494 lines
12 KiB
Plaintext
494 lines
12 KiB
Plaintext
-- 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 ------------------------------------
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---------------------------------------------------------------------------
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RUNSPEC
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-- -------------------------------------------------------------------------
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TITLE
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SPE1 - CASE 1
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DIMENS
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10 5 10 /
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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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OIL
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GAS
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WATER
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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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3 20 1 3 /
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WSEGDIMS
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2 32 5 /
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UNIFIN
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UNIFOUT
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START
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1 'JAN' 2015 /
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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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BOX
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1 10 1 5 1 1 /
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TOPS
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50*7000 /
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BOX
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1 10 1 5 1 10 /
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DXV
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10*100 /
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DYV
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5*100 /
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DZ
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100*20
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50*100
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350*20
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/
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EQUALS
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-- 'DX' 100 /
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-- 'DY' 100 /
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'PERMX' 500 /
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'PERMZ' 50 /
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-- 'DZ' 20 /
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'PORO' 0.2 /
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-- 'TOPS' 7000 1 10 1 5 1 1 /
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-- 'DZ' 100 1 10 1 5 3 3 /
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-- 'PORO' 0.0 1 10 1 5 3 3 /
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/
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COPY
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PERMX PERMY /
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/
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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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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: 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: oil relative permeability when only 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: 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: 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
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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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-- 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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0.00100 14.7 1.0620 1.0400 /
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0.09050 264.7 1.1500 0.9750 /
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0.18000 514.7 1.2070 0.9100 /
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0.37100 1014.7 1.2950 0.8300 /
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0.63600 2014.7 1.4350 0.6950 /
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0.77500 2514.7 1.5000 0.6410 /
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0.93000 3014.7 1.5650 0.5940 /
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1.27000 4014.7 1.6950 0.5100
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5014.7 1.6710 0.5490
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9014.7 1.5790 0.7400 /
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1.61800 5014.7 1.8270 0.4490
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9014.7 1.7260 0.6050 /
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2.00000 8014.7 1.9500 0.3000
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9014.7 1.8500 0.5500 /
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/
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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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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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-- - 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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7200 4800 7300 0 7000 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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7000 1.270
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8000 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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-- In order to compare Eclipse with Flow:
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WBHP
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WGIR
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WGIT
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WGPR
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WGPT
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WOIR
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WOIT
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WOPR
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WOPT
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WWIR
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WWIT
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WWPR
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WWPT
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SOFR
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'PROD' /
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'WINJ' /
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SPR
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'PROD' /
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'WINJ' /
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/
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SPRD
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'PROD' /
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'WINJ' /
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/
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SCHEDULE
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-- -------------------------------------------------------------------------
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TUNING
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1* 1. /
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/
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20 1 50 1 16 16 /
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TUNINGDP
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/
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RPTSCHED
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'PRES' 'SGAS' 'RS' 'WELLS=5' WELSPECS /
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RPTRST
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'BASIC=2' /
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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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-- 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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'PROD' 'G' 1 5 7030 'OIL' 0.0 'STD' 'STOP' /
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'WINJ' 'G' 10 1 7030 'WAT' 0.0 'STD' 'STOP' /
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/
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COMPDAT
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'PROD' 1 5 2 2 3* 0.2 3* 'X' /
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'PROD' 2 5 2 2 3* 0.2 3* 'X' /
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'PROD' 3 5 2 2 3* 0.2 3* 'X' /
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'PROD' 4 5 2 2 3* 0.2 3* 'X' /
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'PROD' 5 5 2 2 3* 0.2 3* 'X' /
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'WINJ' 10 1 9 9 3* 0.2 3* 'X' /
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'WINJ' 9 1 9 9 3* 0.2 3* 'X' /
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'WINJ' 8 1 9 9 3* 0.2 3* 'X' /
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'WINJ' 7 1 9 9 3* 0.2 3* 'X' /
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'WINJ' 6 1 9 9 3* 0.2 3* 'X' /
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/
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WELSEGS
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-- Name Dep 1 Tlen 1 Vol 1
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'PROD' 7010 10 0.31 'INC' /
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-- First Last Branch Outlet Length Depth Diam Ruff Area Vol
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-- Seg Seg Num Seg Chang
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-- Main Stem
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2 2 1 1 20 20 0.2 1.E-3 1* 1* /
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-- Top Branch
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3 3 2 2 50 0 0.2 1.E-3 1* 1* /
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4 7 2 3 100 0 0.2 1.E-3 1* 1* /
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8 8 3 4 0.32800 0 0.500 3.3E-5 /
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9 9 4 5 0.32800 0 0.500 3.3E-5 /
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10 10 5 6 0.32800 0 0.500 3.3E-5 /
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/
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COMPSEGS
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-- Name
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'PROD' /
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-- I J K Brn Start End Dirn End
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-- No Length Length Penet Range
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-- Top Branch
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1 5 2 2 30 130 'X' 3* /
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2 5 2 2 130 230 'X' 3* /
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3 5 2 2 230 330 'X' 3* /
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4 5 2 2 330 430 'X' 3* /
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5 5 2 2 430 530 'X' 3* /
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-- Middle Branch
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/
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WSEGAICD
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-- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 ...
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PROD 8 8 3.260E-05 0.06391 63.678 0.48 1* 1* 1* 1 1* 2.1 1.2 OPEN 1* 1* 1* 1* 1* 1* /
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PROD 9 9 3.260E-05 0.07448 63.678 0.48 1* 1* 1* 1 1* 2.1 1.2 OPEN 1* 1* 1* 1* 1* 1* /
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PROD 10 10 3.260E-05 0.0876 63.678 0.48 0.53 0.048 4.89 0 9.876E6 2.1 1.2 OPEN 0.92 0.89 0.91 1.01 1.02 1.03 /
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/
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WELSEGS
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-- Name Dep 1 Tlen 1 Vol 1
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'WINJ' 7010 10 0.31 'INC' /
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-- First Last Branch Outlet Length Depth Diam Ruff Area Vol
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-- Seg Seg Num Seg Chang
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-- Main Stem
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2 13 1 1 20 20 0.2 1.E-3 1* 1* /
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-- Bottom Branch
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14 14 2 13 50 0 0.2 1.E-3 1* 1* /
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15 18 2 14 100 0 0.2 1.E-3 1* 1* /
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/
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COMPSEGS
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-- Name
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'WINJ' /
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-- I J K Brn Start End Dirn End
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-- No Length Length Penet Range
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-- Bottom Branch
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10 1 9 2 270 370 'X' 3* /
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9 1 9 2 370 470 'X' 3* /
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8 1 9 2 470 570 'X' 3* /
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7 1 9 2 570 670 'X' 3* /
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6 1 9 2 670 770 'X' 3* /
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/
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WCONPROD
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'PROD' 'OPEN' 'GRAT' 2* 100000. 2000 1* 2500 1* /
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/
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WCONINJE
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'WINJ' 'WAT' 'OPEN' 'RESV' 1* 2000 8000 1* /
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/
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TSTEP
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--Advance the simulater once a month for TEN years:
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30
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30
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180.
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/
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END
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