Page 94 - Petroleum Production Engineering, A Computer-Assisted Approach

Guo, Boyun / Computer Assited Petroleum Production Engg 0750682701_chap06 Final Proof page 86 3.1.2007 8:40pm Compositor Name: SJoearun

6/86 PETROLEUM PRODUCTION ENGINEERING FUNDAMENTALS

Reservoir pressure: 6,500 psia Horizontal sections
Tubing ID: 3.5 in Lateral no.: 1 2 3
1
Choke size: 64 ⁄ 64 in. Length of horizontal 1,000 1,100 1,200 ft
Productivity index above bubble 1.2 stb/d-psi section (L)
point: Horizontal permeability (k)8 5 4 md
Producing gas–liquid ratio: 800 scf/stb Net pay thickness (h) 40 50 30 ft
Water cut: 35 % Reservoir pressure (p-bar) 3,500 3,450 3,400 psia
Oil gravity: 40 8API Radius of drainage area (r eh ) 2,000 2,200 2,400 ft
Water-specific gravity: 1.05 1 for Gas viscosity (m g ) 0.02 0.02 0.02 cp
freshwater Wellbore diameter (D i ) 6.00 6.00 6.00 in.
Gas-specific gravity: 0.75 1 for air Bottom-hole 150 140 130 8F
Choke constant: 10 temperature (T)
Choke gas–liquid ratio exponent: 0.546 Gas compressibility 0.95 0.95 0.95
Choke-size exponent: 1.89 factor (z)
Formation volume factor for water: 1 rb/stb Gas specific gravity (g g ) 0.80 0.80 0.80 air ¼ 1
Wellhead temperature: 110 8F Curvic sections
Tubing shoe depth: 10,000 ft Lateral no.: 1 2 3
Bottom-hole temperature: 200 8F
Radius of curve (R) 333 400 500 ft
Average inclination angle (u) 45 45 45 degrees
Tubing diameter (d i ) 1.995 1.995 1.995 in.
Pipe roughness (e) 0.0018 0.0018 0.0018 in.
6.7 Use the following data to estimate the liquid produc-
tion rate of an oil well: Vertical sections
Lateral no.: 1 2 3
Interval length (H) 500 500 6,000 ft
1
Choke size: 48 ⁄ 64 in. Tubing diameter (d i ) 1.995 1.995 1.995 in.
Reservoir pressure: 3,200 psia Pipe roughness (e) 0.0018 0.0018 0.0018 in.
Total measured depth: 7,000 ft
Average inclination angle: 10 degrees
Tubing ID: 1.995 in. 6.10 For the following data, predict the gas production
Gas production rate: 600,000 scfd rate against 2,000 psia wellhead pressure and 80 8F
Gas-specific gravity: 0.7 air ¼ 1 wellhead temperature:
Oil-specific gravity: 0.85 H 2 O ¼ 1
Water cut: 20% Horizontal sections
Water-specific gravity: 1.05 H 2 O ¼ 1 Lateral no.: 1 2 3 4
3
Solid production rate: 0:5ft =d Reservoir pressure 3,500 3,300 3,100 2,900 psia
Solid-specific gravity: 2.65 H 2 O ¼ 1 (p-bar)
Tubing head temperature: 120 8F Oil formation 1.25 1.18 1.19 1.16 stb/rb
Bottom-hole temperature: 180 8F factor (B o )
Absolute open flow (AOF): 2,200 bbl/d Water formation 1.00 1.00 1.00 1.00 stb/rb
Choke flow constant: 10 factor (B w )
Choke gas–liquid ratio exponent: 0.546 Bottom-hole 170 160 150 130 8F
Choke size exponent: 1.89 temperature (T)
Gas compressibility 0.9 0.90 0.90 0.90
factor (z)
Gas-specific gravity 0.75 0.73 0.70 0.75 air ¼ 1
6.8 For the following data, predict the oil production rate: (g g )
Oil-specific gravity 0.85 0.88 0.87 0.8 6 water ¼ 1
(g o )
Water-specific 1.07 1.06 1.05 1.0 4 water ¼ 1
Depth: 7,500 ft
gravity (g w )
Tubing inner diameter: 3.5 in. Water–oil ratio 0.30 0.20 0.10 0.1 0 stb/stb
Oil gravity: 40 8API (WOR)
Oil viscosity: 0.8 cp Gas–oil ratio (GOR) 1,000 1,200 1,500 2,000 scf/stb
Production GLR: 700 scf/bbl Solution–gas–oil 600 1,000 1,200 1,800 scf/stb
Gas-specific gravity: 0.7 air ¼ 1 ratio (Rs)
1
Choke size: 48 ⁄ 64 in. Productivity 2 1.8 1.7 1.6 stb/d/psi
Flowing tubing head temperature: 90 8F index (J)
Flowing temperature at tubing shoe: 160 8F
Water cut: 20% Curvic sections
Reservoir pressure: 4,200 psia Lateral no.: 1 2 3 4
Bubble-point pressure: 4,000 psia Radius of curve (R) 400 400 400 400 ft
Productivity above bubble point: 4 stb/d-psi Average inclination 45 45 45 45 degrees
Choke flow constant: 10 angle (u)
Choke gas–liquid ratio exponent: 0.546 Tubing diameter (d i ) 2.441 2.441 2.441 2.441 in.
Choke-size exponent: 1.89 Pipe roughness (e) 0.0018 0.0018 0.0018 0.0018 in.
Vertical sections
Lateral no.: 1 2 3 4
Interval length (H) 100 100 100 5,000 ft
6.9 For the following data, predict the gas production
rate against 1,200 psia wellhead pressure and 90 8F Tubing diameter (d i ) 2.441 2.441 2.441 2.441 in.
wellhead temperature: Pipe roughness (e) 0.0018 0.0018 0.0018 0.0018 in.