Building Input File
Fluid, Fluid Flow & Rock Data

• Relative Permeability & Capillary Pressure
• K_rw/K_ro vs Sw data available on 5 core plugs
• K_ro / S_w & K_rw / S_w generated for Moore D1 - used in initial simulation
• to obtain production match - end points & curve shape modified
• capillary pressure test data available on 18 core plugs
• Swir obtained from relative permeability curves
• representative capillary pressure curve - shows asymptotic rise near Swir
• PVT data
  • solution GOR, oil API gravity & reservoir temperature - production data – insignificant gas production
    • assumptions
      • solution gas-oil-ratio = 50 cu. ft/bbl
      • gas gravity = 0.7 (air = 1)
    • average API tank gravity of the oil = 40 degrees
    • average reservoir temperature = 115^of.
  • bubble point pressure - bubble point pressure = 225 psia
    • Standing's Correlation in Petroleum Production Handbook
    • depth corresponding to bubble point pressure = 2100 ft
  • bubble point pressure gradient = 0

pbo	pbodat	pbgrad			<===bubble point pressure
225	2100	0
vslope	bslope	rslope	pmax	reprs	<== slope oil vis, Bo above bubble point pressure, max pressure, turn off for repressuring algorithm (valid for undersaturated oil)
.000495	-.000005	0	2000	1

• oil viscosity
  • dead oil viscosity @ 14.7psi & reservoir temperature = 2.5 cp
  • oil viscosity @ bubble point pressure = 1.95 cp
  • slope of oil viscosity above bubble point = .000495 cp/psi
  • estimation of oil viscosity in Properties of Petroleum Fluids
• oil formation volume factor (Bo)
  • @ Bubble Point = 1.037 RB/STB
  • Slope of Bo above bubble point = -.000005 RB/(STB.psi)
  • estimation of Bo in Properties of Petroleum Fluids
• water viscosity & formation volume factor - average total dissolved solids of 30,000 ppm
  • water viscosity = 0.65 cp @ atmospheric pressure
  • corrected @ different pressures above bubble point
  • estimation of water viscosity in Properties of Petroleum Fluids

p	muo	bo	rso	<== oil viscosity, saturated oil formation, saturated oil solution gas oil ratio at different pressures
14.7	2.5	1	1
225	1.95	1.037	50
500	1.98	1.036	50
1000	2.1	1.033	50
2000	2.8	1.028	50

p	muw	bw	rsw	<== water viscosity, water formation, water solution gas oil ratio at different pressures solubility of gas in water neglected in black oil simulation (rsw = 0)
14.7	.650	1.0120	0
225	.655	1.0120	0
500	.660	1.0120	0
1000	.665	1.0117	0
2000	.680	1.0100	0

• gas properties
  • gas viscosity = .0108 cp @ 14.7 psia & reservoir temperature
  • gas viscosity at pressures above atmospheric pressure
    • use pseudo reduced pressure & pseudo reduced temperature
    • read viscosity ratio from cross plot
    • calculate gas viscosity from ratio
  • estimate pseudocritical properties of gas
  • calculate pseudoreduced properties of gas
  • calculate Z-Factor
  • calculate Bg @ different pressures
• estimation of gas viscosity and Bg in Properties of Petroleum Fluids

0	(0) read gas & rock properties table, (1) activate gas correlation & read gas & rock properties table
p	mug	bg	psi	cr	pressure (p), gas viscosity (mug), gas frmn vol factor (bg), gas pseudo pressure (psi), rock compressibility (cr)
14.7	.0108	.196	0.0	.0000038
225	.011	.0123	0.0	.0000038
500	.0113	.0054	0.0	.0000038
1000	.0124	.0025	0.0	.0000038
2000	.0162	.0011	0.0	.0000038

• rock compressibility
  • average reservoir porosity = 17.5%
  • effective rock compressibility = 3.8*10^-6 psi^-1
    • read effective rock compressibility from cross plot
  • estimate rock compressibility in Petroleum Reservoir Engineering
• stock tank properties of oil, gas and water
  • convert API gravity to specific gravity - Density of oil = 51.46 lb/cu. ft
  • specific gravity of water with 30,000ppm = 1.035 - Density of water = 64.55 lb/cu. ft
  • specific gravity of gas = .7 - Density of air @ STP = .0764 lbs/cuft, Density of gas = 0.0535 lb/cu. ft
  • calculation of properties in Properties of Petroleum Fluids

rhosco	rhoscw	rhoscg	oil (rhosco), water (rhoscw), gas density (rhoscg)
51.46	64.55	.0535