Added new shortned SPE9_CP data set for testing
This commit is contained in:
Kristian Hole-Drabløs
parent
1b18443791
commit
69650f65a1
536
spe9/SPE9_CP_SHORT.DATA
Normal file
536
spe9/SPE9_CP_SHORT.DATA
Normal file
|
|
@ -0,0 +1,536 @@
|
|||
-- This reservoir simulation deck is made available under the Open Database
|
||||
-- License: http://opendatacommons.org/licenses/odbl/1.0/. Any rights in
|
||||
-- individual contents of the database are licensed under the Database Contents
|
||||
-- License: http://opendatacommons.org/licenses/dbcl/1.0/
|
||||
|
||||
-- Copyright (C) 2015 Statoil
|
||||
|
||||
-- This simulation is based on the data given in
|
||||
-- 'Ninth SPE Comparative Solution Project:
|
||||
-- A Reexamination of Black-Oil Simulation',
|
||||
-- by J.E. Killough,
|
||||
-- Journal of Petroleum Technology, 1995
|
||||
|
||||
-- A dataset from one of the participants was supplied to the
|
||||
-- participants of SPE 9. Some of the information in this
|
||||
-- dataset has been used here as well.
|
||||
|
||||
-- The origin of information or data used in this simulation is
|
||||
-- specified in comments. This does not include data whose origin
|
||||
-- should be obvious to the reader.
|
||||
|
||||
|
||||
|
||||
-- NOTE: Changes should be made to the data entered in keywords PVTW and ROCK
|
||||
-- See comments under these keywords
|
||||
|
||||
----------------------------------------------------------------
|
||||
------------------------- SPE 9 --------------------------------
|
||||
----------------------------------------------------------------
|
||||
|
||||
RUNSPEC
|
||||
|
||||
TITLE
|
||||
SPE 9
|
||||
|
||||
DIMENS
|
||||
24 25 15 /
|
||||
OIL
|
||||
WATER
|
||||
GAS
|
||||
DISGAS
|
||||
-- From figure 7 in Killough's paper it is evident
|
||||
-- that GOR is increasing with time, meaning
|
||||
-- that there must be dissolved gas present
|
||||
|
||||
FIELD
|
||||
|
||||
START
|
||||
1 'JAN' 2015 /
|
||||
|
||||
WELLDIMS
|
||||
-- Item 1: maximum number of wells in the model
|
||||
-- - there are 26 wells in SPE9; 1 injector and 25 producers
|
||||
-- Item 2: maximum number of grid blocks connected to any one well
|
||||
-- - the injector is completed in 5 layers
|
||||
-- Item 3: maximum number of groups in the model
|
||||
-- - only one group in model
|
||||
-- Item 4: maximum number of wells in any one group
|
||||
-- - this can definitetly not be more than 26
|
||||
26 5 1 26 /
|
||||
TABDIMS
|
||||
-- The number of rows in SWOF exceeds the default maximum,
|
||||
-- so item 3 in this keyword must be changed:
|
||||
1* 1* 40 /
|
||||
|
||||
EQLDIMS
|
||||
/
|
||||
|
||||
--NSTACK
|
||||
-- 25 /
|
||||
-- Eclipse suggested increasing NSTACK
|
||||
|
||||
UNIFOUT
|
||||
|
||||
|
||||
GRID
|
||||
-- Killough says 'the grid was in conventional rectangular
|
||||
-- coordinates without corner point geometry or local grid refinements'
|
||||
|
||||
|
||||
NOECHO
|
||||
|
||||
INIT
|
||||
|
||||
INCLUDE
|
||||
'SPE9.GRDECL' /
|
||||
|
||||
PORO
|
||||
-- Porosity in each level is contant
|
||||
-- The values are specified in table 1 in Killough's paper
|
||||
600*0.087
|
||||
600*0.097
|
||||
600*0.111
|
||||
600*0.16
|
||||
600*0.13
|
||||
600*0.17
|
||||
600*0.17
|
||||
600*0.08
|
||||
600*0.14
|
||||
600*0.13
|
||||
600*0.12
|
||||
600*0.105
|
||||
600*0.12
|
||||
600*0.116
|
||||
600*0.157 /
|
||||
|
||||
-- PERMX, PERMY & PERMZ
|
||||
INCLUDE
|
||||
PERMVALUES.DATA /
|
||||
|
||||
ECHO
|
||||
|
||||
PROPS
|
||||
|
||||
PVTW
|
||||
-- Item 1: pressure reference (psia)
|
||||
-- Item 2: water FVF (rb per bbl or rb per stb)
|
||||
-- Item 3: water compressibility (psi^{-1})
|
||||
-- Item 4: water viscosity (cp)
|
||||
-- Item 5: water 'viscosibility' (psi^{-1})
|
||||
|
||||
-- Item 1 and 2 are stated in Killough, and item 5 is assumed = zero
|
||||
-- Item 3 and 4 are taken from SPE2
|
||||
3600 1.0034 3e-6 0.96 0 /
|
||||
|
||||
--NOTE:
|
||||
-- a) It is not explicitly stated in Killough that it is okay to use SPE2-values here.
|
||||
-- b) I am not 100% sure if the given compressibility value is at ref. pres. 3600psia.
|
||||
-- c) Item 3 and 4 can probably be explained on the basis of Killough's dataset. In
|
||||
-- order to do that I need info about keywords in VIP
|
||||
|
||||
ROCK
|
||||
-- Item 1: reference pressure (psia)
|
||||
-- Item 2: rock compressibility (psi^{-1})
|
||||
|
||||
-- Using values from SPE2:
|
||||
3600 4e-6 /
|
||||
|
||||
-- NOTE:
|
||||
-- a) It is not explicitly stated in Killough that it is okay to use SPE2-values here.
|
||||
-- a) I am not 100% sure if the given compressibility value is at 3600psia.
|
||||
-- b) 'Comp. Methods for Multiphase Flow in Porous Media' states
|
||||
-- that rock compr. is 1e-6 inverse psi. This is probably correct, as
|
||||
-- I think this is based on Killough's dataset - to be sure, I need
|
||||
-- more info about keywords in VIP.
|
||||
|
||||
DENSITY
|
||||
-- Density (lb per ft³) at surface cond. of
|
||||
-- oil, water and gas, respectively (in that order)
|
||||
|
||||
-- The values for oil and water are given by Killough to
|
||||
-- be 0.7206 and 1.0095 gm per cc, or equivalently
|
||||
-- 44.9856 and 63.0210 lb per ft³
|
||||
|
||||
-- A gas density of 0.07039 lb per ft³ was calculated using formula at
|
||||
-- petrowiki.org/Calculating_gas_properties:
|
||||
-- (28.967*Specific gravity*pressure)/(Z-factor*gas constant*temperature)
|
||||
-- with the values given in Killough's table 2 at 14.7 psia (1 atm).
|
||||
-- A temperature of 15C=59F was also used in the above formula.
|
||||
44.9856 63.0210 0.07039 /
|
||||
|
||||
PVTO
|
||||
-- Column 1: dissolved gas-oil ratio (Mscf per stb)
|
||||
-- Column 2: bubble point pressure for oil (psia)
|
||||
-- Column 3: oil FVF for saturated oil (rb per stb)
|
||||
-- Column 4: oil viscosity for saturated oil (cP)
|
||||
|
||||
-- Using values from table 2 in Killough's paper:
|
||||
0 14.7 1 1.20 /
|
||||
0.165 400 1.0120 1.17 /
|
||||
0.335 800 1.0255 1.14 /
|
||||
0.500 1200 1.0380 1.11 /
|
||||
0.665 1600 1.0510 1.08 /
|
||||
0.828 2000 1.0630 1.06 /
|
||||
0.985 2400 1.0750 1.03 /
|
||||
1.130 2800 1.0870 1.00 /
|
||||
1.270 3200 1.0985 0.98 /
|
||||
1.390 3600 1.1100 0.95 /
|
||||
1.500 4000 1.1200 0.94
|
||||
4600 1.1089 0.94 /
|
||||
-- 5000 1.1189 0.94 /
|
||||
/
|
||||
-- Comment in regards to the last row in PVTO:
|
||||
-- Killough says that 'at 1000psi above the saturation
|
||||
-- pressure the Bo is 0.999 times that of the Bo at Psat'
|
||||
-- which means that the FVF (i.e. Bo) at 4600psia is 0.999*0.1100=1.1089
|
||||
-- Killough also says that 'the oil viscosity does not
|
||||
-- increase with increasing pressure in undersaturated conditions'
|
||||
-- which explains why the oil viscosity is 0.94.
|
||||
|
||||
PVDG
|
||||
-- Column 1: gas phase pressure (psia)
|
||||
-- Column 2: gas formation volume factor (rb per Mscf)
|
||||
-- - This is calculated using formula:
|
||||
-- Bg=5.03676*Z*temperature(R)/pressure(psia) rb/Mscf
|
||||
-- where a constant temperature=100F=559.67R has been used because
|
||||
-- that is the initial reservoir temperature according to Killough's paper
|
||||
-- The above formula is retrieved from
|
||||
-- petrowiki.org/Gas_formation_volume_factor_and_density
|
||||
-- Column 3: gas viscosity (cP)
|
||||
|
||||
-- Using values from table 2 in Killough's paper:
|
||||
14.7 191.7443 0.0125
|
||||
400 5.8979 0.0130
|
||||
800 2.9493 0.0135
|
||||
1200 1.9594 0.0140
|
||||
1600 1.4695 0.0145
|
||||
2000 1.1797 0.0150
|
||||
2400 0.9796 0.0155
|
||||
2800 0.8397 0.0160
|
||||
3200 0.7398 0.0165
|
||||
3600 0.6498 0.0170
|
||||
4000 0.5849 0.0175 /
|
||||
|
||||
|
||||
SGOF
|
||||
-- Column 1: gas saturation
|
||||
-- Column 2: gas relative permeability
|
||||
-- Column 3: oil relative permeability when oil, gas and connate water are present
|
||||
-- Column 4: corresponding oil-gas capillary pressure (psi)
|
||||
|
||||
-- Using values from table 3 in Killough's paper:
|
||||
0 0 1 0
|
||||
0.04 0 0.6 0.2
|
||||
0.1 0.022 0.33 0.5
|
||||
0.2 0.1 0.1 1.0
|
||||
0.3 0.24 0.02 1.5
|
||||
0.4 0.34 0 2.0
|
||||
0.5 0.42 0 2.5
|
||||
0.6 0.5 0 3.0
|
||||
0.7 0.8125 0 3.5
|
||||
0.84891 0.9635 0 3.82 /
|
||||
--0.88491 1 0 3.9 /
|
||||
-- Comment in regards to the last row in SGOF:
|
||||
-- Changes have been made so that the last row
|
||||
-- is at a gas sat. of Sg=1-Swc=1-0.151090=0.84891
|
||||
-- The Krg and Pcog values corresponding to Sg=0.84891
|
||||
-- have been approximated by assuming linear relation between
|
||||
-- Krg/Pcog and Sg in the range Sg=0.7 to Sg=0.88491
|
||||
|
||||
SWOF
|
||||
-- Column 1: water saturation
|
||||
-- Column 2: water relative permeability
|
||||
-- Column 3: oil relative permeability when only oil and water are present
|
||||
-- Column 4: corresponding water-oil capillary pressure (psi)
|
||||
|
||||
-- These values are taken from Killough's dataset:
|
||||
0.151090 0.0 1.0 400.0
|
||||
0.151230 0.0 0.99997 359.190
|
||||
0.151740 0.0 0.99993 257.920
|
||||
0.152460 0.0 0.99991 186.310
|
||||
0.156470 0.0 0.999510 79.060
|
||||
0.165850 0.0 0.996290 40.010
|
||||
0.178350 0.0 0.991590 27.930
|
||||
0.203350 0.000010 0.978830 20.400
|
||||
0.253350 0.000030 0.943730 15.550
|
||||
0.350000 0.000280 0.830230 11.655
|
||||
0.352000 0.002292 0.804277 8.720
|
||||
0.354000 0.004304 0.778326 5.947
|
||||
0.356000 0.006316 0.752374 3.317
|
||||
0.358000 0.008328 0.726422 1.165
|
||||
0.360000 0.010340 0.700470 0.463
|
||||
0.364395 0.015548 0.642258 -0.499
|
||||
0.368790 0.020756 0.584046 -1.139
|
||||
0.370000 0.022190 0.568020 -1.194
|
||||
0.380000 0.035890 0.434980 -1.547
|
||||
0.400000 0.069530 0.171430 -1.604
|
||||
0.433450 0.087900 0.125310 -1.710
|
||||
0.461390 0.104910 0.094980 -1.780
|
||||
0.489320 0.123290 0.070530 -1.860
|
||||
0.517250 0.143030 0.051130 -1.930
|
||||
0.573120 0.186590 0.024640 -2.070
|
||||
0.601060 0.210380 0.016190 -2.130
|
||||
0.656930 0.261900 0.005940 -2.260
|
||||
0.712800 0.318650 0.001590 -2.380
|
||||
0.811110 0.430920 0.000020 -2.600
|
||||
0.881490 0.490000 0.000000 -2.750 /
|
||||
|
||||
|
||||
-- These values are approximated by reading off the graphs
|
||||
-- in figure 1 and 2 in Killough's paper:
|
||||
-- $$$ 0.18 0 1 21
|
||||
-- $$$ 0.25 0 0.95 16
|
||||
-- $$$ 0.34 0.07 0.5 12
|
||||
-- $$$ 0.345 0.08 0.4 9
|
||||
-- $$$ 0.35 0.09 0.3 6
|
||||
-- $$$ 0.355 0.095 0.2 0
|
||||
-- $$$ 0.36 0.1 0.19 -2
|
||||
-- $$$ 0.75 0.32 0.02 -2.5
|
||||
-- $$$ 0.88149 0.5 0 -3 /
|
||||
|
||||
|
||||
SOLUTION
|
||||
|
||||
EQUIL
|
||||
-- Item 1: datum depth (ft)
|
||||
-- Item 2: pressure at datum depth (psia)
|
||||
-- - Killough says initial oil phase pressure is
|
||||
-- - 3600psia at depth 9035ft
|
||||
-- Item 3: depth of water-oil contact (ft)
|
||||
-- - Given to be 9950 ft in Killough's paper
|
||||
-- Item 4: oil-water capillary pressure at the water oil contact (psi)
|
||||
-- - Given to be 0 in Killough's dataset
|
||||
-- - 0 in SPE2
|
||||
-- Item 5: depth of gas-oil contact (ft)
|
||||
-- - 8800ft in Killough's dataset
|
||||
-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
|
||||
-- - Given to be 0 in Killough's dataset
|
||||
-- - 0 in SPE2
|
||||
-- Item 7: RSVD-table
|
||||
-- Item 8: RVVD-table
|
||||
-- Item 9: OPM only supports item 9 equal to zero.
|
||||
|
||||
-- #: 1 2 3 4 5 6 7 8 9
|
||||
9035 3600 9950 0 8800 0 1 0 0 /
|
||||
|
||||
|
||||
RSVD
|
||||
-- The initial oil phase pressure is given to be 3600psia, at
|
||||
-- which the GOR is 1.39 Mscf per stb according to Killough's table 2.
|
||||
-- Since there is no free gas initially present*, the oil
|
||||
-- phase (with dissolved gas) must initially have a constant GOR as
|
||||
-- a function of depth through the reservoir (at the given pressure)
|
||||
8800 1.39
|
||||
9950 1.39 /
|
||||
-- *)
|
||||
-- This is explicitly stated in Killough's paper.
|
||||
-- Note that the initial oil phase pressure is the same as
|
||||
-- the saturation (bubble point) pressure of the oil.
|
||||
-- This should also imply that there is no free gas initially present.
|
||||
-- Since there is no free gas initially present, the gas-oil
|
||||
-- contact should lie above the reservoir, which it does (EQUIL, item 5)
|
||||
|
||||
SUMMARY
|
||||
|
||||
|
||||
-- Killough's figure 7:
|
||||
FGOR
|
||||
-- Killough's figure 8:
|
||||
FOPR
|
||||
-- Killough's figure 9:
|
||||
FGPR
|
||||
-- Killough's figure 10:
|
||||
FWPR
|
||||
-- Killough's figure 11:
|
||||
BPR
|
||||
1 1 1 /
|
||||
/
|
||||
-- Killough's figure 12:
|
||||
BGSAT
|
||||
1 13 1 /
|
||||
/
|
||||
-- Killough's figure 13:
|
||||
BWSAT
|
||||
10 25 15 /
|
||||
/
|
||||
-- Killough's figure 14:
|
||||
--WWIR
|
||||
-- 'INJE1' /
|
||||
-- Killough's figure 15:
|
||||
--WOPR
|
||||
-- 'PRODU21' /
|
||||
|
||||
-- In order to compare Eclipse with Flow:
|
||||
WBHP
|
||||
/
|
||||
WGIR
|
||||
/
|
||||
--WGIT
|
||||
--/
|
||||
WGPR
|
||||
/
|
||||
WGPT
|
||||
/
|
||||
WOIR
|
||||
/
|
||||
--WOIT
|
||||
--/
|
||||
WOPR
|
||||
/
|
||||
WOPT
|
||||
/
|
||||
WWIR
|
||||
/
|
||||
--WWIT
|
||||
--/
|
||||
WWPR
|
||||
/
|
||||
WWPT
|
||||
/
|
||||
|
||||
SCHEDULE
|
||||
|
||||
RPTRST
|
||||
'BASIC=2' /
|
||||
|
||||
TUNING
|
||||
4.0 60.0 0.1 /
|
||||
/
|
||||
12 2 15 /
|
||||
|
||||
|
||||
WELSPECS
|
||||
-- Column 3: I-value of well head or heel
|
||||
-- Column 4: J-value of well head or heel
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 5: ref. depth of BHP (ft)
|
||||
-- - stated in the middle of the top perforated cell
|
||||
-- - not anymore stated to be 9110ft in Killough
|
||||
-- Column 6: preferred phase for well
|
||||
-- - should be water for injector and oil for producers
|
||||
-- Column 7: drainage radius for calc. of productivity or
|
||||
-- injectivity indices (ft)
|
||||
-- - stated to be 60ft in Killough
|
||||
|
||||
-- #: 1 2 3 4 5 6 7
|
||||
'INJE1 ' 'P' 24 25 9110 'WATER' 60 /
|
||||
'PRODU2 ' 'P' 5 1 9110 'OIL' 60 /
|
||||
'PRODU3 ' 'P' 8 2 9110 'OIL' 60 /
|
||||
'PRODU4 ' 'P' 11 3 9110 'OIL' 60 /
|
||||
'PRODU5 ' 'P' 10 4 9110 'OIL' 60 /
|
||||
'PRODU6 ' 'P' 12 5 9110 'OIL' 60 /
|
||||
'PRODU7 ' 'P' 4 6 9110 'OIL' 60 /
|
||||
'PRODU8 ' 'P' 8 7 9110 'OIL' 60 /
|
||||
'PRODU9 ' 'P' 14 8 9110 'OIL' 60 /
|
||||
'PRODU10' 'P' 11 9 9110 'OIL' 60 /
|
||||
'PRODU11' 'P' 12 10 9110 'OIL' 60 /
|
||||
'PRODU12' 'P' 10 11 9110 'OIL' 60 /
|
||||
'PRODU13' 'P' 5 12 9110 'OIL' 60 /
|
||||
'PRODU14' 'P' 8 13 9110 'OIL' 60 /
|
||||
'PRODU15' 'P' 11 14 9110 'OIL' 60 /
|
||||
'PRODU16' 'P' 13 15 9110 'OIL' 60 /
|
||||
'PRODU17' 'P' 15 16 9110 'OIL' 60 /
|
||||
'PRODU18' 'P' 11 17 9110 'OIL' 60 /
|
||||
'PRODU19' 'P' 12 18 9110 'OIL' 60 /
|
||||
'PRODU20' 'P' 5 19 9110 'OIL' 60 /
|
||||
'PRODU21' 'P' 8 20 9110 'OIL' 60 /
|
||||
'PRODU22' 'P' 11 21 9110 'OIL' 60 /
|
||||
'PRODU23' 'P' 15 22 9110 'OIL' 60 /
|
||||
'PRODU24' 'P' 12 23 9110 'OIL' 60 /
|
||||
'PRODU25' 'P' 10 24 9110 'OIL' 60 /
|
||||
'PRODU26' 'P' 17 25 9110 'OIL' 60 /
|
||||
/
|
||||
|
||||
COMPDAT
|
||||
-- Column 2: I-value of connecting grid block
|
||||
-- Column 3: J-value of connecting grid block
|
||||
-- Column 4: K-value of upper connecting grid block
|
||||
-- Column 5: K-value of lower connecting grid block
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 9: well bore diameter
|
||||
-- - Killough says radius is 0.5ft
|
||||
|
||||
--Item 8 must be entered in order to get a match between Eclipse and Flow
|
||||
--No match if item 8 is defaulted
|
||||
|
||||
-- #: 1 2 3 4 5 6 7 8 9
|
||||
|
||||
'INJE1' 24 25 11 15 'OPEN' 1* 1* 1 /
|
||||
'PRODU2' 5 1 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU3' 8 2 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU4' 11 3 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU5' 10 4 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU6' 12 5 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU7' 4 6 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU8' 8 7 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU9' 14 8 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU10' 11 9 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU11' 12 10 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU12' 10 11 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU13' 5 12 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU14' 8 13 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU15' 11 14 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU16' 13 15 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU17' 15 16 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU18' 11 17 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU19' 12 18 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU20' 5 19 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU21' 8 20 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU22' 11 21 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU23' 15 22 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU24' 12 23 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU25' 10 24 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU26' 17 25 2 4 'OPEN' 1* 1* 1 /
|
||||
/
|
||||
|
||||
WCONINJE
|
||||
-- Killough says the water injector is set to a max rate of
|
||||
-- 5000 STBW per D with a max BHP of 4000psia at a reference
|
||||
-- depth of 9110ft subsea:
|
||||
-- #: 1 2 3 4 5 7
|
||||
'INJE1' 'WATER' 'OPEN' 'RATE' 5000 1* 4000 /
|
||||
/
|
||||
|
||||
WCONPROD
|
||||
-- Killough says the max oil rate for all producers is set to
|
||||
-- 1500 STBO per D at time zero and that the min flowing BHP
|
||||
-- is set to 1000psia (with a ref. depth of 9110ft
|
||||
-- for this pressure in all wells):
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
-- Here, the wildcard '*' has been used to indicate that this applies
|
||||
-- to all producers; PRODU1-PRODU25.
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
10*10 /
|
||||
|
||||
-- At 300 days, the max oil rate for all producers is lowered
|
||||
-- to 100 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 100 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
6*10 /
|
||||
|
||||
-- At 360 days, the max oil rate for all producers is changed
|
||||
-- back to 1500 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
5*10 /
|
||||
-- End of simulation at 900 days
|
||||
|
||||
END
|
||||
|
||||
|
||||
|
||||
684
spe9/SPE9_CP_SHORT_RESTART.DATA
Normal file
684
spe9/SPE9_CP_SHORT_RESTART.DATA
Normal file
|
|
@ -0,0 +1,684 @@
|
|||
-- This reservoir simulation deck is made available under the Open Database
|
||||
-- License: http://opendatacommons.org/licenses/odbl/1.0/. Any rights in
|
||||
-- individual contents of the database are licensed under the Database Contents
|
||||
-- License: http://opendatacommons.org/licenses/dbcl/1.0/
|
||||
|
||||
-- Copyright (C) 2015 Statoil
|
||||
|
||||
-- This simulation is based on the data given in
|
||||
-- 'Ninth SPE Comparative Solution Project:
|
||||
-- A Reexamination of Black-Oil Simulation',
|
||||
-- by J.E. Killough,
|
||||
-- Journal of Petroleum Technology, 1995
|
||||
|
||||
-- A dataset from one of the participants was supplied to the
|
||||
-- participants of SPE 9. Some of the information in this
|
||||
-- dataset has been used here as well.
|
||||
|
||||
-- The origin of information or data used in this simulation is
|
||||
-- specified in comments. This does not include data whose origin
|
||||
-- should be obvious to the reader.
|
||||
|
||||
|
||||
|
||||
-- NOTE: Changes should be made to the data entered in keywords PVTW and ROCK
|
||||
-- See comments under these keywords
|
||||
|
||||
----------------------------------------------------------------
|
||||
------------------------- SPE 9 --------------------------------
|
||||
----------------------------------------------------------------
|
||||
|
||||
RUNSPEC
|
||||
|
||||
TITLE
|
||||
SPE 9
|
||||
|
||||
DIMENS
|
||||
24 25 15 /
|
||||
OIL
|
||||
WATER
|
||||
GAS
|
||||
DISGAS
|
||||
-- From figure 7 in Killough's paper it is evident
|
||||
-- that GOR is increasing with time, meaning
|
||||
-- that there must be dissolved gas present
|
||||
|
||||
FIELD
|
||||
|
||||
START
|
||||
1 'JAN' 2015 /
|
||||
|
||||
WELLDIMS
|
||||
-- Item 1: maximum number of wells in the model
|
||||
-- - there are 26 wells in SPE9; 1 injector and 25 producers
|
||||
-- Item 2: maximum number of grid blocks connected to any one well
|
||||
-- - the injector is completed in 5 layers
|
||||
-- Item 3: maximum number of groups in the model
|
||||
-- - only one group in model
|
||||
-- Item 4: maximum number of wells in any one group
|
||||
-- - this can definitetly not be more than 26
|
||||
26 5 1 26 /
|
||||
TABDIMS
|
||||
-- The number of rows in SWOF exceeds the default maximum,
|
||||
-- so item 3 in this keyword must be changed:
|
||||
1* 1* 40 /
|
||||
|
||||
EQLDIMS
|
||||
/
|
||||
|
||||
--NSTACK
|
||||
-- 25 /
|
||||
-- Eclipse suggested increasing NSTACK
|
||||
|
||||
UNIFOUT
|
||||
UNIFIN
|
||||
|
||||
GRID
|
||||
-- Killough says 'the grid was in conventional rectangular
|
||||
-- coordinates without corner point geometry or local grid refinements'
|
||||
|
||||
|
||||
NOECHO
|
||||
|
||||
INIT
|
||||
|
||||
INCLUDE
|
||||
'SPE9.GRDECL' /
|
||||
|
||||
PORO
|
||||
-- Porosity in each level is contant
|
||||
-- The values are specified in table 1 in Killough's paper
|
||||
600*0.087
|
||||
600*0.097
|
||||
600*0.111
|
||||
600*0.16
|
||||
600*0.13
|
||||
600*0.17
|
||||
600*0.17
|
||||
600*0.08
|
||||
600*0.14
|
||||
600*0.13
|
||||
600*0.12
|
||||
600*0.105
|
||||
600*0.12
|
||||
600*0.116
|
||||
600*0.157 /
|
||||
|
||||
-- PERMX, PERMY & PERMZ
|
||||
INCLUDE
|
||||
PERMVALUES.DATA /
|
||||
|
||||
ECHO
|
||||
|
||||
PROPS
|
||||
|
||||
PVTW
|
||||
-- Item 1: pressure reference (psia)
|
||||
-- Item 2: water FVF (rb per bbl or rb per stb)
|
||||
-- Item 3: water compressibility (psi^{-1})
|
||||
-- Item 4: water viscosity (cp)
|
||||
-- Item 5: water 'viscosibility' (psi^{-1})
|
||||
|
||||
-- Item 1 and 2 are stated in Killough, and item 5 is assumed = zero
|
||||
-- Item 3 and 4 are taken from SPE2
|
||||
3600 1.0034 3e-6 0.96 0 /
|
||||
|
||||
--NOTE:
|
||||
-- a) It is not explicitly stated in Killough that it is okay to use SPE2-values here.
|
||||
-- b) I am not 100% sure if the given compressibility value is at ref. pres. 3600psia.
|
||||
-- c) Item 3 and 4 can probably be explained on the basis of Killough's dataset. In
|
||||
-- order to do that I need info about keywords in VIP
|
||||
|
||||
ROCK
|
||||
-- Item 1: reference pressure (psia)
|
||||
-- Item 2: rock compressibility (psi^{-1})
|
||||
|
||||
-- Using values from SPE2:
|
||||
3600 4e-6 /
|
||||
|
||||
-- NOTE:
|
||||
-- a) It is not explicitly stated in Killough that it is okay to use SPE2-values here.
|
||||
-- a) I am not 100% sure if the given compressibility value is at 3600psia.
|
||||
-- b) 'Comp. Methods for Multiphase Flow in Porous Media' states
|
||||
-- that rock compr. is 1e-6 inverse psi. This is probably correct, as
|
||||
-- I think this is based on Killough's dataset - to be sure, I need
|
||||
-- more info about keywords in VIP.
|
||||
|
||||
DENSITY
|
||||
-- Density (lb per ft³) at surface cond. of
|
||||
-- oil, water and gas, respectively (in that order)
|
||||
|
||||
-- The values for oil and water are given by Killough to
|
||||
-- be 0.7206 and 1.0095 gm per cc, or equivalently
|
||||
-- 44.9856 and 63.0210 lb per ft³
|
||||
|
||||
-- A gas density of 0.07039 lb per ft³ was calculated using formula at
|
||||
-- petrowiki.org/Calculating_gas_properties:
|
||||
-- (28.967*Specific gravity*pressure)/(Z-factor*gas constant*temperature)
|
||||
-- with the values given in Killough's table 2 at 14.7 psia (1 atm).
|
||||
-- A temperature of 15C=59F was also used in the above formula.
|
||||
44.9856 63.0210 0.07039 /
|
||||
|
||||
PVTO
|
||||
-- Column 1: dissolved gas-oil ratio (Mscf per stb)
|
||||
-- Column 2: bubble point pressure for oil (psia)
|
||||
-- Column 3: oil FVF for saturated oil (rb per stb)
|
||||
-- Column 4: oil viscosity for saturated oil (cP)
|
||||
|
||||
-- Using values from table 2 in Killough's paper:
|
||||
0 14.7 1 1.20 /
|
||||
0.165 400 1.0120 1.17 /
|
||||
0.335 800 1.0255 1.14 /
|
||||
0.500 1200 1.0380 1.11 /
|
||||
0.665 1600 1.0510 1.08 /
|
||||
0.828 2000 1.0630 1.06 /
|
||||
0.985 2400 1.0750 1.03 /
|
||||
1.130 2800 1.0870 1.00 /
|
||||
1.270 3200 1.0985 0.98 /
|
||||
1.390 3600 1.1100 0.95 /
|
||||
1.500 4000 1.1200 0.94
|
||||
4600 1.1089 0.94 /
|
||||
-- 5000 1.1189 0.94 /
|
||||
/
|
||||
-- Comment in regards to the last row in PVTO:
|
||||
-- Killough says that 'at 1000psi above the saturation
|
||||
-- pressure the Bo is 0.999 times that of the Bo at Psat'
|
||||
-- which means that the FVF (i.e. Bo) at 4600psia is 0.999*0.1100=1.1089
|
||||
-- Killough also says that 'the oil viscosity does not
|
||||
-- increase with increasing pressure in undersaturated conditions'
|
||||
-- which explains why the oil viscosity is 0.94.
|
||||
|
||||
PVDG
|
||||
-- Column 1: gas phase pressure (psia)
|
||||
-- Column 2: gas formation volume factor (rb per Mscf)
|
||||
-- - This is calculated using formula:
|
||||
-- Bg=5.03676*Z*temperature(R)/pressure(psia) rb/Mscf
|
||||
-- where a constant temperature=100F=559.67R has been used because
|
||||
-- that is the initial reservoir temperature according to Killough's paper
|
||||
-- The above formula is retrieved from
|
||||
-- petrowiki.org/Gas_formation_volume_factor_and_density
|
||||
-- Column 3: gas viscosity (cP)
|
||||
|
||||
-- Using values from table 2 in Killough's paper:
|
||||
14.7 191.7443 0.0125
|
||||
400 5.8979 0.0130
|
||||
800 2.9493 0.0135
|
||||
1200 1.9594 0.0140
|
||||
1600 1.4695 0.0145
|
||||
2000 1.1797 0.0150
|
||||
2400 0.9796 0.0155
|
||||
2800 0.8397 0.0160
|
||||
3200 0.7398 0.0165
|
||||
3600 0.6498 0.0170
|
||||
4000 0.5849 0.0175 /
|
||||
|
||||
|
||||
SGOF
|
||||
-- Column 1: gas saturation
|
||||
-- Column 2: gas relative permeability
|
||||
-- Column 3: oil relative permeability when oil, gas and connate water are present
|
||||
-- Column 4: corresponding oil-gas capillary pressure (psi)
|
||||
|
||||
-- Using values from table 3 in Killough's paper:
|
||||
0 0 1 0
|
||||
0.04 0 0.6 0.2
|
||||
0.1 0.022 0.33 0.5
|
||||
0.2 0.1 0.1 1.0
|
||||
0.3 0.24 0.02 1.5
|
||||
0.4 0.34 0 2.0
|
||||
0.5 0.42 0 2.5
|
||||
0.6 0.5 0 3.0
|
||||
0.7 0.8125 0 3.5
|
||||
0.84891 0.9635 0 3.82 /
|
||||
--0.88491 1 0 3.9 /
|
||||
-- Comment in regards to the last row in SGOF:
|
||||
-- Changes have been made so that the last row
|
||||
-- is at a gas sat. of Sg=1-Swc=1-0.151090=0.84891
|
||||
-- The Krg and Pcog values corresponding to Sg=0.84891
|
||||
-- have been approximated by assuming linear relation between
|
||||
-- Krg/Pcog and Sg in the range Sg=0.7 to Sg=0.88491
|
||||
|
||||
SWOF
|
||||
-- Column 1: water saturation
|
||||
-- Column 2: water relative permeability
|
||||
-- Column 3: oil relative permeability when only oil and water are present
|
||||
-- Column 4: corresponding water-oil capillary pressure (psi)
|
||||
|
||||
-- These values are taken from Killough's dataset:
|
||||
0.151090 0.0 1.0 400.0
|
||||
0.151230 0.0 0.99997 359.190
|
||||
0.151740 0.0 0.99993 257.920
|
||||
0.152460 0.0 0.99991 186.310
|
||||
0.156470 0.0 0.999510 79.060
|
||||
0.165850 0.0 0.996290 40.010
|
||||
0.178350 0.0 0.991590 27.930
|
||||
0.203350 0.000010 0.978830 20.400
|
||||
0.253350 0.000030 0.943730 15.550
|
||||
0.350000 0.000280 0.830230 11.655
|
||||
0.352000 0.002292 0.804277 8.720
|
||||
0.354000 0.004304 0.778326 5.947
|
||||
0.356000 0.006316 0.752374 3.317
|
||||
0.358000 0.008328 0.726422 1.165
|
||||
0.360000 0.010340 0.700470 0.463
|
||||
0.364395 0.015548 0.642258 -0.499
|
||||
0.368790 0.020756 0.584046 -1.139
|
||||
0.370000 0.022190 0.568020 -1.194
|
||||
0.380000 0.035890 0.434980 -1.547
|
||||
0.400000 0.069530 0.171430 -1.604
|
||||
0.433450 0.087900 0.125310 -1.710
|
||||
0.461390 0.104910 0.094980 -1.780
|
||||
0.489320 0.123290 0.070530 -1.860
|
||||
0.517250 0.143030 0.051130 -1.930
|
||||
0.573120 0.186590 0.024640 -2.070
|
||||
0.601060 0.210380 0.016190 -2.130
|
||||
0.656930 0.261900 0.005940 -2.260
|
||||
0.712800 0.318650 0.001590 -2.380
|
||||
0.811110 0.430920 0.000020 -2.600
|
||||
0.881490 0.490000 0.000000 -2.750 /
|
||||
|
||||
|
||||
-- These values are approximated by reading off the graphs
|
||||
-- in figure 1 and 2 in Killough's paper:
|
||||
-- $$$ 0.18 0 1 21
|
||||
-- $$$ 0.25 0 0.95 16
|
||||
-- $$$ 0.34 0.07 0.5 12
|
||||
-- $$$ 0.345 0.08 0.4 9
|
||||
-- $$$ 0.35 0.09 0.3 6
|
||||
-- $$$ 0.355 0.095 0.2 0
|
||||
-- $$$ 0.36 0.1 0.19 -2
|
||||
-- $$$ 0.75 0.32 0.02 -2.5
|
||||
-- $$$ 0.88149 0.5 0 -3 /
|
||||
|
||||
|
||||
SOLUTION
|
||||
-- ---------------------------------------------------------------------------
|
||||
RESTART
|
||||
SPE9_CP_SHORT 11 /
|
||||
|
||||
EQUIL
|
||||
-- Item 1: datum depth (ft)
|
||||
-- Item 2: pressure at datum depth (psia)
|
||||
-- - Killough says initial oil phase pressure is
|
||||
-- - 3600psia at depth 9035ft
|
||||
-- Item 3: depth of water-oil contact (ft)
|
||||
-- - Given to be 9950 ft in Killough's paper
|
||||
-- Item 4: oil-water capillary pressure at the water oil contact (psi)
|
||||
-- - Given to be 0 in Killough's dataset
|
||||
-- - 0 in SPE2
|
||||
-- Item 5: depth of gas-oil contact (ft)
|
||||
-- - 8800ft in Killough's dataset
|
||||
-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
|
||||
-- - Given to be 0 in Killough's dataset
|
||||
-- - 0 in SPE2
|
||||
-- Item 7: RSVD-table
|
||||
-- Item 8: RVVD-table
|
||||
-- Item 9: OPM only supports item 9 equal to zero.
|
||||
|
||||
-- #: 1 2 3 4 5 6 7 8 9
|
||||
9035 3600 9950 0 8800 0 1 0 0 /
|
||||
|
||||
|
||||
RSVD
|
||||
-- The initial oil phase pressure is given to be 3600psia, at
|
||||
-- which the GOR is 1.39 Mscf per stb according to Killough's table 2.
|
||||
-- Since there is no free gas initially present*, the oil
|
||||
-- phase (with dissolved gas) must initially have a constant GOR as
|
||||
-- a function of depth through the reservoir (at the given pressure)
|
||||
8800 1.39
|
||||
9950 1.39 /
|
||||
-- *)
|
||||
-- This is explicitly stated in Killough's paper.
|
||||
-- Note that the initial oil phase pressure is the same as
|
||||
-- the saturation (bubble point) pressure of the oil.
|
||||
-- This should also imply that there is no free gas initially present.
|
||||
-- Since there is no free gas initially present, the gas-oil
|
||||
-- contact should lie above the reservoir, which it does (EQUIL, item 5)
|
||||
|
||||
SUMMARY
|
||||
|
||||
|
||||
-- Killough's figure 7:
|
||||
FGOR
|
||||
-- Killough's figure 8:
|
||||
FOPR
|
||||
-- Killough's figure 9:
|
||||
FGPR
|
||||
-- Killough's figure 10:
|
||||
FWPR
|
||||
-- Killough's figure 11:
|
||||
BPR
|
||||
1 1 1 /
|
||||
/
|
||||
-- Killough's figure 12:
|
||||
BGSAT
|
||||
1 13 1 /
|
||||
/
|
||||
-- Killough's figure 13:
|
||||
BWSAT
|
||||
10 25 15 /
|
||||
/
|
||||
-- Killough's figure 14:
|
||||
--WWIR
|
||||
-- 'INJE1' /
|
||||
-- Killough's figure 15:
|
||||
--WOPR
|
||||
-- 'PRODU21' /
|
||||
|
||||
-- In order to compare Eclipse with Flow:
|
||||
WBHP
|
||||
/
|
||||
WGIR
|
||||
/
|
||||
--WGIT
|
||||
--/
|
||||
WGPR
|
||||
/
|
||||
WGPT
|
||||
/
|
||||
WOIR
|
||||
/
|
||||
--WOIT
|
||||
--/
|
||||
WOPR
|
||||
/
|
||||
WOPT
|
||||
/
|
||||
WWIR
|
||||
/
|
||||
--WWIT
|
||||
--/
|
||||
WWPR
|
||||
/
|
||||
WWPT
|
||||
/
|
||||
|
||||
SCHEDULE
|
||||
-- -----------------------------------------
|
||||
SKIPREST
|
||||
|
||||
|
||||
RPTRST
|
||||
'BASIC=2' /
|
||||
|
||||
TUNING
|
||||
4.0 60.0 0.1 /
|
||||
/
|
||||
12 2 15 /
|
||||
|
||||
|
||||
WELSPECS
|
||||
-- Column 3: I-value of well head or heel
|
||||
-- Column 4: J-value of well head or heel
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 5: ref. depth of BHP (ft)
|
||||
-- - stated in the middle of the top perforated cell
|
||||
-- - not anymore stated to be 9110ft in Killough
|
||||
-- Column 6: preferred phase for well
|
||||
-- - should be water for injector and oil for producers
|
||||
-- Column 7: drainage radius for calc. of productivity or
|
||||
-- injectivity indices (ft)
|
||||
-- - stated to be 60ft in Killough
|
||||
|
||||
-- #: 1 2 3 4 5 6 7
|
||||
'INJE1 ' 'P' 24 25 9110 'WATER' 60 /
|
||||
'PRODU2 ' 'P' 5 1 9110 'OIL' 60 /
|
||||
'PRODU3 ' 'P' 8 2 9110 'OIL' 60 /
|
||||
'PRODU4 ' 'P' 11 3 9110 'OIL' 60 /
|
||||
'PRODU5 ' 'P' 10 4 9110 'OIL' 60 /
|
||||
'PRODU6 ' 'P' 12 5 9110 'OIL' 60 /
|
||||
'PRODU7 ' 'P' 4 6 9110 'OIL' 60 /
|
||||
'PRODU8 ' 'P' 8 7 9110 'OIL' 60 /
|
||||
'PRODU9 ' 'P' 14 8 9110 'OIL' 60 /
|
||||
'PRODU10' 'P' 11 9 9110 'OIL' 60 /
|
||||
'PRODU11' 'P' 12 10 9110 'OIL' 60 /
|
||||
'PRODU12' 'P' 10 11 9110 'OIL' 60 /
|
||||
'PRODU13' 'P' 5 12 9110 'OIL' 60 /
|
||||
'PRODU14' 'P' 8 13 9110 'OIL' 60 /
|
||||
'PRODU15' 'P' 11 14 9110 'OIL' 60 /
|
||||
'PRODU16' 'P' 13 15 9110 'OIL' 60 /
|
||||
'PRODU17' 'P' 15 16 9110 'OIL' 60 /
|
||||
'PRODU18' 'P' 11 17 9110 'OIL' 60 /
|
||||
'PRODU19' 'P' 12 18 9110 'OIL' 60 /
|
||||
'PRODU20' 'P' 5 19 9110 'OIL' 60 /
|
||||
'PRODU21' 'P' 8 20 9110 'OIL' 60 /
|
||||
'PRODU22' 'P' 11 21 9110 'OIL' 60 /
|
||||
'PRODU23' 'P' 15 22 9110 'OIL' 60 /
|
||||
'PRODU24' 'P' 12 23 9110 'OIL' 60 /
|
||||
'PRODU25' 'P' 10 24 9110 'OIL' 60 /
|
||||
'PRODU26' 'P' 17 25 9110 'OIL' 60 /
|
||||
/
|
||||
|
||||
COMPDAT
|
||||
-- Column 2: I-value of connecting grid block
|
||||
-- Column 3: J-value of connecting grid block
|
||||
-- Column 4: K-value of upper connecting grid block
|
||||
-- Column 5: K-value of lower connecting grid block
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 9: well bore diameter
|
||||
-- - Killough says radius is 0.5ft
|
||||
|
||||
--Item 8 must be entered in order to get a match between Eclipse and Flow
|
||||
--No match if item 8 is defaulted
|
||||
|
||||
-- #: 1 2 3 4 5 6 7 8 9
|
||||
|
||||
'INJE1' 24 25 11 15 'OPEN' 1* 1* 1 /
|
||||
'PRODU2' 5 1 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU3' 8 2 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU4' 11 3 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU5' 10 4 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU6' 12 5 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU7' 4 6 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU8' 8 7 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU9' 14 8 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU10' 11 9 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU11' 12 10 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU12' 10 11 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU13' 5 12 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU14' 8 13 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU15' 11 14 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU16' 13 15 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU17' 15 16 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU18' 11 17 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU19' 12 18 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU20' 5 19 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU21' 8 20 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU22' 11 21 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU23' 15 22 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU24' 12 23 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU25' 10 24 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU26' 17 25 2 4 'OPEN' 1* 1* 1 /
|
||||
/
|
||||
|
||||
WCONINJE
|
||||
-- Killough says the water injector is set to a max rate of
|
||||
-- 5000 STBW per D with a max BHP of 4000psia at a reference
|
||||
-- depth of 9110ft subsea:
|
||||
-- #: 1 2 3 4 5 7
|
||||
'INJE1' 'WATER' 'OPEN' 'RATE' 5000 1* 4000 /
|
||||
/
|
||||
|
||||
WCONPROD
|
||||
-- Killough says the max oil rate for all producers is set to
|
||||
-- 1500 STBO per D at time zero and that the min flowing BHP
|
||||
-- is set to 1000psia (with a ref. depth of 9110ft
|
||||
-- for this pressure in all wells):
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
-- Here, the wildcard '*' has been used to indicate that this applies
|
||||
-- to all producers; PRODU1-PRODU25.
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
10*10 /
|
||||
|
||||
-- At 300 days, the max oil rate for all producers is lowered
|
||||
-- to 100 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 100 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
6*10 /
|
||||
|
||||
-- At 360 days, the max oil rate for all producers is changed
|
||||
-- back to 1500 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
5*10 /
|
||||
-- End of simulation at 900 days
|
||||
|
||||
END
|
||||
|
||||
|
||||
|
||||
|
||||
RPTRST
|
||||
'BASIC=2' /
|
||||
|
||||
TUNING
|
||||
4.0 60.0 0.1 /
|
||||
/
|
||||
12 2 15 /
|
||||
|
||||
|
||||
WELSPECS
|
||||
-- Column 3: I-value of well head or heel
|
||||
-- Column 4: J-value of well head or heel
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 5: ref. depth of BHP (ft)
|
||||
-- - stated in the middle of the top perforated cell
|
||||
-- - not anymore stated to be 9110ft in Killough
|
||||
-- Column 6: preferred phase for well
|
||||
-- - should be water for injector and oil for producers
|
||||
-- Column 7: drainage radius for calc. of productivity or
|
||||
-- injectivity indices (ft)
|
||||
-- - stated to be 60ft in Killough
|
||||
|
||||
-- #: 1 2 3 4 5 6 7
|
||||
'INJE1 ' 'P' 24 25 9110 'WATER' 60 /
|
||||
'PRODU2 ' 'P' 5 1 9110 'OIL' 60 /
|
||||
'PRODU3 ' 'P' 8 2 9110 'OIL' 60 /
|
||||
'PRODU4 ' 'P' 11 3 9110 'OIL' 60 /
|
||||
'PRODU5 ' 'P' 10 4 9110 'OIL' 60 /
|
||||
'PRODU6 ' 'P' 12 5 9110 'OIL' 60 /
|
||||
'PRODU7 ' 'P' 4 6 9110 'OIL' 60 /
|
||||
'PRODU8 ' 'P' 8 7 9110 'OIL' 60 /
|
||||
'PRODU9 ' 'P' 14 8 9110 'OIL' 60 /
|
||||
'PRODU10' 'P' 11 9 9110 'OIL' 60 /
|
||||
'PRODU11' 'P' 12 10 9110 'OIL' 60 /
|
||||
'PRODU12' 'P' 10 11 9110 'OIL' 60 /
|
||||
'PRODU13' 'P' 5 12 9110 'OIL' 60 /
|
||||
'PRODU14' 'P' 8 13 9110 'OIL' 60 /
|
||||
'PRODU15' 'P' 11 14 9110 'OIL' 60 /
|
||||
'PRODU16' 'P' 13 15 9110 'OIL' 60 /
|
||||
'PRODU17' 'P' 15 16 9110 'OIL' 60 /
|
||||
'PRODU18' 'P' 11 17 9110 'OIL' 60 /
|
||||
'PRODU19' 'P' 12 18 9110 'OIL' 60 /
|
||||
'PRODU20' 'P' 5 19 9110 'OIL' 60 /
|
||||
'PRODU21' 'P' 8 20 9110 'OIL' 60 /
|
||||
'PRODU22' 'P' 11 21 9110 'OIL' 60 /
|
||||
'PRODU23' 'P' 15 22 9110 'OIL' 60 /
|
||||
'PRODU24' 'P' 12 23 9110 'OIL' 60 /
|
||||
'PRODU25' 'P' 10 24 9110 'OIL' 60 /
|
||||
'PRODU26' 'P' 17 25 9110 'OIL' 60 /
|
||||
/
|
||||
|
||||
COMPDAT
|
||||
-- Column 2: I-value of connecting grid block
|
||||
-- Column 3: J-value of connecting grid block
|
||||
-- Column 4: K-value of upper connecting grid block
|
||||
-- Column 5: K-value of lower connecting grid block
|
||||
-- - these coordinates are listed in Killough's dataset
|
||||
-- Column 9: well bore diameter
|
||||
-- - Killough says radius is 0.5ft
|
||||
|
||||
--Item 8 must be entered in order to get a match between Eclipse and Flow
|
||||
--No match if item 8 is defaulted
|
||||
|
||||
-- #: 1 2 3 4 5 6 7 8 9
|
||||
|
||||
'INJE1' 24 25 11 15 'OPEN' 1* 1* 1 /
|
||||
'PRODU2' 5 1 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU3' 8 2 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU4' 11 3 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU5' 10 4 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU6' 12 5 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU7' 4 6 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU8' 8 7 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU9' 14 8 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU10' 11 9 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU11' 12 10 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU12' 10 11 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU13' 5 12 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU14' 8 13 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU15' 11 14 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU16' 13 15 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU17' 15 16 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU18' 11 17 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU19' 12 18 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU20' 5 19 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU21' 8 20 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU22' 11 21 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU23' 15 22 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU24' 12 23 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU25' 10 24 2 4 'OPEN' 1* 1* 1 /
|
||||
'PRODU26' 17 25 2 4 'OPEN' 1* 1* 1 /
|
||||
/
|
||||
|
||||
WCONINJE
|
||||
-- Killough says the water injector is set to a max rate of
|
||||
-- 5000 STBW per D with a max BHP of 4000psia at a reference
|
||||
-- depth of 9110ft subsea:
|
||||
-- #: 1 2 3 4 5 7
|
||||
'INJE1' 'WATER' 'OPEN' 'RATE' 5000 1* 4000 /
|
||||
/
|
||||
|
||||
WCONPROD
|
||||
-- Killough says the max oil rate for all producers is set to
|
||||
-- 1500 STBO per D at time zero and that the min flowing BHP
|
||||
-- is set to 1000psia (with a ref. depth of 9110ft
|
||||
-- for this pressure in all wells):
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
-- Here, the wildcard '*' has been used to indicate that this applies
|
||||
-- to all producers; PRODU1-PRODU25.
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
30*10 /
|
||||
|
||||
-- At 300 days, the max oil rate for all producers is lowered
|
||||
-- to 100 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 100 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
6*10 /
|
||||
|
||||
-- At 360 days, the max oil rate for all producers is changed
|
||||
-- back to 1500 STBO per D:
|
||||
WCONPROD
|
||||
-- #: 1 2 3 4 9
|
||||
'PRODU*' 'OPEN' 'ORAT' 1500 4* 1000 /
|
||||
/
|
||||
|
||||
|
||||
TSTEP
|
||||
54*10 /
|
||||
-- End of simulation at 900 days
|
||||
|
||||
END
|
||||
|
||||
Loading…
Reference in New Issue
Block a user