John R. Fanchi - Principles of Applied Reservoir Simulation, Second Edition
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262
Principles
of
Applied
Reservoir Simulation
Option
Constant rock compressibility
NOTE:
Enter
1
record.
Pressure-dependent rock com-
pressibility
NOTE:
Enter MPGT
records.
Code
PMAX
CR
P
CR
Meaning
Maximum
table pressure (psia)
from
record
4.
Rock compressibility
(1/psia)
Pressure (psia). Pressures must
be in
ascending order
from
PI
(normally 14.7
psia)
to
PMAX.
The
last table entry
must
be
PMAX.
Rock
compressibility
(1/psia)
18.
Heading
Up to 80
characters.
19.
RHOSCO,
RHOSCW,
RHOSCG
RHOSCO Stock tank
oil
density
(Ib/cu
ft).
RHOSCW Stock tank water density (Ib/cu ft).
RHOSCG
Gas
density
at
standard conditions (Ib/cu ft).
NOTE:
At
standard conditions (14.7 psia
and 60
degrees
F for
oilfield
units) pure water
has a
density
of
62.4
Ib/cu
ft
and
air has a
density
of
0.0765
Ib/cu
ft.
Repeat records
1
through
19 a
total
of
NPVT times.
24.7 Pressure
and
Saturation Initialization
1,
Heading
Up to 80
characters.
2,
KPI,
KSI,
PDATUM, GRAD
KPI
Pressure
initialization code.
KSI
Saturation initialization code.
PDATUM Depth
to
pressure
datum (ft).
GRAD
Estimated pressure gradient
(psia/ft)
for
pressure corrections
to
PDATUM.
If
GRAD
= 0, a map of
pressures
corrected
to
PDATUM will
not be
printed.
If
GRAD
*
0, a map of
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263
pressures corrected
to
PDATUM will
be
printed using
pressure gradient
GRAD,
Code
KPI
KSI
Value
0
1
0
1
Meaning
Read
II x JJ
*
KK
pressures (one
for
each block).
Equilibrium pressure initialization. Requires pressures
and
depths
at the OWC and
GOC.
Read
II x JJ x KK oil
saturations (one
for
each block)
and
II
x
JJ
x
KK
water
saturations.
Gas
saturations
will
be
calculated
by the
program.
Gravity
segregated oil, water
and gas
saturation initializa-
tion.
NOTE:
Options
KPI and KSI may be
used
to
prepare
a
restart
data
file.
3.
PO
Omit
this record
if
KPI
= 1.
PO
Oil-phase
pressure
(psia).
Read
II x JJ x KK
values.
4.
PWOC, WOC, PGOC,
GOC
Omit
this record
if
KPI
= 0.
PWOC Pressure
at the
water-oil contact (psia).
WOC
Depth
to the
water-oil contact
(ft
below datum).
PGOC
Pressure
at the
gas-oil contact (psia).
GOC
Depth
to the
gas-oil contact
(ft
below datum).
NOTE: Repeat this record
a
total
of
NROCK times
-
one
record
for
each Rock region.
5.
SO
Omit
this record
if
KSI
=
1.
SO Oil
saturation array (fraction). Read
II x JJ x KK
values,
6.
SW
Omit
this record
if
KSI
= /.
SW
Water saturation array (fraction). Read
II x JJ x KK
values.
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264
Principles
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Applied
Reservoir Simulation
7.
SOI, SGI,
SOR
Omit
this record
ifKSI
= 0.
SOI
Initial
oil
saturation
for the
oil-water zone
to be
assigned
to
all
blocks
in the
rock region (fraction). Initial water
satura-
tion
in the
oil-water zone
is
I
-
SOI.
SGI
Initial
gas
saturation
for the
gas-water zone
to be
assigned
to all
blocks
in the
rock region (fraction). Initial water
saturation
in the
gas-water zone
is 1 -
SGI.
SOR
Irreducible
oil
saturation
to be
assigned
to all
blocks
in the
rock
region (fraction).
If SOR > 0,
calculated
So
will
be set
to
0
when
So <
SOR. Water
and gas
saturations
are
then
renormalized.
NOTE:
Repeat this record
a
total
of
NROCK
times
-
one
record
for
each Rock region.
24.8
Run
Control Parameters
I,
Heading
Up to 80
characters.
2
NMAX,
FACT1,
FACT2,
TMAX,
WORMAX,
GORMAX,
PAMIN,
PAMAX
NMAX
Maximum number
of
timesteps allowed.
FACT
1
Factor
for
increasing
timestep
size
using automatic
timestep
control.
FACT1
= 1.0 for fixed
timestep size.
A
common
value
for
FACT1
is
1.25.
F
ACT2 Factor
for
decreasing timestep size using automatic
timestep
control. FACT2
=
1.0
for fixed
timestep
size.
A
common
value
for
FACT2
is
0.5.
TMAX
Maximum elapsed time
to be
simulated
(days);
the run
will
be
terminated when
the
time
exceeds
TMAX.
WORMAX
Maximum allowed water-oil ratio
for a
producing
oil
well
(STB/STB); WORMAX
>
0.
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GORMAX
Maximum allowed gas-oil
ratio
for a
producing
oil
well
(SCF/STB); GORMAX
;>
0.
PAMIN
Minimum
field
average pressure
(psia);
the run
will
be
terminated when
the
pore volume weighted average reser-
voir
pressure
<
PAMIN.
PAMAX
Maximum
field
average pressure (psia);
the run
will
be
terminated
when
the
pore volume weighted average reser-
voir pressure
>
PAMAX.
NOTE: PAMIN
and
PAMAX should
be
within
the
range
of
pressures covered
by the fluid PVT
tables discussed
in
Chapter 24.6.
3.
WOROCK
Omit
this record
ifWORMAX
*
0.
WOROCK Maximum
WOR
allowed
in
the
corresponding
Rock region.
NOTE:
If a
well
is
completed
in
more
than
one
Rock region,
the
largest maximum
WOR
which applies
to the
Rock
regions
penetrated
by the
well will
be
used
as the WOR
control
for
that well. Enter NROCK records
- one
for
each
Rock
region.
4.
GOROCK
Omit
this record
if
GORMAX
*
0.
GOROCK Maximum
GOR
allowed
in
the
corresponding Rock region.
NOTE:
If a
well
is
completed
in
more than
one
Rock region,
the
largest maximum
GOR
which applies
to the
Rock
regions
penetrated
by the
well will
be
used
as the GOR
control
for
that
well.
Enter NROCK records
- one
for
each
Rock region.
24.9 Solution Method Specification
1.
Heading
Up to 80
characters.
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Principles
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Reservoir Simulation
2,
KSOL
Solution method code.
MITR
Maximum number
of
LSOR iterations
per
timestep.
A
typical
value
is
100.
OMEGA Initial LSOR acceleration parameter. Values
of
OMEGA
should
be
between
1.0
and
2.0.
A
typical initial value
is
1.5.
TOL
Maximum acceptable pressure change
for
convergence
of
LSOR
iterations (psia).
A
typical value
is
0.1.
TOL1
Parameter
for
determining when
to
change OMEGA.
A
typical value
is
0,001.
If
TOL1
=
0.0,
the
initial
value
of
OMEGA will
be
used
for the
entire run.
DSMAX
Maximum saturation change allowed
per
timestep (traction).
The
timestep size will
be
reduced
by
FACT2
if
the
saturation
change
of
a
phase
in
any
gridblock
exceeds DSMAX during
a
timestep.
A
typical value
for
DSMAX
is
0.05.
DPMAX
Maximum pressure change allowed
per
timestep
(psia).
The
timestep size
will
be
reduced
by
FACT2
if the
pressure
change
in
any
gridblock exceeds DPMAX during
a
timestep.
A
typical value
of
DPMAX
is
100
psia.
NUMDIS
Code
for
controlling numerical dispersion
Code
1C
SOT
Value
1
2
3
4
5
Meaning
ID
Tridiagonal
Algorithm.
Use
with
ID
problems
and
OD
(tank) problems, i.e. when
II = JJ =
KK
=
1
.
Direct solution band algorithm.
Use
with
2D and
3D
problems.
LSORX
-
Iterative matrix
solver
with direct solver
in
x
direction.
LSORY
-
Iterative matrix solver with direct solver
in
y
direction.
LSORZ
-
Iterative matrix solver with direct solver
in
z
direction.
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Code
MT
T"NjfT"YFQ
fNUMUlo
Value
1
2
Meaning
Single-point
upstream weighting.
Two-point upstream weighting.
24.10
Analytic Aquifer Models
1.
Heading
Up to 80
characters.
2
IAQOPT
IAQOPT
Analytic
aquifer
model code.
Code
IAQOPT
Value
0
1
2
3
4
5
6
7
8
9
10
11
Meaning
No
analytic aquifer model
Pot
aquifer model (small
and
bounded
aquifer)
Steady-state aquifer model (constant aquifer pres-
sure)
Carter-Tracy aquifer
model:
Re/Rw
=1.5
Carter-Tracy aquifer model:
Re/Rw
= 2.0
Carter-Tracy aquifer model:
Re/Rw
= 3.0
Carter-Tracy aquifer model:
Re/Rw
= 4.0
Carter-Tracy aquifer model:
Re/Rw
= 5.0
Carter-Tracy aquifer
model:
Re/Rw
= 6.0
Carter-Tracy aquifer
model:
Re/Rw
= 8.0
Carter-Tracy aquifer
model:
Re/Rw
=
10.0
Carter-Tracy aquifer
model:
Re/Rw
=
°°
NOTE:
Only
one
aquifer model option
(IAQOPT)
may be
selected
for a
given run.
Different
aquifer
influx
strengths
may be
specified
for a
given
aquifer.
3.
NAQEN
Omit
this record
if
IAQOPT
*
1.
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Reservoir Simulation
NAQEN
Number
of
regions containing
a pot
aquifer.
4
I1,I2,J1,J2,K1,K2,POT
Omit
this record
iflAQOPT
*
1.
11
Coordinate
of
first
region block
in I
direction.
12
Coordinate
of
last region block
in I
direction.
J1
Coordinate
of first
region block
in J
direction.
J2
Coordinate
of
last region block
in J
direction.
Kl
Coordinate
of first
region block
in
K
direction.
K2
Coordinate
of
last
region
block
in K
direction.
POT
Pot
aquifer strength (SCF/psia).
NOTE: NAQEN records must
be
read.
5.
NAQEN
Omit
this record
iflAQOPT
*2,
NAQEN Number
of
regions
containing
a
steady-state
aquifer.
6.
II,
12,
Jl,
J2, Kl,
K2,
SSAQ
Omit
this record iflAQOPT
*
2.
Coordinate
of first
region block
in I
direction.
Coordinate
of
last region block
in I
direction.
Coordinate
of first
region
block
in J
direction.
Coordinate
of
last
region block
in J
direction.
Coordinate
of first
region block
in K
direction.
Coordinate
of
last region block
in K
direction.
Steady-state
aquifer
strength
(SCF/day/psia).
NOTE:
NAQEN records must
be
read.
7.
NAQREG
Omit
this record iflAQOPT
< 3.
NAQREG
Number
of
Carter-Tracy aquifer parameter regions.
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8
AQCR,
AQCW, AQMUW, AQK, AQPHI, AQH, AQS, AQRE
Omit
this record
iflAQOPT
< 3.
Aquifer
rock compressibility
(1/psia).
Aquifer
water compressibility (1/psia).
Aquifer
water viscosity (cp).
Aquifer
permeability (md).
Aquifer
porosity (fraction).
Aquifer
net
thickness (ft).
Aquifer
to
reservoir boundary interface (fraction).
A
value
of 0
implies there
is no
boundary (hence
no
influx);
a
value
of 1
implies that
the
aquifer
surrounds
the
gridblock.
AQRE
External aquifer radius (ft).
9.
NAQEN
Omit
this record iflAQOPT
< 3.
NAQEN
Number
of
regions containing
a
Carter-Tracy aquifer.
10
I1,I2,J1,J2,K1,K2
Omit
this record
iflAQOPT
< 3.
11
Coordinate
of first
region block
in I
direction.
12
Coordinate
of
last region block
in I
direction.
Jl
Coordinate
of first
region block
in J
direction.
J2
Coordinate
of
last region block
in J
direction.
Kl
Coordinate
of first
region
block
in K
direction.
K2
Coordinate
of
last region block
in K
direction.
NOTE: NAQEN lines must
be
read.
Repeat
records
8
through
10
a
total
of
NAQREG times.
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Chapter
25
Recurrent Data
Recurrent data records
are
read periodically during
the
course
of the
simulation
run. These data include
the
location
and
specification
of
wells
in the
model, changes
in
well completions
and field
operations over time,
a
schedule
of
well
rate
and/or
pressure
performance
over time, timestep control
information
for
advancing
the
simulation through time,
and
controls
on the
type
and
frequency of
printout information provided
by the
simulator.
1.
Major Heading
Up to 80
characters,
NOTE:
This record signifies
the
start
of
the
recurrent
data section.
25.1
Timestep
and
Output
Control
Timestep
and
output control
records
must
be
read
to
start
the
simulation.
1.
Heading
Up to 80
characters.
2.
IWLCNG, IOMETH
IWLCNG
Controls reading
of
well information.
IOMETH
Controls program output
and
well scheduling.
270
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Code
IWLCNG
lOMETH
Value
0
1
>
1
Meaning
Do not
read well information
Read well information
Number
of
elapsed time values
to be
read
on
record
3
.
The
program
will
print results
to
output
files at
these
elapsed times
and
allow
you to
change well character-
istics
after
the
last elapsed time entered during
this
recurrent
data period,
3.
FTIO
FTIO
Array containing total elapsed times
at
which output will occur
(days).
Up to 50
monotonically
increasing values
may be
entered.
The first
entry must
be
greater than
0 and
greater than
the
last entry
of any
previously completed recurrent data periods.
NOTE:
When
the
elapsed time
of
a
run
equals
an
FTIO
value,
the
well
and
basic summary reports will
be
printed. Maps will also
be
printed according
to the
instructions given
in
record
4,
4
IPMAP, ISOMAP, ISWMAP, ISGMAP, IPBMAP, IAQMAP
IPMAP
Control code
for
printing pressure array.
ISOMAP Control code
for
printing
oil
saturation array.
ISWMAP Control code
for
printing water saturation array.
ISGMAP Control code
for
printing
gas
saturation array.
IPBMAP Control code
for
printing bubble point pressure array.
IAQMAP
Control code
for
printing
aquifer
influx
array.
Code
Value
0
1
2
Meaning
Do not
print
the
array
Print
the
array
Print
the
array
and
a
digital contour plot
5
IVPMAP,
IZMAP,
IRCMAP,
IVSMAP,
IVRMAP
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