Page 79 - A Practical Companion to Reservoir Stimulation

DESIGN AND MODELING OF PROPPED FRACTURES

Reservoir Data Formation thickness, h 40 ft
Reservoir porosity, (J 0.077
Reservoir temperature, T 215" F
Initial reservoir pressure, p, 4000 psi
Oil API gravity 42
Gas specific gravity 0.662
Reservoir oil saturation 0.55
Drainage area 160 acres
Plumbing and Well: pumping
Well Producing Data Producing gas-oil ratio 600 SCFISTB
Flowing bottomhole"pressure, pwr 500 psi
Tubing inside diameter 2.441 in.
Tubing outside diameter 2.875 in.
Tubing length (measured depth) 7383 ft
Fracture Mechanics Data Fracture geometry model PKN
Minimum horizontal stress 5571 psi
Young's modulus, E 4.5 x lo6 psi
Poisson's ratio, v 0.2
Leakoff height, h, 38 ft
Fracture gross height, h, 140 ft
Leakoff coefficient, CL 3 x 10-3 ftifi
Spurt loss coefficient, S, 1 gall1 00 ft2
Proppant Data Proppant type 20140 sand
Proppant specific gravity 2.65
Proppant diameter 0.0248 in.
Retained permeability factor 0.3
Fracturing Fluid Data Fluid Crosslinked borate
K' 4.5 x 1 0-2 Ibf sec"lft2
n' 0.6
Viscosity at 170-' sec 276 cp

Operational Constraints Maximum net pressure 1500 psi
Maximum pump rate 20 BPM
Maximum slurry concentration 8 PPP
Economic Data Proppant cost $0.0911 b
Fluid cost $0.43/gal
Horsepower cost $4lhp-hr
Miscellaneous costs $20,000
Discount rate 1 2%
Oil unit revenue $20/STB

Table Ed-Data for fracture design parametric studies in Examples E-12 to E-16.

E- 19