498 lines
15 KiB
Plaintext
498 lines
15 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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-- '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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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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-- The max number of saturation and pressure nodes in the PROPS-tables
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-- exceeds the default -> item 3 and 4 in TABDIMS must be changed
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1* 1* 30 30 /
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EQLDIMS
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/
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UNIFOUT
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GRID
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-- The INIT keyword is used to request an .INIT file. The .INIT file
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-- is written before the simulation actually starts, and contains grid
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-- properties and saturation tables as inferred from the input
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-- deck. There are no other keywords which can be used to configure
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-- exactly what is written to the .INIT file.
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INIT
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-- ---------------------------------------------------------------
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-- 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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-- There are in total 324 cells with length 293.3ft 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 /
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TOPS
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-- The depth of the top of each grid block
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-- 81*7315 81*7345 81*7375 81*7425 /
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81*7315 /
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PORO
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-- Constant porosity of 0.3 throughout all 324 grid cells
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324*0.13 /
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PERMX
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-- The layers have horizontal (meaning x- and y-direction) permeability
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-- of 130mD, 40mD, 20mD and 150, respectively, from top to bottom layer.
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81*130 81*40 81*20 81*150 /
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PERMY
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81*130 81*40 81*20 81*150 /
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PERMZ
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-- z-direction permeability is 13mD, 4mD, 2mD and 15mD,respectively, from top
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-- to bottom layer
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81*13 81*4 81*2 81*15 /
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ECHO
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PROPS
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-- -------------------------------------------------------------
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ROCK
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-- Item 1: reference pressure (psia)
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-- Item 2: rock compressibility (psi^{-1})
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-- Using values from table 2 in Kenyon & Behie:
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3550 4e-6 /
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SGOF
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-- Values taken from Kenyon & Behie's table 2
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-- Sg Krg Kro(g) Pc
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-- (first val 0) (first val 0) (only oil, gas & con. water) (for oil-gas)
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0.00 0.00 0.800 0
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0.04 0.005 0.650 0
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0.08 0.013 0.513 0
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0.12 0.026 0.400 0
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0.16 0.040 0.315 0
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0.20 0.058 0.250 0
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0.24 0.078 0.196 0
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0.28 0.100 0.150 0
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0.32 0.126 0.112 0
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0.36 0.156 0.082 0
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0.40 0.187 0.060 0
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0.44 0.222 0.040 0
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0.48 0.260 0.024 0
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0.52 0.300 0.012 0
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0.56 0.348 0.005 0
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0.60 0.400 0 0
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0.64 0.450 0 0
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0.68 0.505 0 0
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0.72 0.562 0 0
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0.76 0.620 0 0
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0.80 0.680 0 0
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0.84 0.740 0 0 /
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-- Since Kenyon & Behie say that 'Relative permeability data were
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-- based on the simplistic assumption that the rel. perm. of
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-- any phase depends only on its saturation', the Kro values
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-- depend only on So, which is 1-Sg-Swc when only
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-- oil, gas and connate water are present. Swc=0.16 (= Swi here)
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SWOF
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-- Values taken from Kenyon & Behie's table 2
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-- Sw Krw 0 Kro(w) Pc
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-- (first val is (first val 0) (only oil & water) (for water-oil)
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-- connate water sat) (first val must be Krog at Sg=0)
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0.16 0.00 0.800 50
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0.20 0.002 0.650 32
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0.24 0.010 0.513 21
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0.28 0.020 0.400 15.5
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0.32 0.033 0.315 12.0
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0.36 0.049 0.250 9.2
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0.40 0.066 0.196 7.0
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0.44 0.090 0.150 5.3
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0.48 0.119 0.112 4.2
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0.52 0.150 0.082 3.4
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0.56 0.186 0.060 2.7
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0.60 0.227 0.040 2.1
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0.64 0.277 0.024 1.7
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0.68 0.330 0.012 1.3
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0.72 0.390 0.005 1.0
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0.76 0.462 0 0.7
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0.80 0.540 0 0.5
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0.84 0.620 0 0.4
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0.88 0.710 0 0.3
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0.92 0.800 0 0.2
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0.96 0.900 0 0.1
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1.00 1.000 0 0.0 /
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-- The Kro values depend only on So, which is 1-Sw when
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-- only oil and water are present
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-- Since we know Pcgw and since Pcog=0, we can conclude that Pcwo
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-- should be equal to Pcgw
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-------------------- START OF PVTsim GENERATED VALUES -------------------------
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-- Generated with PVTsim version 21.0.0 at 03.07.2015 10:04:27
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--#FIELD
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-- Salinity (mg/l)
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-- 0.0
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--
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DENSITY
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-- OilDens WaterDens GasDens
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-- lb/ft3 lb/ft3 lb/ft3
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43.33 62.37 0.05850 /
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--
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PVTW
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-- RefPres Bw Cw Vw dVw
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-- psia rb/stb 1/psia cP 1/psia
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3427.6 1.02629 0.30698E-05 0.31107 0.59410E-05 /
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--
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-- Separator Conditions (from table 3 in Kenyon & Behie's paper)
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-- Tsep(F) Psep(psia)
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-- ---------- ----------
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-- 80.00 815.00
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-- 80.00 315.00
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-- 80.00 65.00
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-- 59.00 14.70
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--
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-- Reservoir temperature (F)
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-- 200.00
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--
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-- Experiment type: Constant Mass Expansion
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--
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------------------------------------------------------------
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--SOLUTION PRESSURE OIL FVF OIL
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-- GOR Rs Po Bo VISCOSITY
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--MSCF/STB psia RB/STB cP
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------------------------------------------------------------
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PVTO
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0.189473 500.0 1.20936 0.219
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1000.0 1.19352 0.240
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1500.0 1.17997 0.260
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2000.0 1.16819 0.279
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2500.0 1.15780 0.299
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3000.0 1.14853 0.318
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3427.6 1.14135 0.334
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3500.0 1.14019 0.337
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4000.0 1.13263 0.356
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4500.0 1.12574 0.374
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5000.0 1.11941 0.393 /
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0.479365 1000.0 1.40215 0.149
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1500.0 1.37754 0.164
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2000.0 1.35701 0.179
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2500.0 1.33949 0.194
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3000.0 1.32426 0.208
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3427.6 1.31270 0.220
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3500.0 1.31085 0.222
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4000.0 1.29891 0.237
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4500.0 1.28817 0.251
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5000.0 1.27845 0.265 /
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0.826985 1500.0 1.62448 0.113
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2000.0 1.58913 0.124
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2500.0 1.56020 0.135
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3000.0 1.53584 0.146
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3427.6 1.51777 0.156
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3500.0 1.51492 0.157
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4000.0 1.49666 0.168
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4500.0 1.48052 0.179
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5000.0 1.46610 0.190 /
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1.250165 2000.0 1.89110 0.089
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2500.0 1.84197 0.098
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3000.0 1.80234 0.107
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3427.6 1.77380 0.114
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3500.0 1.76937 0.115
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4000.0 1.74128 0.124
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4500.0 1.71695 0.132
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5000.0 1.69557 0.141 /
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1.794854 2500.0 2.23421 0.073
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3000.0 2.16656 0.080
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3427.6 2.11974 0.086
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3500.0 2.11259 0.087
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4000.0 2.06805 0.093
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4500.0 2.03039 0.100
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5000.0 1.99794 0.106 /
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2.549781 3000.0 2.71411 0.071
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3427.6 2.63221 0.076
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3500.0 2.61998 0.077
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4000.0 2.54537 0.083
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4500.0 2.48418 0.089
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5000.0 2.43271 0.094 /
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2.951016 3427.6 2.96669 0.068
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3500.0 2.94777 0.069
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4000.0 2.83495 0.075
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4500.0 2.74550 0.080
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5000.0 2.67220 0.085 /
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3.033715 3500.0 3.01897 0.068
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4000.0 2.90343 0.073
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4500.0 2.81181 0.079
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5000.0 2.73675 0.084 /
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3.605023 4000.0 3.38017 0.065
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4500.0 3.27351 0.070
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5000.0 3.18612 0.075 /
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/
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------------------------------------------------------------
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--PRESSURE VAPORIZED GAS FVF GAS
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-- Pg OGR Rv Bg VISCOSITY
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-- psia STB/MSCF RB/MSCF cP
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------------------------------------------------------------
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PVTG
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500.0 0.0382886993 6.419987 0.012999 /
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1000.0 0.0314227763 3.007969 0.014122 /
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1500.0 0.0357629796 1.922602 0.015848 /
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2000.0 0.0473304978 1.408289 0.018550 /
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2500.0 0.0679314005 1.123337 0.022691 /
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3000.0 0.1043958616 0.959755 0.029087 /
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3427.6 0.1670518252 0.893267 0.038650 /
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3500.0 0.1670518252 0.884653 0.039158 /
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4000.0 0.1670518252 0.834785 0.042494
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0.1043958616 0.809080 0.035345
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0.0679314005 0.798204 0.031649
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0.0473304978 0.792752 0.029766
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0.0357629796 0.789094 0.028868
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0.0314227763 0.786258 0.028754
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0.0000000000 0.773146 0.026778 /
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/
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--Warning: Constant reservoir fluid composition assumed above 3428. psia
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--Tabulated properties corrected to be monotonic with pressure
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-------------------- END OF PVTsim GENERATED VALUES -------------------------
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SOLUTION
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EQUIL
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-- Item 1: datum depth (ft)
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-- - Datum depth is at 7500ft (table 2, Kenyon & Behie)
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-- Item 2: pressure at datum depth (psia)
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-- - This is 3550psia (table 2, Kenyon & Behie)
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-- Item 3: depth of water-oil contact
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-- - See comment under item 5
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-- Item 4: oil-water capillary pressure at the water-oil contact
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-- - Cap. pres. at gas-water contact is 0 (table 2, Kenyon & Behie)
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-- - Cap. pres. for gas-oil is assumed 0 (table 2, Kenyon & Behie)
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-- - This means oil-water cap. pres. is 0 at contact
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-- Item 5: depth of gas-oil contact (ft)
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-- - Since all oil is initially contained in the gas phase,
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-- we can set item 5 equal to item 3, which must be
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-- set to the gas-water contact (since we have assumed no oil)
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-- The gas-water contact is at 7500ft (table 2, Kenyon & Behie)
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-- Item 6: gas-oil capillary pressure at gas-oil contact (psi)
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-- - Kenyon & Behie say this is assumed to be zero
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-- Item 7: RSVD-table
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-- Item 8: RVVD-table
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-- Item 9: must set to 0 as only this is supported in OPM
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-- Item #: 1 2 3 4 5 6 7 8 9
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7500 3550 7500 0 7500 0 0 0 0 /
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--
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SUMMARY
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WOPR
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'PROD'
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/
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FOPR
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WOPT
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'PROD'
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/
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FOPT
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BOSAT
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-- Oil Saturation in lower cell block of production well
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7 7 4 /
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/
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BRS
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7 7 4 /
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1 1 1 /
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9 9 1 /
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9 1 4 /
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1 9 1 /
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4 4 4 /
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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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RPTRST
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'BASIC=4' /
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--DRSDT
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-- 0 /
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-- GOR cannot rise and free gas does not dissolve in undersaturated
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-- oil when setting DRSDT to 0,
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-- Notice that all GOR curves are decreasing
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-- -> adding DRSDT=0 should not make difference
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-- No difference in BOSAT, FOPR and FOPT graphs when including DRSDT=0
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WELSPECS
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-- Item #: 1 2 3 4 5 6
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'PROD' 'G1' 7 7 7375 'GAS' /
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'INJ' 'G1' 1 1 7315 'GAS' /
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/
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-- The coordinates in item 3-4 are retrieved from figure 1 in Kenyon & Behie
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-- Ref. manual says the top-most perforation of the well is the
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-- recommended value for datum depth for BHP (item 5), which are the values
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-- that are entered above
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-- Both oil and gas are produced, and 'GAS' has been chosen as preferred
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-- phase (item 6) for PROD. All graphs will be identical if choosing OIL
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COMPDAT
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-- Item #: 1 2 3 4 5 6 7 8 9
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'PROD' 7 7 3 4 'OPEN' 1* 1* 2 /
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'INJ' 1 1 1 2 'OPEN' 1* 1* 2 /
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/
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-- The coordinates in item 2-5 are retrieved from figure 1 in Kenyon & Behie
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-- Item 9 is the well bore internal diameter,
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-- the radius is given to be 1ft in Kenyon & Behie's paper
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WCONPROD
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-- Item #: 1 2 3 6 9
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'PROD' 'OPEN' 'GRAT' 2* 6200 2* 500 /
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/
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-- It is stated in Kenyon & Behie's table 3 that the production is
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-- controlled by a separator gas rate of 6200Mscf per day (item 6)
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-- Kenyon & Behie also say that min BHP is 500psi (item 9)
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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' 4700 1* 4000 /
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/
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-- In Case 1, Kenyon & Behie require a constant recycle-gas rate of
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-- 4700Mscf per day (item 5) for ten years
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-- Kenyon & Behie say max BHP is 4000psi (item 7)
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TSTEP
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-- first year:
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7*52.14285714
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-- next nine 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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-- The cycling period ends after ten years,
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-- so we need to set item 5 in WCONINJE to 0:
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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' 0 1* 4000 /
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/
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TSTEP
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-- Advance the simulator once a month for next 5 years
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-- because Kenyon & Behie say models are to run for a total of 15 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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END |