added SPE-case with copyright Statoil
This commit is contained in:
Lars Kristoffer Uhlen Blatny (MADI FER MEM)
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spe1_statoil/SPE1STATOIL.DATA
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418
spe1_statoil/SPE1STATOIL.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 1 & 2 ---------------------------------
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---------------------------------------------------------------------------
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RUNSPEC
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-- -------------------------------------------------------------------------
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TITLE
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SPE1
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-- Case 1: Include keyword DRSDT in SCHEDULE-section and the corresponding data
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-- Case 2: Do not include keyword DRSDT and the corresponding data
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DIMENS
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-- Dimensions are 10 x 10 x 3
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10 10 3 /
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OIL
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GAS
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WATER
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DISGAS
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-- DISGAS must be included if the run contains dissolved gas
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-- This means that we are dealing with live oil
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FIELD
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START
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-- Start date
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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 1 1 2 /
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UNIFOUT
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GRID
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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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-- Same reasoning as above (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 100*8345 100*8375 /
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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 (top layer), 50mD and 200mD respectivly.
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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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PVTW
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-- Item 1: pressure reference (psia)
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-- Item 2: water FVF (rb per bbl or rb per stb)
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-- Item 3: water compressibility (psi^{-1})
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-- Item 4: water viscosity (cp)
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-- Item 5: water 'viscosibility' (psi^{-1})
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-- Using values from Norne:
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-- In METRIC units:
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-- 277.0 1.038 4.67E-5 0.318 0.0 /
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-- In FIELD units:
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4017.55 1.038 3.22E-6 0.318 0.0 /
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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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-- Using values from Norne:
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-- In METRIC units:
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-- 277.0 4.84E-5 /
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-- In FIELD units:
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-- 4017.55 3.34E-6 /
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SWOF
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-- Column 1: water saturation
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-- - this has been set to (almost) equally spaced values from 0.12 to 1
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-- Column 2: corresponding water relative permeability
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-- - generated from the Corey-type approx. formula
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-- the coeffisient is set to 10e-5, S_{orw}=0 and S_{wi}=0.12
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-- Column 3: corresponding oil relative permeability when only
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-- oil and water are present
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-- - we will use the same values as in column 3 in SGOF
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-- this is not really correct, but since only the first
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-- two values are of importance, this does not really matter
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-- Column 4: corresponding water-oil capillary pressure (psi)
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0.12 0 1 0
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0.18 4.64876033057851E-008 1 0
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0.24 0.000000186 0.997 0
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0.3 4.18388429752066E-007 0.98 0
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0.36 7.43801652892562E-007 0.7 0
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0.42 1.16219008264463E-006 0.35 0
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0.48 1.67355371900826E-006 0.2 0
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0.54 2.27789256198347E-006 0.09 0
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0.6 2.97520661157025E-006 0.021 0
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0.66 3.7654958677686E-006 0.01 0
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0.72 4.64876033057851E-006 0.001 0
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0.78 0.000005625 0.0001 0
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0.84 6.69421487603306E-006 0 0
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0.91 8.05914256198347E-006 0 0
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1 0.00001 0 0 /
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SGOF
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-- Column 1: gas saturation
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-- Column 2: corresponding gas relative permeability
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-- Column 3: corresponding oil relative permeability when oil, gas
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-- and connate water are present
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-- Column 4: corresponding oil-gas capillary pressure (psi)
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-- Values in column 1 through 3 correspond to table 3 in Odeh's paper
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0 0 1 0
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0.001 0 1 0
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0.02 0 0.997 0
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0.05 0.005 0.980 0
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0.12 0.025 0.700 0
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0.2 0.075 0.350 0
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0.25 0.125 0.200 0
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0.3 0.190 0.090 0
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0.4 0.410 0.021 0
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0.45 0.60 0.010 0
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0.5 0.72 0.001 0
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0.6 0.87 0.0001 0
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0.7 0.94 0.000 0
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0.85 0.98 0.000 0
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0.88 0.984 0.000 0 /
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--1.00 1.0 0.000 0 /
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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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-- OPM 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, respectivly (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: corresponding 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: corresponding 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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-- Item 1: dissolved gas-oil ratio (Mscf per stb)
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-- Item 2: bubble point pressure (P-bub) (psia)
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-- Item 3: oil FVF for saturated oil (rb per stb)
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-- Item 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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-- Need to specify data for undersaturated oil for the highest GOR.
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-- Assume linear relation between GOR and FVF at 9014.7psi for saturated
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-- and undersaturated oil such that we can find a value for FVF at 9014.7psi
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-- and GOR=1.618. Use same approx. for viscosity.
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/
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SOLUTION
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-- -------------------------------------------------------------------------
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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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-- 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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-- Item 7: RSVD-table (enter true or false)
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-- Item 8: RVVD-table (enter true or false)
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-- Item 9: Set to zero 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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-- This table needs to be specified as item 7 in EQUIL is set to true
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-- Dissolved GOR initially constant with depth through the reservoir:
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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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-- 1b) GOR vs time
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WGOR
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-- Well Gas-Oil Ratio
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'PROD'
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/
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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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-- In order to compare Eclipse with Flow:
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WBHP
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'INJ'
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'PROD'
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/
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WGIR
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'INJ'
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'PROD'
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/
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WGIT
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'INJ'
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'PROD'
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/
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WGPR
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'INJ'
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'PROD'
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/
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WGPT
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'INJ'
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'PROD'
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/
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WOIR
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'INJ'
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'PROD'
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/
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WOIT
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'INJ'
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'PROD'
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/
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WOPR
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'INJ'
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'PROD'
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/
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WOPT
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'INJ'
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'PROD'
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/
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WWIR
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'INJ'
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'PROD'
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/
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WWIT
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'INJ'
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'PROD'
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/
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WWPR
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'INJ'
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'PROD'
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/
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WWPT
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'INJ'
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'PROD'
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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' /
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-- If no resolution (i.e. case 1) add:
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--DRSDT
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-- 0 /
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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
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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.
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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' 100000 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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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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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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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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489
spe3_statoil/SPE3CASE1STATOIL.DATA
Normal file
489
spe3_statoil/SPE3CASE1STATOIL.DATA
Normal file
|
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@ -0,0 +1,489 @@
|
|||
-- 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
|
||||
-- 'Third SPE Comparative Solution Project: Gas
|
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-- Cycling of Retrograde Condensate Reservoirs'
|
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-- by D.E. Kenyon and G.A. Behie,
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-- Journal of Petroleum Technology, August 1987
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----------------------------------------------------------------
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------------------ SPE 3, CASE 1 -------------------------------
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----------------------------------------------------------------
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RUNSPEC
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-- -------------------------------------------------------------
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TITLE
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SPE 3 - CASE 1
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DIMENS
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9 9 4 /
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OIL
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GAS
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WATER
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VAPOIL
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DISGAS
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FIELD
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START
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-- Start date
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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 two as both wells are located at two 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 2 1 2 /
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TABDIMS
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1 1 30 30 1 /
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UNIFOUT
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GRID
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-- ---------------------------------------------------------------
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-- The values in this section are retrieved from table 2
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-- and figure 1 in Kenyon & Behie
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NOECHO
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DX
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-- There are in total 324 cells with length 293.3ft in x-direction
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324*293.3 /
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DY
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-- Same reasoning as above (now in y-direction)
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324*293.3 /
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DZ
|
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-- The layers are 30, 30, 50 and 50 ft thick,
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-- in each layer there are 81 cells
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81*30 81*30 81*50 81*50 /
|
||||
|
||||
TOPS
|
||||
-- The depth of the top of each grid block
|
||||
81*7315 81*7345 81*7375 81*7425 /
|
||||
|
||||
PORO
|
||||
-- Constant porosity of 0.3 throughout all 324 grid cells
|
||||
324*0.13 /
|
||||
|
||||
PERMX
|
||||
-- The layers have horizontal (meaning x- and y-direction) permeability
|
||||
-- of 130mD, 40mD, 20mD and 150, respectivly, from top to bottom layer.
|
||||
81*130 81*40 81*20 81*150 /
|
||||
|
||||
PERMY
|
||||
81*130 81*40 81*20 81*150 /
|
||||
|
||||
PERMZ
|
||||
-- z-direction permeability is 13mD, 4mD, 2mD and 15mD from top
|
||||
-- to bottom layer
|
||||
81*13 81*4 81*2 81*15 /
|
||||
ECHO
|
||||
|
||||
PROPS
|
||||
-- -------------------------------------------------------------
|
||||
|
||||
ROCK
|
||||
-- Item 1: reference pressure (psia)
|
||||
-- Item 2: rock compressibility (psi^{-1})
|
||||
-- - PV (pore volume) compressibility = rock compressibility
|
||||
|
||||
-- Using values from table 2 in Kenyon & Behie:
|
||||
3550 4e-6 /
|
||||
|
||||
|
||||
SGOF
|
||||
-- Values taken from Kenyon & Behie's table 2
|
||||
-- Sg Krg Kro(g) Pc
|
||||
-- (first val 0) (first val 0) (only oil, gas & con. water) (for oil-gas)
|
||||
0.00 0.00 0.800 0
|
||||
0.04 0.005 0.650 0
|
||||
0.08 0.013 0.513 0
|
||||
0.12 0.026 0.400 0
|
||||
0.16 0.040 0.315 0
|
||||
0.20 0.058 0.250 0
|
||||
0.24 0.078 0.196 0
|
||||
0.28 0.100 0.150 0
|
||||
0.32 0.126 0.112 0
|
||||
0.36 0.156 0.082 0
|
||||
0.40 0.187 0.060 0
|
||||
0.44 0.222 0.040 0
|
||||
0.48 0.260 0.024 0
|
||||
0.52 0.300 0.012 0
|
||||
0.56 0.348 0.005 0
|
||||
0.60 0.400 0 0
|
||||
0.64 0.450 0 0
|
||||
0.68 0.505 0 0
|
||||
0.72 0.562 0 0
|
||||
0.76 0.620 0 0
|
||||
0.80 0.680 0 0
|
||||
0.84 0.740 0 0 /
|
||||
-- Since Kenyon & Behie say that 'Relative permeability data were
|
||||
-- based on the simplistic assumption that the rel. perm. of
|
||||
-- any phase depends only on its saturation', the Kro values
|
||||
-- depend only on So, which is 1-Sg-Swc when only
|
||||
-- oil, gas and connate water are present.
|
||||
SWOF
|
||||
-- Values taken from Kenyon & Behie's table 2
|
||||
-- Sw Krw 0 Kro(w) Pc
|
||||
-- (first val is (first val 0) (only oil & water) (for water-oil)
|
||||
-- connate water sat) (first val must be Krog at Sg=0)
|
||||
0.16 0.00 0.800 50
|
||||
0.20 0.002 0.650 32
|
||||
0.24 0.010 0.513 21
|
||||
0.28 0.020 0.400 15.5
|
||||
0.32 0.033 0.315 12.0
|
||||
0.36 0.049 0.250 9.2
|
||||
0.40 0.066 0.196 7.0
|
||||
0.44 0.090 0.150 5.3
|
||||
0.48 0.119 0.112 4.2
|
||||
0.52 0.150 0.082 3.4
|
||||
0.56 0.186 0.060 2.7
|
||||
0.60 0.227 0.040 2.1
|
||||
0.64 0.277 0.024 1.7
|
||||
0.68 0.330 0.012 1.3
|
||||
0.72 0.390 0.005 1.0
|
||||
0.76 0.462 0 0.7
|
||||
0.80 0.540 0 0.5
|
||||
0.84 0.620 0 0.4
|
||||
0.88 0.710 0 0.3
|
||||
0.92 0.800 0 0.2
|
||||
0.96 0.900 0 0.1
|
||||
1.00 1.000 0 0.0 /
|
||||
-- The Kro values depend only on So, which is 1-Sw when
|
||||
-- only oil and water are present
|
||||
-- Since we know Pcgw and Pcog=0, we can conclude that Pcwo
|
||||
-- should be equal to Pcgw
|
||||
-- Note that 0.16 is the connate water sat. Swc (= Swi here)
|
||||
|
||||
-------------------- START OF PVTsim GENERATED VALUES -------------------------
|
||||
-- Generated with PVTsim version 21.0.0 at 03.07.2015 10:04:27
|
||||
--#FIELD
|
||||
-- Salinity (mg/l)
|
||||
-- 0.0
|
||||
--
|
||||
DENSITY
|
||||
-- OilDens WaterDens GasDens
|
||||
-- lb/ft3 lb/ft3 lb/ft3
|
||||
43.33 62.37 0.05850 /
|
||||
--
|
||||
PVTW
|
||||
-- RefPres Bw Cw Vw dVw
|
||||
-- psia rb/stb 1/psia cP 1/psia
|
||||
3427.6 1.02629 0.30698E-05 0.31107 0.59410E-05 /
|
||||
--
|
||||
-- Separator Conditions
|
||||
-- Tsep(F) Psep(psia)
|
||||
-- ---------- ----------
|
||||
-- 80.00 815.00
|
||||
-- 80.00 315.00
|
||||
-- 80.00 65.00
|
||||
-- 59.00 14.70
|
||||
--
|
||||
-- Reservoir temperature (F)
|
||||
-- 200.00
|
||||
--
|
||||
-- Experiment type: Constant Mass Expansion
|
||||
--
|
||||
------------------------------------------------------------
|
||||
--SOLUTION PRESSURE OIL FVF OIL
|
||||
-- GOR Rs Po Bo VISCOSITY
|
||||
--MSCF/STB psia RB/STB cP
|
||||
------------------------------------------------------------
|
||||
PVTO
|
||||
0.189473 500.0 1.20936 0.219
|
||||
1000.0 1.19352 0.240
|
||||
1500.0 1.17997 0.260
|
||||
2000.0 1.16819 0.279
|
||||
2500.0 1.15780 0.299
|
||||
3000.0 1.14853 0.318
|
||||
3427.6 1.14135 0.334
|
||||
3500.0 1.14019 0.337
|
||||
4000.0 1.13263 0.356
|
||||
4500.0 1.12574 0.374
|
||||
5000.0 1.11941 0.393 /
|
||||
0.479365 1000.0 1.40215 0.149
|
||||
1500.0 1.37754 0.164
|
||||
2000.0 1.35701 0.179
|
||||
2500.0 1.33949 0.194
|
||||
3000.0 1.32426 0.208
|
||||
3427.6 1.31270 0.220
|
||||
3500.0 1.31085 0.222
|
||||
4000.0 1.29891 0.237
|
||||
4500.0 1.28817 0.251
|
||||
5000.0 1.27845 0.265 /
|
||||
0.826985 1500.0 1.62448 0.113
|
||||
2000.0 1.58913 0.124
|
||||
2500.0 1.56020 0.135
|
||||
3000.0 1.53584 0.146
|
||||
3427.6 1.51777 0.156
|
||||
3500.0 1.51492 0.157
|
||||
4000.0 1.49666 0.168
|
||||
4500.0 1.48052 0.179
|
||||
5000.0 1.46610 0.190 /
|
||||
1.250165 2000.0 1.89110 0.089
|
||||
2500.0 1.84197 0.098
|
||||
3000.0 1.80234 0.107
|
||||
3427.6 1.77380 0.114
|
||||
3500.0 1.76937 0.115
|
||||
4000.0 1.74128 0.124
|
||||
4500.0 1.71695 0.132
|
||||
5000.0 1.69557 0.141 /
|
||||
1.794854 2500.0 2.23421 0.073
|
||||
3000.0 2.16656 0.080
|
||||
3427.6 2.11974 0.086
|
||||
3500.0 2.11259 0.087
|
||||
4000.0 2.06805 0.093
|
||||
4500.0 2.03039 0.100
|
||||
5000.0 1.99794 0.106 /
|
||||
2.549781 3000.0 2.71411 0.071
|
||||
3427.6 2.63221 0.076
|
||||
3500.0 2.61998 0.077
|
||||
4000.0 2.54537 0.083
|
||||
4500.0 2.48418 0.089
|
||||
5000.0 2.43271 0.094 /
|
||||
2.951016 3427.6 2.96669 0.068
|
||||
3500.0 2.94777 0.069
|
||||
4000.0 2.83495 0.075
|
||||
4500.0 2.74550 0.080
|
||||
5000.0 2.67220 0.085 /
|
||||
3.033715 3500.0 3.01897 0.068
|
||||
4000.0 2.90343 0.073
|
||||
4500.0 2.81181 0.079
|
||||
5000.0 2.73675 0.084 /
|
||||
3.605023 4000.0 3.38017 0.065
|
||||
4500.0 3.27351 0.070
|
||||
5000.0 3.18612 0.075 /
|
||||
/
|
||||
------------------------------------------------------------
|
||||
--PRESSURE VAPORIZED GAS FVF GAS
|
||||
-- Pg OGR Rv Bg VISCOSITY
|
||||
-- psia STB/MSCF RB/MSCF cP
|
||||
------------------------------------------------------------
|
||||
PVTG
|
||||
500.0 0.0382886993 6.419987 0.012999 /
|
||||
1000.0 0.0314227763 3.007969 0.014122 /
|
||||
1500.0 0.0357629796 1.922602 0.015848 /
|
||||
2000.0 0.0473304978 1.408289 0.018550 /
|
||||
2500.0 0.0679314005 1.123337 0.022691 /
|
||||
3000.0 0.1043958616 0.959755 0.029087 /
|
||||
3427.6 0.1670518252 0.893267 0.038650 /
|
||||
3500.0 0.1670518252 0.884653 0.039158 /
|
||||
4000.0 0.1670518252 0.834785 0.042494
|
||||
0.1043958616 0.809080 0.035345
|
||||
0.0679314005 0.798204 0.031649
|
||||
0.0473304978 0.792752 0.029766
|
||||
0.0357629796 0.789094 0.028868
|
||||
0.0314227763 0.786258 0.028754
|
||||
0.0000000000 0.773146 0.026778 /
|
||||
/
|
||||
|
||||
--Warning: Constant reservoir fluid composition assumed above 3428. psia
|
||||
--Tabulated properties corrected to be monotonic with pressure
|
||||
|
||||
-------------------- END OF PVTsim GENERATED VALUES -------------------------
|
||||
|
||||
|
||||
SOLUTION
|
||||
|
||||
EQUIL
|
||||
-- Item 1: datum depth (ft)
|
||||
-- - Datum depth is at 7500ft (table 2, Kenyon & Behie)
|
||||
-- Item 2: pressure at datum depth (psia)
|
||||
-- - This is 3550psia (table 2, Kenyon & Behie)
|
||||
-- Item 3: depth of water-oil contact
|
||||
-- - See comment under item 5
|
||||
-- Item 4: oil-water capillary pressure at the water-oil contact
|
||||
-- - Cap. pres. at gas-water contact is 0 (table 2, Kenyon & Behie)
|
||||
-- - Cap. pres. for gas-oil is assumed 0 (table 2, Kenyon & Behie)
|
||||
-- - This means oil-water cap. pres. is 0 at contact
|
||||
-- Item 5: depth of gas-oil contact (ft)
|
||||
-- - Since all oil is initially contained in the gas phase,
|
||||
-- we can set item 5 equal to item 3, which must be
|
||||
-- set to the gas-water contact (since we have assumed no oil)
|
||||
-- The gas-water contact is at 7500ft (table 2, Kenyon & Behie)
|
||||
-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
|
||||
-- - Kenyon & Behie say this is assumed to be zero
|
||||
-- Item 7: RSVD-table (enter true or false)
|
||||
-- Item 8: RVVD-table (enter true or false)
|
||||
-- Item 9: must set to 0 as only this is supported in OPM
|
||||
|
||||
-- Item #: 1 2 3 4 5 6 7 8 9
|
||||
7500 3550 7500 0 7500 0 0 0 0 /
|
||||
--
|
||||
SUMMARY
|
||||
|
||||
WOPR
|
||||
-- Well Oil Production Rate
|
||||
'PROD'
|
||||
/
|
||||
|
||||
FOPR
|
||||
-- Field Oil Production Rate
|
||||
|
||||
WOPT
|
||||
-- Well Oil Production Total
|
||||
'PROD'
|
||||
/
|
||||
|
||||
FOPT
|
||||
-- Field Oil Production Total
|
||||
|
||||
BOSAT
|
||||
-- Oil Saturation in lower cell block of production well
|
||||
7 7 4 /
|
||||
/
|
||||
|
||||
BRS
|
||||
7 7 4 /
|
||||
1 1 1 /
|
||||
9 9 1 /
|
||||
9 1 4 /
|
||||
1 9 1 /
|
||||
4 4 4 /
|
||||
/
|
||||
|
||||
-- $$$ -- In order to compare Eclipse with Flow:
|
||||
-- $$$ WBHP
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
|
||||
SCHEDULE
|
||||
|
||||
RPTRST
|
||||
'BASIC=4' /
|
||||
|
||||
--DRSDT
|
||||
-- 0 /
|
||||
-- GOR cannot rise and free gas does not dissolve in undersaturated
|
||||
-- oil when setting DRSDT to 0,
|
||||
-- Notice that all GOR curves are decreasing
|
||||
-- -> adding DRSDT=0 should not make difference
|
||||
-- No difference in BOSAT, FOPR and FOPT graphs when including DRSDT=0
|
||||
|
||||
WELSPECS
|
||||
-- Item #: 1 2 3 4 5 6
|
||||
'PROD' 'G1' 7 7 7375 'GAS' /
|
||||
'INJ' 'G1' 1 1 7315 'GAS' /
|
||||
/
|
||||
-- The coordinates in item 3-4 are retrieved from figure 1 in Kenyon & Behie
|
||||
-- Ref. manual says the top-most perforation of the well is the
|
||||
-- recommended value for datum depth for BHP (item 5), which are the values
|
||||
-- that are entered above
|
||||
-- Both oil and gas are produced, and 'GAS' has been chosen as preferred
|
||||
-- phase (item 6) for PROD. All graphs will be identical if choosing OIL
|
||||
|
||||
COMPDAT
|
||||
-- Item #: 1 2 3 4 5 6 7 8 9
|
||||
'PROD' 7 7 3 4 'OPEN' 1* 1* 2 /
|
||||
'INJ' 1 1 1 2 'OPEN' 1* 1* 2 /
|
||||
/
|
||||
-- The coordinates item 2-5 are retrieved from figure 1 in Kenyon & Behie
|
||||
-- Item 9 is the well bore internal diameter,
|
||||
-- the radius is given to be 1ft in Kenyon & Behie
|
||||
|
||||
|
||||
WCONPROD
|
||||
-- Item #: 1 2 3 6 9
|
||||
'PROD' 'OPEN' 'GRAT' 2* 6200 2* 500 /
|
||||
/
|
||||
-- It is stated in Kenyon & Behie's table 3 that the production is
|
||||
-- controlled by separator gas rate of 6200Mscf per day (item 6)
|
||||
-- Kenyon also says that min BHP is 500psi (item 9)
|
||||
|
||||
WCONINJE
|
||||
-- Item #: 1 2 3 4 5 6 7
|
||||
'INJ' 'GAS' 'OPEN' 'RATE' 4700 1* 4000 /
|
||||
/
|
||||
-- In Case 1, Kenyon & Behie require a constant recycle-gas rate of
|
||||
-- 4700Mscf per day (item 5) for ten years
|
||||
-- Kenyon & Behie say max BHP is 4000psi (item 7)
|
||||
|
||||
TSTEP
|
||||
-- first year:
|
||||
7*52.14285714
|
||||
-- next nine 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
|
||||
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
|
||||
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 /
|
||||
|
||||
-- The cycling period ends after ten years,
|
||||
-- so we need to set item 5 in WCONINJE to 0
|
||||
WCONINJE
|
||||
-- Item #: 1 2 3 4 5 6 7
|
||||
'INJ' 'GAS' 'OPEN' 'RATE' 0 1* 4000 /
|
||||
/
|
||||
|
||||
TSTEP
|
||||
-- Advance the simulator once a month for next 5 years
|
||||
-- because Kenyon & Behie say models are to run for a total of 15 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
|
||||
31 28 31 30 31 30 31 31 30 31 30 31
|
||||
31 28 31 30 31 30 31 31 30 31 30 31 /
|
||||
|
||||
|
||||
END
|
||||
499
spe3_statoil/SPE3CASE2STATOIL.DATA
Normal file
499
spe3_statoil/SPE3CASE2STATOIL.DATA
Normal file
|
|
@ -0,0 +1,499 @@
|
|||
-- 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
|
||||
-- 'Third SPE Comparative Solution Project: Gas
|
||||
-- Cycling of Retrograde Condensate Reservoirs'
|
||||
-- by D.E. Kenyon and G.A. Behie,
|
||||
-- Journal of Petroleum Technology, August 1987
|
||||
|
||||
----------------------------------------------------------------
|
||||
------------------ SPE 3, CASE 2 -------------------------------
|
||||
----------------------------------------------------------------
|
||||
|
||||
RUNSPEC
|
||||
-- -------------------------------------------------------------
|
||||
|
||||
TITLE
|
||||
SPE 3 - CASE 2
|
||||
DIMENS
|
||||
9 9 4 /
|
||||
OIL
|
||||
GAS
|
||||
WATER
|
||||
VAPOIL
|
||||
DISGAS
|
||||
|
||||
FIELD
|
||||
|
||||
START
|
||||
-- Start date
|
||||
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 two as both wells are located at two 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 2 1 2 /
|
||||
|
||||
TABDIMS
|
||||
1 1 30 30 1 /
|
||||
|
||||
UNIFOUT
|
||||
|
||||
GRID
|
||||
-- ---------------------------------------------------------------
|
||||
-- The values in this section are retrieved from table 2
|
||||
-- and figure 1 in Kenyon & Behie
|
||||
NOECHO
|
||||
DX
|
||||
-- There are in total 324 cells with length 293.3ft in x-direction
|
||||
324*293.3 /
|
||||
DY
|
||||
-- Same reasoning as above (now in y-direction)
|
||||
324*293.3 /
|
||||
DZ
|
||||
-- The layers are 30, 30, 50 and 50 ft thick,
|
||||
-- in each layer there are 81 cells
|
||||
81*30 81*30 81*50 81*50 /
|
||||
|
||||
TOPS
|
||||
-- The depth of the top of each grid block
|
||||
81*7315 81*7345 81*7375 81*7425 /
|
||||
|
||||
PORO
|
||||
-- Constant porosity of 0.3 throughout all 324 grid cells
|
||||
324*0.13 /
|
||||
|
||||
PERMX
|
||||
-- The layers have horizontal (meaning x- and y-direction) permeability
|
||||
-- of 130mD, 40mD, 20mD and 150, respectivly, from top to bottom layer.
|
||||
81*130 81*40 81*20 81*150 /
|
||||
|
||||
PERMY
|
||||
81*130 81*40 81*20 81*150 /
|
||||
|
||||
PERMZ
|
||||
-- z-direction permeability is 13mD, 4mD, 2mD and 15mD from top
|
||||
-- to bottom layer
|
||||
81*13 81*4 81*2 81*15 /
|
||||
ECHO
|
||||
|
||||
PROPS
|
||||
-- -------------------------------------------------------------
|
||||
|
||||
ROCK
|
||||
-- Item 1: reference pressure (psia)
|
||||
-- Item 2: rock compressibility (psi^{-1})
|
||||
-- - PV (pore volume) compressibility = rock compressibility
|
||||
|
||||
-- Using values from table 2 in Kenyon & Behie:
|
||||
3550 4e-6 /
|
||||
|
||||
|
||||
SGOF
|
||||
-- Values taken from Kenyon & Behie's table 2
|
||||
-- Sg Krg Kro(g) Pc
|
||||
-- (first val 0) (first val 0) (only oil, gas & con. water) (for oil-gas)
|
||||
0.00 0.00 0.800 0
|
||||
0.04 0.005 0.650 0
|
||||
0.08 0.013 0.513 0
|
||||
0.12 0.026 0.400 0
|
||||
0.16 0.040 0.315 0
|
||||
0.20 0.058 0.250 0
|
||||
0.24 0.078 0.196 0
|
||||
0.28 0.100 0.150 0
|
||||
0.32 0.126 0.112 0
|
||||
0.36 0.156 0.082 0
|
||||
0.40 0.187 0.060 0
|
||||
0.44 0.222 0.040 0
|
||||
0.48 0.260 0.024 0
|
||||
0.52 0.300 0.012 0
|
||||
0.56 0.348 0.005 0
|
||||
0.60 0.400 0 0
|
||||
0.64 0.450 0 0
|
||||
0.68 0.505 0 0
|
||||
0.72 0.562 0 0
|
||||
0.76 0.620 0 0
|
||||
0.80 0.680 0 0
|
||||
0.84 0.740 0 0 /
|
||||
-- Since Kenyon & Behie say that 'Relative permeability data were
|
||||
-- based on the simplistic assumption that the rel. perm. of
|
||||
-- any phase depends only on its saturation', the Kro values
|
||||
-- depend only on So, which is 1-Sg-Swc when only
|
||||
-- oil, gas and connate water are present.
|
||||
SWOF
|
||||
-- Values taken from Kenyon & Behie's table 2
|
||||
-- Sw Krw 0 Kro(w) Pc
|
||||
-- (first val is (first val 0) (only oil & water) (for water-oil)
|
||||
-- connate water sat) (first val must be Krog at Sg=0)
|
||||
0.16 0.00 0.800 50
|
||||
0.20 0.002 0.650 32
|
||||
0.24 0.010 0.513 21
|
||||
0.28 0.020 0.400 15.5
|
||||
0.32 0.033 0.315 12.0
|
||||
0.36 0.049 0.250 9.2
|
||||
0.40 0.066 0.196 7.0
|
||||
0.44 0.090 0.150 5.3
|
||||
0.48 0.119 0.112 4.2
|
||||
0.52 0.150 0.082 3.4
|
||||
0.56 0.186 0.060 2.7
|
||||
0.60 0.227 0.040 2.1
|
||||
0.64 0.277 0.024 1.7
|
||||
0.68 0.330 0.012 1.3
|
||||
0.72 0.390 0.005 1.0
|
||||
0.76 0.462 0 0.7
|
||||
0.80 0.540 0 0.5
|
||||
0.84 0.620 0 0.4
|
||||
0.88 0.710 0 0.3
|
||||
0.92 0.800 0 0.2
|
||||
0.96 0.900 0 0.1
|
||||
1.00 1.000 0 0.0 /
|
||||
-- The Kro values depend only on So, which is 1-Sw when
|
||||
-- only oil and water are present
|
||||
-- Since we know Pcgw and Pcog=0, we can conclude that Pcwo
|
||||
-- should be equal to Pcgw
|
||||
-- Note that 0.16 is the connate water sat. Swc (= Swi here)
|
||||
|
||||
-------------------- START OF PVTsim GENERATED VALUES -------------------------
|
||||
-- Generated with PVTsim version 21.0.0 at 03.07.2015 10:04:27
|
||||
--#FIELD
|
||||
-- Salinity (mg/l)
|
||||
-- 0.0
|
||||
--
|
||||
DENSITY
|
||||
-- OilDens WaterDens GasDens
|
||||
-- lb/ft3 lb/ft3 lb/ft3
|
||||
43.33 62.37 0.05850 /
|
||||
--
|
||||
PVTW
|
||||
-- RefPres Bw Cw Vw dVw
|
||||
-- psia rb/stb 1/psia cP 1/psia
|
||||
3427.6 1.02629 0.30698E-05 0.31107 0.59410E-05 /
|
||||
--
|
||||
-- Separator Conditions
|
||||
-- Tsep(F) Psep(psia)
|
||||
-- ---------- ----------
|
||||
-- 80.00 815.00
|
||||
-- 80.00 315.00
|
||||
-- 80.00 65.00
|
||||
-- 59.00 14.70
|
||||
--
|
||||
-- Reservoir temperature (F)
|
||||
-- 200.00
|
||||
--
|
||||
-- Experiment type: Constant Mass Expansion
|
||||
--
|
||||
------------------------------------------------------------
|
||||
--SOLUTION PRESSURE OIL FVF OIL
|
||||
-- GOR Rs Po Bo VISCOSITY
|
||||
--MSCF/STB psia RB/STB cP
|
||||
------------------------------------------------------------
|
||||
PVTO
|
||||
0.189473 500.0 1.20936 0.219
|
||||
1000.0 1.19352 0.240
|
||||
1500.0 1.17997 0.260
|
||||
2000.0 1.16819 0.279
|
||||
2500.0 1.15780 0.299
|
||||
3000.0 1.14853 0.318
|
||||
3427.6 1.14135 0.334
|
||||
3500.0 1.14019 0.337
|
||||
4000.0 1.13263 0.356
|
||||
4500.0 1.12574 0.374
|
||||
5000.0 1.11941 0.393 /
|
||||
0.479365 1000.0 1.40215 0.149
|
||||
1500.0 1.37754 0.164
|
||||
2000.0 1.35701 0.179
|
||||
2500.0 1.33949 0.194
|
||||
3000.0 1.32426 0.208
|
||||
3427.6 1.31270 0.220
|
||||
3500.0 1.31085 0.222
|
||||
4000.0 1.29891 0.237
|
||||
4500.0 1.28817 0.251
|
||||
5000.0 1.27845 0.265 /
|
||||
0.826985 1500.0 1.62448 0.113
|
||||
2000.0 1.58913 0.124
|
||||
2500.0 1.56020 0.135
|
||||
3000.0 1.53584 0.146
|
||||
3427.6 1.51777 0.156
|
||||
3500.0 1.51492 0.157
|
||||
4000.0 1.49666 0.168
|
||||
4500.0 1.48052 0.179
|
||||
5000.0 1.46610 0.190 /
|
||||
1.250165 2000.0 1.89110 0.089
|
||||
2500.0 1.84197 0.098
|
||||
3000.0 1.80234 0.107
|
||||
3427.6 1.77380 0.114
|
||||
3500.0 1.76937 0.115
|
||||
4000.0 1.74128 0.124
|
||||
4500.0 1.71695 0.132
|
||||
5000.0 1.69557 0.141 /
|
||||
1.794854 2500.0 2.23421 0.073
|
||||
3000.0 2.16656 0.080
|
||||
3427.6 2.11974 0.086
|
||||
3500.0 2.11259 0.087
|
||||
4000.0 2.06805 0.093
|
||||
4500.0 2.03039 0.100
|
||||
5000.0 1.99794 0.106 /
|
||||
2.549781 3000.0 2.71411 0.071
|
||||
3427.6 2.63221 0.076
|
||||
3500.0 2.61998 0.077
|
||||
4000.0 2.54537 0.083
|
||||
4500.0 2.48418 0.089
|
||||
5000.0 2.43271 0.094 /
|
||||
2.951016 3427.6 2.96669 0.068
|
||||
3500.0 2.94777 0.069
|
||||
4000.0 2.83495 0.075
|
||||
4500.0 2.74550 0.080
|
||||
5000.0 2.67220 0.085 /
|
||||
3.033715 3500.0 3.01897 0.068
|
||||
4000.0 2.90343 0.073
|
||||
4500.0 2.81181 0.079
|
||||
5000.0 2.73675 0.084 /
|
||||
3.605023 4000.0 3.38017 0.065
|
||||
4500.0 3.27351 0.070
|
||||
5000.0 3.18612 0.075 /
|
||||
/
|
||||
------------------------------------------------------------
|
||||
--PRESSURE VAPORIZED GAS FVF GAS
|
||||
-- Pg OGR Rv Bg VISCOSITY
|
||||
-- psia STB/MSCF RB/MSCF cP
|
||||
------------------------------------------------------------
|
||||
PVTG
|
||||
500.0 0.0382886993 6.419987 0.012999 /
|
||||
1000.0 0.0314227763 3.007969 0.014122 /
|
||||
1500.0 0.0357629796 1.922602 0.015848 /
|
||||
2000.0 0.0473304978 1.408289 0.018550 /
|
||||
2500.0 0.0679314005 1.123337 0.022691 /
|
||||
3000.0 0.1043958616 0.959755 0.029087 /
|
||||
3427.6 0.1670518252 0.893267 0.038650 /
|
||||
3500.0 0.1670518252 0.884653 0.039158 /
|
||||
4000.0 0.1670518252 0.834785 0.042494
|
||||
0.1043958616 0.809080 0.035345
|
||||
0.0679314005 0.798204 0.031649
|
||||
0.0473304978 0.792752 0.029766
|
||||
0.0357629796 0.789094 0.028868
|
||||
0.0314227763 0.786258 0.028754
|
||||
0.0000000000 0.773146 0.026778 /
|
||||
/
|
||||
|
||||
--Warning: Constant reservoir fluid composition assumed above 3428. psia
|
||||
--Tabulated properties corrected to be monotonic with pressure
|
||||
|
||||
-------------------- END OF PVTsim GENERATED VALUES -------------------------
|
||||
|
||||
|
||||
SOLUTION
|
||||
|
||||
EQUIL
|
||||
-- Item 1: datum depth (ft)
|
||||
-- - Datum depth is at 7500ft (table 2, Kenyon & Behie)
|
||||
-- Item 2: pressure at datum depth (psia)
|
||||
-- - This is 3550psia (table 2, Kenyon & Behie)
|
||||
-- Item 3: depth of water-oil contact
|
||||
-- - See comment under item 5
|
||||
-- Item 4: oil-water capillary pressure at the water-oil contact
|
||||
-- - Cap. pres. at gas-water contact is 0 (table 2, Kenyon & Behie)
|
||||
-- - Cap. pres. for gas-oil is assumed 0 (table 2, Kenyon & Behie)
|
||||
-- - This means oil-water cap. pres. is 0 at contact
|
||||
-- Item 5: depth of gas-oil contact (ft)
|
||||
-- - Since all oil is initially contained in the gas phase,
|
||||
-- we can set item 5 equal to item 3, which must be
|
||||
-- set to the gas-water contact (since we have assumed no oil)
|
||||
-- The gas-water contact is at 7500ft (table 2, Kenyon & Behie)
|
||||
-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
|
||||
-- - Kenyon & Behie say this is assumed to be zero
|
||||
-- Item 7: RSVD-table (enter true or false)
|
||||
-- Item 8: RVVD-table (enter true or false)
|
||||
-- Item 9: must set to 0 as only this is supported in OPM
|
||||
|
||||
-- Item #: 1 2 3 4 5 6 7 8 9
|
||||
7500 3550 7500 0 7500 0 0 0 0 /
|
||||
--
|
||||
SUMMARY
|
||||
|
||||
WOPR
|
||||
-- Well Oil Production Rate
|
||||
'PROD'
|
||||
/
|
||||
|
||||
FOPR
|
||||
-- Field Oil Production Rate
|
||||
|
||||
WOPT
|
||||
-- Well Oil Production Total
|
||||
'PROD'
|
||||
/
|
||||
|
||||
FOPT
|
||||
-- Field Oil Production Total
|
||||
|
||||
BOSAT
|
||||
-- Oil Saturation in lower cell block of production well
|
||||
7 7 4 /
|
||||
/
|
||||
|
||||
BRS
|
||||
7 7 4 /
|
||||
1 1 1 /
|
||||
9 9 1 /
|
||||
9 1 4 /
|
||||
1 9 1 /
|
||||
4 4 4 /
|
||||
/
|
||||
|
||||
-- $$$ -- In order to compare Eclipse with Flow:
|
||||
-- $$$ WBHP
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WGPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WOPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWIR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWIT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWPR
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
-- $$$ WWPT
|
||||
-- $$$ 'INJ'
|
||||
-- $$$ 'PROD'
|
||||
-- $$$ /
|
||||
|
||||
SCHEDULE
|
||||
|
||||
RPTRST
|
||||
'BASIC=4' /
|
||||
|
||||
--DRSDT
|
||||
-- 0 /
|
||||
-- GOR cannot rise and free gas does not dissolve in undersaturated
|
||||
-- oil when setting DRSDT to 0,
|
||||
-- Notice that all GOR curves are decreasing
|
||||
-- -> adding DRSDT=0 should not make difference
|
||||
-- No difference in BOSAT, FOPR and FOPT graphs when including DRSDT=0
|
||||
|
||||
WELSPECS
|
||||
-- Item #: 1 2 3 4 5 6
|
||||
'PROD' 'G1' 7 7 7375 'GAS' /
|
||||
'INJ' 'G1' 1 1 7315 'GAS' /
|
||||
/
|
||||
-- The coordinates in item 3-4 are retrieved from figure 1 in Kenyon & Behie
|
||||
-- Ref. manual says the top-most perforation of the well is the
|
||||
-- recommended value for datum depth for BHP (item 5), which are the values
|
||||
-- that are entered above
|
||||
-- Both oil and gas are produced, and 'GAS' has been chosen as preferred
|
||||
-- phase (item 6) for PROD. All graphs will be identical if choosing OIL
|
||||
|
||||
COMPDAT
|
||||
-- Item #: 1 2 3 4 5 6 7 8 9
|
||||
'PROD' 7 7 3 4 'OPEN' 1* 1* 2 /
|
||||
'INJ' 1 1 1 2 'OPEN' 1* 1* 2 /
|
||||
/
|
||||
-- The coordinates item 2-5 are retrieved from figure 1 in Kenyon & Behie
|
||||
-- Item 9 is the well bore internal diameter,
|
||||
-- the radius is given to be 1ft in Kenyon & Behie
|
||||
|
||||
|
||||
WCONPROD
|
||||
-- Item #: 1 2 3 6 9
|
||||
'PROD' 'OPEN' 'GRAT' 2* 6200 2* 500 /
|
||||
/
|
||||
-- It is stated in Kenyon & Behie's table 3 that the production is
|
||||
-- controlled by separator gas rate of 6200Mscf per day (item 6)
|
||||
-- Kenyon also says that min BHP is 500psi (item 9)
|
||||
|
||||
WCONINJE
|
||||
-- Item #: 1 2 3 4 5 6 7
|
||||
'INJ' 'GAS' 'OPEN' 'RATE' 5700 1* 4000 /
|
||||
/
|
||||
-- In Case 2, Kenyon & Behie require a constant recycle-gas rate of
|
||||
-- 5700Mscf per day (item 5) for the first 5 years
|
||||
-- Kenyon & Behie say max BHP is 4000psi (item 7)
|
||||
|
||||
TSTEP
|
||||
-- first year:
|
||||
7*52.14285714
|
||||
-- next four 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
|
||||
31 28 31 30 31 30 31 31 30 31 30 31 /
|
||||
|
||||
-- For the next 5 years, item 5 in WCONINJE must be changed to 3700Mscf per day
|
||||
-- as stated in Kenyon & Behie
|
||||
WCONINJE
|
||||
-- Item #: 1 2 3 4 5 6 7
|
||||
'INJ' 'GAS' 'OPEN' 'RATE' 3700 1* 4000 /
|
||||
/
|
||||
|
||||
TSTEP
|
||||
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
|
||||
31 28 31 30 31 30 31 31 30 31 30 31
|
||||
31 28 31 30 31 30 31 31 30 31 30 31 /
|
||||
|
||||
|
||||
-- The cycling period ends after ten years,
|
||||
-- so we need to set item 5 in WCONINJE to 0
|
||||
WCONINJE
|
||||
-- Item #: 1 2 3 4 5 6 7
|
||||
'INJ' 'GAS' 'OPEN' 'RATE' 0 1* 4000 /
|
||||
/
|
||||
|
||||
TSTEP
|
||||
-- Advance the simulator once a month for next 5 years
|
||||
-- because Kenyon & Behie say models are to run for a total of 15 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
|
||||
31 28 31 30 31 30 31 31 30 31 30 31
|
||||
31 28 31 30 31 30 31 31 30 31 30 31 /
|
||||
|
||||
|
||||
END
|
||||
Loading…
Reference in New Issue
Block a user