CMG初学者请教~ [复制链接]

1.CMG-STARS中的网格边界条件是否为某种默认的，例如：周期性边界，定压等
2.另计算一个算例，发现和数值模拟的出入过大，是何原因？
  计算一个1*128*64的网格系统，蒸汽热采，只有重油和水组分
  初始条件3000KPA，127C，岩石上层距地表300M，SW=0.3,SO=0.7
   从开始就一直保持开井状态，时间步长0.3天
  源文件如下，望达人指教哪个地方设置的有问题~
   *TITLE1 'STARS dataset for 2D simulation - release 2002'
** Units
*INUNIT *SI
**CHECKONLY
*INTERRUPT *STOP
** Output / results
*WRST *TIME
*WPRN *GRID 1
*WPRN *ITER 1
*OUTPRN *WELL *ALL
*OUTPRN *ITER *NEWTON
*WSRF *GRID *TIME
*OUTSRF *WELL *COMPONENT *ALL *LAYER *ALL *DOWNHOLE
*OUTSRF *GRID *PRES *SW *SO *SG *TEMP *X *Y *VISO *VISW *VISG *THCONDUCT
*FLUXRC *MASDENW *MASDENO *MASDENG *OBHLOSS
*OUTSRF *SPECIAL *SOR 'Injector S1' 'Producer P1' INST
*SOR 'Injector S1' 'Producer P1' CUM
*MAXERROR 10
**************************************************************************
** GRID DEFINITION **
**************************************************************************
GRID CART 1 128 64
KDIR DOWN
DI CON 1.
DJ CON 1.
DK CON 1.
DEPTH 1 1 1 300.
** Porosity
POR CON 0.35
** Permeabilities (mD)
PERMI CON 2000.
PERMJ EQUALSI
PERMK EQUALSI * 0.5
END-GRID
*************************************************************************
** THERMAL PROPERTIES (rock/fluids) **
*************************************************************************
** 1st thermal rocktype
ROCKTYPE 1
** Rock compressibility (1/kPa)
CPOR 7.E-6
** Volumetric heat capacity of reservoir rock (J/m3-°C)
ROCKCP 2.39E+06
** Thermal conductivity of reservoir rock (J/m-day-°C)
THCONR 1.33E+05
** Thermal conductivity of water phase (J/m-day-°C)
THCONW 3.9E+05
** Thermal conductivity of oil phase (J/m-day-°C)
THCONO 1.33E+05
** Thermal conductivity of gas phase (J/m-day-°C)
THCONG 1.E+05
** Temperature of underburden / overburden
*HLOSST 127.
** Overburden/underburden heat loss:
** Volumetric heat capacity - Thermal conductivity
*HLOSSPROP OVERBUR 2.39E+06 2.333E+05
*HLOSSPROP UNDERBUR 2.39E+06 2.333E+05
** Grid of thermal rocktypes
THTYPE CON 1.
*************************************************************************
** Component definitions **
*************************************************************************
*MODEL 2 2 2 1
** Component names, molar weight (Kg/mol), critical pressure (kPa) and temperature (°C)
*COMPNAME 'WATER' 'BITUMEN'
*CMM 0.01802 0.5
*PCRIT 22048 0.0E+0
*TCRIT 374.15 0.0E+0
** Coefficients in the correlation for gas-liquid K-values
** 0 for 1st column means default water values
*KV1 1.186e+7 0.E+00
*KV4 -3816.44 0.E+00
*KV5 -227.02 0.E+00
** Coefficients in the gas heat capacity correlation
*CPG1 32.243 1000.0
*CPG2 1.924e-3 0.0E+0
*CPG3 1.055e-5 0.0E+0
*CPG4 -3.596e-9 0.0E+0
** Vaporization enthalpy (J/gmol) at reference temperature
*HVAPR 4820 0
** Reference conditions (Pressure in kPa, T° in °C)
*PRSR 100
*TEMR 25
** Volume weight (Kg/m3) at reference conditions
*MASSDEN 1.000E+3 1.010E+3
** Liquid compressibility at constant temperature (1/kPa)
*CP 5.8E-7 6.84E-7
** 1st and 2nd coefficients of thermal expansion correlation (1/°C, 1/°C**2)
*CT1 7.2E-4 7.85E-4
*CT2 0.0E+0 0.0E+0
** Table of liquid viscosities (in cp) versus T° for each component
*VISCTABLE
** T° WATER BITUMEN
10 0 1700000
20 0 319000
30 0 80722
40 0 22300
50 0 8028
60 0 3073
70 0 1415.4
80 0 680.6
100 0 212.6
125 0 70.94
150 0 30.92
175 0 16.35
200 0 9.96
225 0 6.787
250 0 4.999
275 0 3.73
300 0 3
1000 0 2
** Coefficients in correlation for temperature dependence of component
** viscosity in the gas phase
*AVG 0.0E+0 0.0E+0
*BVG 0.0E+0 0.0E+0
**********************************************************************
** Relative permeabilities **
**********************************************************************
*ROCKFLUID
** 1st rock-type
*RPT 1
** Water-oil relative permeabilities
*SWT
** Sw Krw Krow Pcow (kPa)
0.200000 0.000000 1.000000 4.500000
0.246200 0.0003918 0.8589186 1.700000
0.292300 0.0026358 0.7280375 0.700000
0.338500 0.0080382 0.6074459 0.200000
0.384600 0.0177312 0.4972427 0.050000
0.430800 0.0327523 0.397538 0.044000
0.476900 0.0540742 0.3084565 0.039000
0.523100 0.0826217 0.2301415 0.033000
0.569200 0.1192811 0.1627611 0.028000
0.615400 0.1649078 0.1065177 0.022000
0.661500 0.2203303 0.0616649 0.017000
0.707700 0.2863546 0.0285407 0.011000
0.753800 0.3637665 0.0076473 0.006000
0.800000 0.4533342 0.000000 0.000000
0.850000 0.5649555 0.000000 0.000000
0.900000 0.6926632 0.000000 0.000000
0.950000 0.837377 0.000000 0.000000
1.000000 1.000000 0.000000 0.000000
** Liquid-gas relative permeabilities
*SLT
** Sl Krg Krog Pcog
0.200000 1.000000 0.000000 13.500000
0.257700 0.802425 0.000724 5.100000
0.315400 0.631663 0.004869 2.100000
0.373100 0.486022 0.014848 0.600000
0.430800 0.363766 0.032752 0.150000
0.488500 0.263120 0.060498 0.138000
0.546200 0.182253 0.099883 0.125000
0.603800 0.119281 0.152615 0.113000
0.661500 0.072248 0.220330 0.100000
0.719200 0.039113 0.304610 0.088000
0.776900 0.017731 0.406983 0.075000
0.834600 0.005814 0.528940 0.063000
0.892300 0.000864 0.671932 0.050000
0.950000 0.000000 0.837377 0.038000
0.962500 0.000000 0.876319 0.025000
0.975000 0.000000 0.916394 0.013000
0.987500 0.000000 0.957616 0.000000
1.000000 0.000000 1.000000 0.000000
** Grid of rocktypes
KRTYPE CON 1.
**********************************************************************
** Initial conditions **
**********************************************************************
*INITIAL
** Use of vertical gradient to compute initial pressure
*VERTICAL *ON
*INITREGION 1
** Reference depth, pressure at reference depth (kPa)
*REFDEPTH 300.
*REFPRES 3000.
** Initial water/oil saturations
SW CON 0.3
SO CON 0.7
** Initial temperature (°C)
TEMP CON 127.
** Initial composition of each phase
MFRAC_GAS 'WATER' CON 1.
MFRAC_OIL 'BITUMEN' CON 1.
MFRAC_WAT 'WATER' CON 1.
**********************************************************************
** Numerical parameters **
**********************************************************************
*NUMERICAL
** Maximum timestep (in days)
*DTMAX 1
** Maximum number of Newton iterations
*NEWTONCYC 30
*ITERMAX 30
*PRECC 1.0e-4
** Use of adaptive-implicit resolution
*AIM *STAB *BACK 20
**********************************************************************
** Well management **
**********************************************************************
RUN
** Project starts on 01/01/2001
DATE 2001 01 01.
** Maximum timestep each time a well is open
DTWELL 0.01
** For SAGD startup: heat source temperature and location
TMPSET IJK
1:1 65:65 55:55 127.
1:1 65:65 45:45 250.
** For SAGD startup: heat source coefficient and location
UHTR IJK
1:1 65:65 55:55 0
1:1 65:65 45:45 0
** Definition of the steam injector
WELL 1 'Injector S1'
INJECTOR UNWEIGHT 'Injector S1'
TINJW 250.
QUAL 0.95
INCOMP WATER 1.0 0.0
OPERATE MAX BHP 4000. CONT REPEAT
**OPERATE MAX STW 200. CONT REPEAT
GEOMETRY I 0.11 0.249 1. 0.
PERF GEO 'Injector S1'
1 65 45 1.0
** Definition of the oil producer
WELL 2 'Producer P1'
PRODUCER 'Producer P1'
OPERATE MIN BHP 1000. CONT
**OPERATE MAX STEAM 50. CONT REPEAT
GEOMETRY I 0.11 0.249 1. 0.
PERF GEO 'Producer P1'
1 65 55 1.0
OPEN 'Injector S1'
OPEN 'Producer P1'
TIME 1 TIME 10 TIME 20 TIME 30 TIME 40 TIME 50 TIME 70 TIME 90 TIME 120
TIME 150 TIME 160 TIME 170 TIME 180 TIME 210 TIME 220 TIME 232
STOP
***************************** TERMINATE SIMULATION *****************************