OilfieldToolsNet/opm-data
4
0
Fork 0
Code Issues Pull Requests Packages Projects Releases Wiki Activity

Add 2p oil gas case

Browse Source 
new file:   spe1/SPE1CASE2_OILGAS.DATA

	modified:   spe1/SPE1CASE2_OILGAS.DATA
This commit is contained in:
Tor Harald Sandve 2017-09-04 12:51:18 +02:00
parent a601812ce2
commit bd39395fc0
1 changed files with 329 additions and 0 deletions
Show Stats Download Patch File Download Diff File Expand all files Collapse all files

329
spe1/SPE1CASE2_OILGAS.DATA Normal file
View File

@ -0,0 +1,329 @@
-- 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
-- 'Comparison of Solutions to a Three-Dimensional
-- Black-Oil Reservoir Simulation Problem' by Aziz S. Odeh,
-- Journal of Petroleum Technology, January 1981
---------------------------------------------------------------------------
------------------------ SPE1 - CASE 2 ------------------------------------
---------------------------------------------------------------------------
RUNSPEC
-- -------------------------------------------------------------------------
TITLE
SPE1 - CASE 2 - 2P GAS OIL case
DIMENS
10 10 3 /
-- The number of equilibration regions is inferred from the EQLDIMS
-- keyword.
EQLDIMS
/
-- The number of PVTW tables is inferred from the TABDIMS keyword;
-- when no data is included in the keyword the default values are used.
TABDIMS
/
-- water is removed to facilitate a gas oil test case
OIL
GAS
DISGAS
-- As seen from figure 4 in Odeh, GOR is increasing with time,
-- which means that dissolved gas is present
FIELD
START
1 'JAN' 2015 /
WELLDIMS
-- Item 1: maximum number of wells in the model
-- - there are two wells in the problem; injector and producer
-- Item 2: maximum number of grid blocks connected to any one well
-- - must be one as the wells are located at specific grid blocks
-- Item 3: maximum number of groups in the model
-- - we are dealing with only one 'group'
-- Item 4: maximum number of wells in any one group
-- - there must be two wells in a group as there are two wells in total
2 3 1 2 /
UNIFOUT
GRID
-- The INIT keyword is used to request an .INIT file. The .INIT file
-- is written before the simulation actually starts, and contains grid
-- properties and saturation tables as inferred from the input
-- deck. There are no other keywords which can be used to configure
-- exactly what is written to the .INIT file.
INIT
-- -------------------------------------------------------------------------
NOECHO
DX
-- There are in total 300 cells with length 1000ft in x-direction
300*1000 /
DY
-- There are in total 300 cells with length 1000ft in y-direction
300*1000 /
DZ
-- The layers are 20, 30 and 50 ft thick, in each layer there are 100 cells
100*20 100*30 100*50 /
TOPS
-- The depth of the top of each grid block
100*8325 /
PORO
-- Constant porosity of 0.3 throughout all 300 grid cells
300*0.3 /
PERMX
-- The layers have perm. 500mD, 50mD and 200mD, respectively.
100*500 100*50 100*200 /
PERMY
-- Equal to PERMX
100*500 100*50 100*200 /
PERMZ
-- Cannot find perm. in z-direction in Odeh's paper
-- For the time being, we will assume PERMZ equal to PERMX and PERMY:
100*500 100*50 100*200 /
ECHO
PROPS
-- -------------------------------------------------------------------------
ROCK
-- Item 1: reference pressure (psia)
-- Item 2: rock compressibility (psi^{-1})
-- Using values from table 1 in Odeh:
14.7 3E-6 /
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: oil-gas capillary pressure (psi)
-- - stated to be zero in Odeh's paper
-- Values in column 1-3 are taken from table 3 in Odeh's paper:
0 0 1 0.01
1 1 0 0.01 /
--1.00 1.0 0.000 /
-- Warning from Eclipse: first sat. value in SWOF + last sat. value in SGOF
-- must not be greater than 1, but Eclipse still runs
-- Flow needs the sum to be excactly 1 so I added a row with gas sat. = 0.88
-- The corresponding krg value was estimated by assuming linear rel. between
-- gas sat. and krw. between gas sat. 0.85 and 1.00 (the last two values given)
DENSITY
-- Density (lb per ft³) at surface cond. of
-- oil, water and gas, respectively (in that order)
-- Using values from Norne:
-- In METRIC units:
-- 859.5 1033.0 0.854 /
-- In FIELD units:
53.66 64.49 0.0533 /
PVDG
-- Column 1: gas phase pressure (psia)
-- Column 2: gas formation volume factor (rb per Mscf)
-- - in Odeh's paper the units are said to be given in rb per bbl,
-- but this is assumed to be a mistake: FVF-values in Odeh's paper
-- are given in rb per scf, not rb per bbl. This will be in
-- agreement with conventions
-- Column 3: gas viscosity (cP)
-- Using values from lower right table in Odeh's table 2:
14.700 166.666 0.008000
264.70 12.0930 0.009600
514.70 6.27400 0.011200
1014.7 3.19700 0.014000
2014.7 1.61400 0.018900
2514.7 1.29400 0.020800
3014.7 1.08000 0.022800
4014.7 0.81100 0.026800
5014.7 0.64900 0.030900
9014.7 0.38600 0.047000 /
PVTO
-- Column 1: dissolved gas-oil ratio (Mscf per stb)
-- Column 2: bubble point pressure (psia)
-- Column 3: oil FVF for saturated oil (rb per stb)
-- Column 4: oil viscosity for saturated oil (cP)
-- Use values from top left table in Odeh's table 2:
0.0010 14.7 1.0620 1.0400 /
0.0905 264.7 1.1500 0.9750 /
0.1800 514.7 1.2070 0.9100 /
0.3710 1014.7 1.2950 0.8300 /
0.6360 2014.7 1.4350 0.6950 /
0.7750 2514.7 1.5000 0.6410 /
0.9300 3014.7 1.5650 0.5940 /
1.2700 4014.7 1.6950 0.5100
9014.7 1.5790 0.7400 /
1.6180 5014.7 1.8270 0.4490
9014.7 1.7370 0.6310 /
-- It is required to enter data for undersaturated oil for the highest GOR
-- (i.e. the last row) in the PVTO table.
-- In order to fulfill this requirement, values for oil FVF and viscosity
-- at 9014.7psia and GOR=1.618 for undersaturated oil have been approximated:
-- It has been assumed that there is a linear relation between the GOR
-- and the FVF when keeping the pressure constant at 9014.7psia.
-- From Odeh we know that (at 9014.7psia) the FVF is 2.357 at GOR=2.984
-- for saturated oil and that the FVF is 1.579 at GOR=1.27 for undersaturated oil,
-- so it is possible to use the assumption described above.
-- An equivalent approximation for the viscosity has been used.
/
SOLUTION
-- -------------------------------------------------------------------------
--PRESSURE
--300*4700 /
--SGAS
--300*0.0/
--RS
--300*1.27 /
EQUIL
-- Item 1: datum depth (ft)
-- Item 2: pressure at datum depth (psia)
-- - Odeh's table 1 says that initial reservoir pressure is
-- 4800 psi at 8400ft, which explains choice of item 1 and 2
-- Item 3: depth of water-oil contact (ft)
-- - chosen to be directly under the reservoir
-- Item 4: oil-water capillary pressure at the water oil contact (psi)
-- - given to be 0 in Odeh's paper
-- Item 5: depth of gas-oil contact (ft)
-- - chosen to be directly above the reservoir
-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
-- - given to be 0 in Odeh's paper
-- Item 7: RSVD-table
-- Item 8: RVVD-table
-- Item 9: Set to 0 as this is the only value supported by OPM
-- Item #: 1 2 3 4 5 6 7 8 9
8400 4800 8450 0 8300 0 1 0 0 /
RSVD
-- Dissolved GOR is initially constant with depth through the reservoir.
-- The reason is that the initial reservoir pressure given is higher
---than the bubble point presssure of 4014.7psia, meaning that there is no
-- free gas initially present.
8300 1.270
8450 1.270 /
SUMMARY
-- -------------------------------------------------------------------------
-- 1a) Oil rate vs time
FOPR
-- Field Oil Production Rate
-- Using FGOR instead of WGOR:PROD results in the same graph
FGOR
-- 2a) Pressures of the cell where the injector and producer are located
BPR
1 1 1 /
10 10 3 /
/
-- 2b) Gas saturation at grid points given in Odeh's paper
BGSAT
1 1 1 /
1 1 2 /
1 1 3 /
10 1 1 /
10 1 2 /
10 1 3 /
10 10 1 /
10 10 2 /
10 10 3 /
/
WBHP
/
SCHEDULE
-- -------------------------------------------------------------------------
RPTSCHED
'PRES' 'SGAS' 'RS' 'WELLS' /
RPTRST
'BASIC=1' 'DENSITY' 'ALLPROPS' /
-- If no resolution (i.e. case 1), the two following lines must be added:
--DRSDT
-- 0 /
-- Since this is Case 2, the two lines above have been commented out.
-- if DRSDT is set to 0, GOR cannot rise and free gas does not
-- dissolve in undersaturated oil -> constant bubble point pressure
WELSPECS
-- Item #: 1 2 3 4 5 6
'PROD' 'G1' 10 10 8400 'OIL' /
'INJ' 'G1' 1 1 8335 'GAS' /
/
-- Coordinates in item 3-4 are retrieved from Odeh's figure 1 and 2
-- Note that the depth at the midpoint of the well grid blocks
-- has been used as reference depth for bottom hole pressure in item 5
COMPDAT
-- Item #: 1 2 3 4 5 6 7 8 9
'PROD' 10 10 3 3 'OPEN' 1* 1* 0.5 /
'INJ' 1 1 1 1 'OPEN' 1* 1* 0.5 /
/
-- Coordinates in item 2-5 are retreived from Odeh's figure 1 and 2
-- Item 9 is the well bore internal diameter,
-- the radius is given to be 0.25ft in Odeh's paper
WCONPROD
-- Item #:1 2 3 4 5 9
'PROD' 'OPEN' 'ORAT' 20000 4* 1000 /
/
-- It is stated in Odeh's paper that the maximum oil prod. rate
-- is 20 000stb per day which explains the choice of value in item 4.
-- The items > 4 are defaulted with the exception of item 9,
-- the BHP lower limit, which is given to be 1000psia in Odeh's paper
WCONINJE
-- Item #:1 2 3 4 5 6 7
'INJ' 'GAS' 'OPEN' 'RATE' 10000 1* 9014 /
/
-- Stated in Odeh that gas inj. rate (item 5) is 100MMscf per day
-- BHP upper limit (item 7) should not be exceeding the highest
-- pressure in the PVT table=9014.7psia (default is 100 000psia)
TSTEP
--Advance the simulater once a month for TEN years:
31 28 31 30 31 30 31 31 30 31 30 31
31 28 31 30 31 30 31 31 30 31 30 31
31 28 31 30 31 30 31 31 30 31 30 31 /
--Advance the simulator once a year for TEN years:
--10*365 /
END