Add 2p oil gas case
new file: spe1/SPE1CASE2_OILGAS.DATA modified: spe1/SPE1CASE2_OILGAS.DATA
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Tor Harald Sandve
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spe1/SPE1CASE2_OILGAS.DATA
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329
spe1/SPE1CASE2_OILGAS.DATA
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-- This reservoir simulation deck is made available under the Open Database
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-- License: http://opendatacommons.org/licenses/odbl/1.0/. Any rights in
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-- individual contents of the database are licensed under the Database Contents
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-- License: http://opendatacommons.org/licenses/dbcl/1.0/
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-- Copyright (C) 2015 Statoil
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-- This simulation is based on the data given in
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-- 'Comparison of Solutions to a Three-Dimensional
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-- Black-Oil Reservoir Simulation Problem' by Aziz S. Odeh,
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-- Journal of Petroleum Technology, January 1981
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---------------------------------------------------------------------------
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------------------------ SPE1 - CASE 2 ------------------------------------
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---------------------------------------------------------------------------
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RUNSPEC
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-- -------------------------------------------------------------------------
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TITLE
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SPE1 - CASE 2 - 2P GAS OIL case
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DIMENS
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10 10 3 /
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-- The number of equilibration regions is inferred from the EQLDIMS
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-- keyword.
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EQLDIMS
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/
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-- The number of PVTW tables is inferred from the TABDIMS keyword;
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-- when no data is included in the keyword the default values are used.
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TABDIMS
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/
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-- water is removed to facilitate a gas oil test case
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OIL
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GAS
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DISGAS
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-- As seen from figure 4 in Odeh, GOR is increasing with time,
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-- which means that dissolved gas is present
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FIELD
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START
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1 'JAN' 2015 /
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WELLDIMS
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-- Item 1: maximum number of wells in the model
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-- - there are two wells in the problem; injector and producer
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-- Item 2: maximum number of grid blocks connected to any one well
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-- - must be one as the wells are located at specific grid blocks
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-- Item 3: maximum number of groups in the model
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-- - we are dealing with only one 'group'
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-- Item 4: maximum number of wells in any one group
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-- - there must be two wells in a group as there are two wells in total
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2 3 1 2 /
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UNIFOUT
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GRID
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-- The INIT keyword is used to request an .INIT file. The .INIT file
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-- is written before the simulation actually starts, and contains grid
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-- properties and saturation tables as inferred from the input
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-- deck. There are no other keywords which can be used to configure
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-- exactly what is written to the .INIT file.
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INIT
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-- -------------------------------------------------------------------------
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NOECHO
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DX
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-- There are in total 300 cells with length 1000ft in x-direction
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300*1000 /
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DY
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-- There are in total 300 cells with length 1000ft in y-direction
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300*1000 /
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DZ
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-- The layers are 20, 30 and 50 ft thick, in each layer there are 100 cells
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100*20 100*30 100*50 /
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TOPS
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-- The depth of the top of each grid block
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100*8325 /
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PORO
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-- Constant porosity of 0.3 throughout all 300 grid cells
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300*0.3 /
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PERMX
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-- The layers have perm. 500mD, 50mD and 200mD, respectively.
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100*500 100*50 100*200 /
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PERMY
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-- Equal to PERMX
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100*500 100*50 100*200 /
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PERMZ
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-- Cannot find perm. in z-direction in Odeh's paper
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-- For the time being, we will assume PERMZ equal to PERMX and PERMY:
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100*500 100*50 100*200 /
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ECHO
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PROPS
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-- -------------------------------------------------------------------------
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ROCK
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-- Item 1: reference pressure (psia)
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-- Item 2: rock compressibility (psi^{-1})
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-- Using values from table 1 in Odeh:
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14.7 3E-6 /
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SGOF
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-- Column 1: gas saturation
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-- Column 2: gas relative permeability
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-- Column 3: oil relative permeability when oil, gas and connate water are present
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-- Column 4: oil-gas capillary pressure (psi)
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-- - stated to be zero in Odeh's paper
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-- Values in column 1-3 are taken from table 3 in Odeh's paper:
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0 0 1 0.01
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1 1 0 0.01 /
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--1.00 1.0 0.000 /
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-- Warning from Eclipse: first sat. value in SWOF + last sat. value in SGOF
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-- must not be greater than 1, but Eclipse still runs
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-- Flow needs the sum to be excactly 1 so I added a row with gas sat. = 0.88
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-- The corresponding krg value was estimated by assuming linear rel. between
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-- gas sat. and krw. between gas sat. 0.85 and 1.00 (the last two values given)
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DENSITY
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-- Density (lb per ft³) at surface cond. of
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-- oil, water and gas, respectively (in that order)
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-- Using values from Norne:
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-- In METRIC units:
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-- 859.5 1033.0 0.854 /
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-- In FIELD units:
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53.66 64.49 0.0533 /
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PVDG
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-- Column 1: gas phase pressure (psia)
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-- Column 2: gas formation volume factor (rb per Mscf)
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-- - in Odeh's paper the units are said to be given in rb per bbl,
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-- but this is assumed to be a mistake: FVF-values in Odeh's paper
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-- are given in rb per scf, not rb per bbl. This will be in
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-- agreement with conventions
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-- Column 3: gas viscosity (cP)
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-- Using values from lower right table in Odeh's table 2:
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14.700 166.666 0.008000
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264.70 12.0930 0.009600
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514.70 6.27400 0.011200
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1014.7 3.19700 0.014000
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2014.7 1.61400 0.018900
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2514.7 1.29400 0.020800
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3014.7 1.08000 0.022800
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4014.7 0.81100 0.026800
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5014.7 0.64900 0.030900
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9014.7 0.38600 0.047000 /
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PVTO
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-- Column 1: dissolved gas-oil ratio (Mscf per stb)
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-- Column 2: bubble point pressure (psia)
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-- Column 3: oil FVF for saturated oil (rb per stb)
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-- Column 4: oil viscosity for saturated oil (cP)
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-- Use values from top left table in Odeh's table 2:
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0.0010 14.7 1.0620 1.0400 /
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0.0905 264.7 1.1500 0.9750 /
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0.1800 514.7 1.2070 0.9100 /
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0.3710 1014.7 1.2950 0.8300 /
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0.6360 2014.7 1.4350 0.6950 /
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0.7750 2514.7 1.5000 0.6410 /
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0.9300 3014.7 1.5650 0.5940 /
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1.2700 4014.7 1.6950 0.5100
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9014.7 1.5790 0.7400 /
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1.6180 5014.7 1.8270 0.4490
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9014.7 1.7370 0.6310 /
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-- It is required to enter data for undersaturated oil for the highest GOR
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-- (i.e. the last row) in the PVTO table.
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-- In order to fulfill this requirement, values for oil FVF and viscosity
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-- at 9014.7psia and GOR=1.618 for undersaturated oil have been approximated:
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-- It has been assumed that there is a linear relation between the GOR
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-- and the FVF when keeping the pressure constant at 9014.7psia.
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-- From Odeh we know that (at 9014.7psia) the FVF is 2.357 at GOR=2.984
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-- for saturated oil and that the FVF is 1.579 at GOR=1.27 for undersaturated oil,
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-- so it is possible to use the assumption described above.
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-- An equivalent approximation for the viscosity has been used.
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/
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SOLUTION
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-- -------------------------------------------------------------------------
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--PRESSURE
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--300*4700 /
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--SGAS
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--300*0.0/
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--RS
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--300*1.27 /
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EQUIL
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-- Item 1: datum depth (ft)
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-- Item 2: pressure at datum depth (psia)
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-- - Odeh's table 1 says that initial reservoir pressure is
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-- 4800 psi at 8400ft, which explains choice of item 1 and 2
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-- Item 3: depth of water-oil contact (ft)
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-- - chosen to be directly under the reservoir
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-- Item 4: oil-water capillary pressure at the water oil contact (psi)
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-- - given to be 0 in Odeh's paper
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-- Item 5: depth of gas-oil contact (ft)
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-- - chosen to be directly above the reservoir
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-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
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-- - given to be 0 in Odeh's paper
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-- Item 7: RSVD-table
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-- Item 8: RVVD-table
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-- Item 9: Set to 0 as this is the only value supported by OPM
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-- Item #: 1 2 3 4 5 6 7 8 9
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8400 4800 8450 0 8300 0 1 0 0 /
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RSVD
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-- Dissolved GOR is initially constant with depth through the reservoir.
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-- The reason is that the initial reservoir pressure given is higher
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---than the bubble point presssure of 4014.7psia, meaning that there is no
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-- free gas initially present.
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8300 1.270
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8450 1.270 /
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SUMMARY
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-- -------------------------------------------------------------------------
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-- 1a) Oil rate vs time
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FOPR
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-- Field Oil Production Rate
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-- Using FGOR instead of WGOR:PROD results in the same graph
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FGOR
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-- 2a) Pressures of the cell where the injector and producer are located
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BPR
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1 1 1 /
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10 10 3 /
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/
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-- 2b) Gas saturation at grid points given in Odeh's paper
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BGSAT
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1 1 1 /
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1 1 2 /
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1 1 3 /
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10 1 1 /
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10 1 2 /
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10 1 3 /
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10 10 1 /
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10 10 2 /
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10 10 3 /
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/
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WBHP
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/
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SCHEDULE
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-- -------------------------------------------------------------------------
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RPTSCHED
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'PRES' 'SGAS' 'RS' 'WELLS' /
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RPTRST
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'BASIC=1' 'DENSITY' 'ALLPROPS' /
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-- If no resolution (i.e. case 1), the two following lines must be added:
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--DRSDT
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-- 0 /
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-- Since this is Case 2, the two lines above have been commented out.
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-- if DRSDT is set to 0, GOR cannot rise and free gas does not
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-- dissolve in undersaturated oil -> constant bubble point pressure
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WELSPECS
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-- Item #: 1 2 3 4 5 6
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'PROD' 'G1' 10 10 8400 'OIL' /
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'INJ' 'G1' 1 1 8335 'GAS' /
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/
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-- Coordinates in item 3-4 are retrieved from Odeh's figure 1 and 2
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-- Note that the depth at the midpoint of the well grid blocks
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-- has been used as reference depth for bottom hole pressure in item 5
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COMPDAT
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-- Item #: 1 2 3 4 5 6 7 8 9
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'PROD' 10 10 3 3 'OPEN' 1* 1* 0.5 /
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'INJ' 1 1 1 1 'OPEN' 1* 1* 0.5 /
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/
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-- Coordinates in item 2-5 are retreived from Odeh's figure 1 and 2
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-- Item 9 is the well bore internal diameter,
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-- the radius is given to be 0.25ft in Odeh's paper
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WCONPROD
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-- Item #:1 2 3 4 5 9
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'PROD' 'OPEN' 'ORAT' 20000 4* 1000 /
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/
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-- It is stated in Odeh's paper that the maximum oil prod. rate
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-- is 20 000stb per day which explains the choice of value in item 4.
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-- The items > 4 are defaulted with the exception of item 9,
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-- the BHP lower limit, which is given to be 1000psia in Odeh's paper
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WCONINJE
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-- Item #:1 2 3 4 5 6 7
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'INJ' 'GAS' 'OPEN' 'RATE' 10000 1* 9014 /
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/
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-- Stated in Odeh that gas inj. rate (item 5) is 100MMscf per day
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-- BHP upper limit (item 7) should not be exceeding the highest
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-- pressure in the PVT table=9014.7psia (default is 100 000psia)
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TSTEP
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--Advance the simulater once a month for TEN years:
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31 28 31 30 31 30 31 31 30 31 30 31
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31 28 31 30 31 30 31 31 30 31 30 31
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31 28 31 30 31 30 31 31 30 31 30 31 /
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--Advance the simulator once a year for TEN years:
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--10*365 /
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END
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