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Nomenclature
 
A = pattern area , acres
Bo = oil formation volume factor , volume @ reservoir conditions divided by volume @ standard conditions, dimensionless
Bw = water formation volume factor, volume @ reservoir conditions divided by volume @ standard conditions
C = constant
d = distance between adjacent rows of wells
Ea = model areal sweep efficiency, area swept divided by total pattern area , fraction
Ed = microscopic oil displacement efficiency , volume of oil displaced divided by total volume of oil , fraction
Ev = volumetric sweep efficiency , fraction of total reservoir volume contacted by the injected fluid
fo = fraction of total flowing stream composed of oil
fw = fraction of total flowing stream composed of water
hnet = formation thickness , ft
ibase = injection rate of fluid having the same mobility as reservoir oil
iw = water injection rate , BPD
k = absolute permeability , md
ko = effective permeability to oil , md
kro = relative permeability to oil , fraction
krw   relative permeability to water, fraction
kw = effective permeability to water , md
kwko = water - oil permeability ratio, dimensionless
Ln = natural logarithm , base
M = mobility ratio, mobility of the displacing fluid divided by the mobility of oil, dimensionless
Nwf = initial oil in place, bbl
Np = cumulative produced oil volume , bbl
DNp = incremental oil produced , bbl
p = pressure, psi
D p = pressure difference, between the formation face injection pressure and the pressure of the leading edge of the oil bank in the reservoir, psig
pb = bubble point or saturation pressure, psi
pe = pressure at external boundary, psi
pi = initial pressure, psi
piwf = injection well bottom hole pressure , psi
po = pressure in oil phase, atm
pw = pressure in water phase, atm or bottom hole pressure, psi
pc = capillary pressure, atm ( equal to po - pw )
q = production rate, BPD
qo = oil production rate, BOPD
qw = water production rate, BWPD
Qi = pore volumes of cumulative injected fluid
r = radial distance, ft, water bank, prior to interference
re = external boundary radius, ft, oil bank, prior to interference
rw = well radius , ft
Rs = solution GOR, scf/bbl
Sg = gas saturation , fraction of pore volume
Sg* = gas saturation, in pilot flooding, equal to C * (Soi-Sobt) from fig E.7
Sgi = initial gas saturation , fraction of pore volume
So = oil saturation, fraction of pore volume
Soi = initial oil saturation , fraction of pore volume
Sor = residual oil saturation, fraction of pore volume
Sw = water saturation, fraction of pore volume
Sw = average water saturation, fraction of pore volume
Swi = initial water saturation, fraction of pore volume
Swc = connate water saturation, fraction of pore volume
dfw/dsw = slope of the fractional flow curve
t = time , days
Vd = displaceable volume , equal to the cumulative injected fluid as a fraction of the product of the pattern pore volume and the displacement efficiency of the flood
Vp = pore volume , bbl
W = water volume, bbl
Wi = cumulative injected water volume, bbl
DWi = incremental injected water volume , bbl
DWp = incremental produced water volume , bbl
Wor = Water to oil ratio
g = conductance ratio, ratio of injectivity of water at any pattern areal sweep to that of reservoir oil
l = mobility, ( k / m )
lg = gas mobility , ( kg / mg)
lo = oil mobility , ( ko / mo)
lw = water mobility , ( kw / mw)
m = viscosity , cp
mg     = gas viscosity , cp
mo = oil viscosity , cp
mw    = water  viscosity , cp
f = porosity , fraction

Subscripts

a = atmospheric
bt = breakthrough
d = displacing phase
f = front or fillup
fo = floodout
g = gas
i = initial value, injection or interference
o = oil
p = produced
r = residual or relative
s = swept zone
sz = stabilized zone
t = total
u = unswept or uniform
w = water
2 = behind the flow front
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