total measured depth: 8,000 ft
J. Petroleum Technol. 1983:31–39. Average inclination angle: 10 degrees
larsen, l. Productivity computations for multilateral, Tubing ID: 1.995 in.
branched and other generalized and extended well con- Gas production rate: 500,000 scfd
Gas-specific gravity:
0.7 air ¼ 1
cepts. Presented at the SPE Annual Technical Confer- Oil-specific gravity: 0.82 H 2 O ¼ 1
ence and Exhibition held 6–9 October 1996 in Denver, Water cut: 20%
Colorado. Paper SPE 36753. Water-specific gravity: 1.07 H 2 O ¼ 1
3
nind, t.e.w. Principles of Oil Well Production, 2nd edition. Solid production rate: 2ft =d
New York: McGraw-Hill, 1981. Solid-specific gravity: 2.65 H 2 O ¼ 1
pernadi, p., wibowo, w., and permadi, a.k. Inflow per- Tubing head temperature: 120 8F
formance of stacked multilateral well. Presented at the Bottom-hole temperature: 160 8F
SPE Asia Pacific Conference on Integrated Modeling Tubing head pressure: 400 psia
for Asset Management held 23–24 March 1996 in Absolute open flow (AOF): 2,200 bbl/d
Kuala Lumpur, Malaysia. Paper SPE 39750.
russell, d.g., goodrich, j.h., perry, g.e., and bruskot-
ter, j.f. Methods for predicting gas well performance. 6.4 For the data given in the following table, predict the
J. Petroleum Technol. January 1966:50–57. operating point using the bottom-hole as the solution
salas, j.r., clifford, p.j., and hill, a.d. Multilateral well node:
performance prediction. Presented at the SPE Western
Regional Meeting held 22–24 May 1996 in Anchorage,
Alaska. Paper SPE 35711.
Depth: 9,500 ft
Tubing inner diameter: 1.995 in.
Oil gravity: 40 8API
Problems Oil viscosity: 3 cp
Production gas–liquid ratio: 600 scf/bbl
6.1 Suppose that a vertical well produces 0.65 specific Gas-specific gravity: 0.75 air ¼ 1
7
gravity gas through a 2 ⁄ 8 -in. tubing set to the top of Flowing tubing head pressure: 500 psia
a gas reservoir at a depth of 8,000 ft. At tubing head,
Flowing tubing head temperature: 90 8F
the pressure is 600 psia and the temperature is 120 8F,
Flowing temperature at tubing shoe: 190 8F
and the bottom-hole temperature is 180 8F. The rela-
Water cut: 20%
tive roughness of tubing is about 0.0006. Calculate the
Reservoir pressure: 5,250 psia
expected gas production rate of the well using the
Bubble-point pressure: 4,200 psia
following data for IPR:
Productivity above bubble point: 1.2 stb/d-psi
Reservoir pressure: 1,800 psia
IPR model parameter C: 0:15 Mscf=d-psi 2n
IPR model parameter n: 0.82 6.5 Use the following data to estimate the gas production
rate of a gas well:
6.2 For the data given in the following table, predict the
operating point using the bottom-hole as a solution
node:
Reservoir pressure: 3,200 psia Gas-specific gravity: 0.75
Tubing ID: 1.66 in. Tubing inside diameter: 2.259 in.
Wellhead pressure: 600 psia Tubing wall relative roughness: 0.0006
Productivity index 1.5 stb/d-psi Measured depth at tubing shoe: 8,000 ft
above bubble point: Inclination angle: 0 degrees
Producing gas–liquid 800 scf/stb Wellhead choke size: 24 ⁄ 64 in.
1
ratio (GLR): Flowline diameter: 2 in.
Water cut (WC): 30% Gas-specific heat ratio: 1.3
Oil gravity: 408API Gas viscosity at wellhead: 0.01 cp
Water-specific gravity: 1.05 1 for Wellhead temperature: 140 8F
freshwater Bottom-hole temperature: 180 8F
Gas-specific gravity: 0.75 1 for air Reservoir pressure: 2,200 psia
N 2 content in gas: 0.05 mole fraction C-constant in backpressure IPR 0:01 Mscf d-psi 2n
CO 2 content in gas: 0.03 mole fraction model:
H 2 S content in gas: 0.02 mole fraction n-exponent in backpressure 0.84
Formation volume factor 1.25 rb/stb IPR model:
for water:
Wellhead temperature: 110 8F
Tubing shoe depth: 6,000 ft 6.6 Use the following data to estimate liquid production
Bottom-hole temperature: 140 8F rate of an oil well: