-- 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 -- 'Comparison of Solutions to a Three-Dimensional -- Black-Oil Reservoir Simulation Problem' by Aziz S. Odeh, -- Journal of Petroleum Technology, January 1981 --------------------------------------------------------------------------- ------------------------ SPE1 - CASE 2 ------------------------------------ --------------------------------------------------------------------------- RUNSPEC -- ------------------------------------------------------------------------- TITLE SPE1 - CASE 2 DIMENS 10 10 3 / -- The number of equilibration regions is inferred from the EQLDIMS -- keyword. EQLDIMS / -- The number of PVTW tables is inferred from the TABDIMS keyword; -- when no data is included in the keyword the default values are used. TABDIMS / -- request a black-oil simulation with the thermal option (not supported by E100!) THERMAL -- request the temperature option instead (NOT supported by OPM!) --TEMP BLACKOIL OIL GAS WATER DISGAS -- As seen from figure 4 in Odeh, GOR is increasing with time, -- which means that dissolved gas is present FIELD START 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 one as the wells are located at specific 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 1 1 2 / UNIFOUT GRID -- The INIT keyword is used to request an .INIT file. The .INIT file -- is written before the simulation actually starts, and contains grid -- properties and saturation tables as inferred from the input -- deck. There are no other keywords which can be used to configure -- exactly what is written to the .INIT file. INIT -- ------------------------------------------------------------------------- NOECHO DX -- There are in total 300 cells with length 1000ft in x-direction 300*1000 / DY -- There are in total 300 cells with length 1000ft in y-direction 300*1000 / DZ -- The layers are 20, 30 and 50 ft thick, in each layer there are 100 cells 100*20 100*30 100*50 / TOPS -- The depth of the top of each grid block 100*8325 / PORO -- Constant porosity of 0.3 throughout all 300 grid cells 300*0.3 / PERMX -- The layers have perm. 500mD, 50mD and 200mD, respectively. 100*500 100*50 100*200 / PERMY -- Equal to PERMX 100*500 100*50 100*200 / PERMZ -- Cannot find perm. in z-direction in Odeh's paper -- For the time being, we will assume PERMZ equal to PERMX and PERMY: 100*500 100*50 100*200 / -- volumetric heat capacity of rock for each cell (not supported by E100!) -- Note: This keyword is incompatible with SPECROCK --HEATCR -- 300*32.0 / -- temperature dependence of the volumetric heat capacity of rock for each cell (not supported by E100!) -- Note: This keyword is incompatible with SPECROCK --HEATCRT -- 300*0.05 / -- total thermal conductivty THCONR 300*30.0 / -- btu/(day / ft / °F) -- gas saturation dependence of total thermal conductivty (not supported by E100!) --THCONSF -- 300*0.1 / ECHO PROPS -- ------------------------------------------------------------------------- PVTW -- Item 1: pressure reference (psia) -- Item 2: water FVF (rb per bbl or rb per stb) -- Item 3: water compressibility (psi^{-1}) -- Item 4: water viscosity (cp) -- Item 5: water 'viscosibility' (psi^{-1}) -- Using values from Norne: -- In METRIC units: -- 277.0 1.038 4.67E-5 0.318 0.0 / -- In FIELD units: 4017.55 1.038 3.22E-6 0.318 0.0 / ROCK -- Item 1: reference pressure (psia) -- Item 2: rock compressibility (psi^{-1}) -- Using values from table 1 in Odeh: 14.7 3E-6 / SPECHEAT -- Column 1: Temperature [deg F] -- Column 2: Specific heat capacity of oil [btu / (lb * degF)] -- Column 3: Specific heat capacity of water [btu / (lb * degF)] -- Column 4: Specific heat capacity of gas [btu / (lb * degF)] 0.0 0.5 1.0 0.25 300.0 0.5 1.0 0.25 / SPECROCK -- Column 1: Temperature [deg F] -- Column 2: Volumetric heat capacity of rock [btu / (ft^3 * degF)] 0.0 33. 300.0 32. / SWOF -- Column 1: water saturation -- - this has been set to (almost) equally spaced values from 0.12 to 1 -- Column 2: water relative permeability -- - generated from the Corey-type approx. formula -- the coeffisient is set to 10e-5, S_{orw}=0 and S_{wi}=0.12 -- Column 3: oil relative permeability when only oil and water are present -- - we will use the same values as in column 3 in SGOF. -- This is not really correct, but since only the first -- two values are of importance, this does not really matter -- Column 4: corresponding water-oil capillary pressure (psi) 0.12 0 1 0 0.18 4.64876033057851E-008 1 0 0.24 0.000000186 0.997 0 0.3 4.18388429752066E-007 0.98 0 0.36 7.43801652892562E-007 0.7 0 0.42 1.16219008264463E-006 0.35 0 0.48 1.67355371900826E-006 0.2 0 0.54 2.27789256198347E-006 0.09 0 0.6 2.97520661157025E-006 0.021 0 0.66 3.7654958677686E-006 0.01 0 0.72 4.64876033057851E-006 0.001 0 0.78 0.000005625 0.0001 0 0.84 6.69421487603306E-006 0 0 0.91 8.05914256198347E-006 0 0 1 0.00001 0 0 / SGOF -- Column 1: gas saturation -- Column 2: gas relative permeability -- Column 3: oil relative permeability when oil, gas and connate water are present -- Column 4: oil-gas capillary pressure (psi) -- - stated to be zero in Odeh's paper -- Values in column 1-3 are taken from table 3 in Odeh's paper: 0 0 1 0 0.001 0 1 0 0.02 0 0.997 0 0.05 0.005 0.980 0 0.12 0.025 0.700 0 0.2 0.075 0.350 0 0.25 0.125 0.200 0 0.3 0.190 0.090 0 0.4 0.410 0.021 0 0.45 0.60 0.010 0 0.5 0.72 0.001 0 0.6 0.87 0.0001 0 0.7 0.94 0.000 0 0.85 0.98 0.000 0 0.88 0.984 0.000 0 / --1.00 1.0 0.000 0 / -- Warning from Eclipse: first sat. value in SWOF + last sat. value in SGOF -- must not be greater than 1, but Eclipse still runs -- Flow needs the sum to be excactly 1 so I added a row with gas sat. = 0.88 -- The corresponding krg value was estimated by assuming linear rel. between -- gas sat. and krw. between gas sat. 0.85 and 1.00 (the last two values given) DENSITY -- Density (lb per ft³) at surface cond. of -- oil, water and gas, respectively (in that order) -- Using values from Norne: -- In METRIC units: -- 859.5 1033.0 0.854 / -- In FIELD units: 53.66 64.49 0.0533 / PVDG -- Column 1: gas phase pressure (psia) -- Column 2: gas formation volume factor (rb per Mscf) -- - in Odeh's paper the units are said to be given in rb per bbl, -- but this is assumed to be a mistake: FVF-values in Odeh's paper -- are given in rb per scf, not rb per bbl. This will be in -- agreement with conventions -- Column 3: gas viscosity (cP) -- Using values from lower right table in Odeh's table 2: 14.700 166.666 0.008000 264.70 12.0930 0.009600 514.70 6.27400 0.011200 1014.7 3.19700 0.014000 2014.7 1.61400 0.018900 2514.7 1.29400 0.020800 3014.7 1.08000 0.022800 4014.7 0.81100 0.026800 5014.7 0.64900 0.030900 9014.7 0.38600 0.047000 / PVTO -- Column 1: dissolved gas-oil ratio (Mscf per stb) -- Column 2: bubble point pressure (psia) -- Column 3: oil FVF for saturated oil (rb per stb) -- Column 4: oil viscosity for saturated oil (cP) -- Use values from top left table in Odeh's table 2: 0.0010 14.7 1.0620 1.0400 / 0.0905 264.7 1.1500 0.9750 / 0.1800 514.7 1.2070 0.9100 / 0.3710 1014.7 1.2950 0.8300 / 0.6360 2014.7 1.4350 0.6950 / 0.7750 2514.7 1.5000 0.6410 / 0.9300 3014.7 1.5650 0.5940 / 1.2700 4014.7 1.6950 0.5100 9014.7 1.5790 0.7400 / 1.6180 5014.7 1.8270 0.4490 9014.7 1.7370 0.6310 / -- It is required to enter data for undersaturated oil for the highest GOR -- (i.e. the last row) in the PVTO table. -- In order to fulfill this requirement, values for oil FVF and viscosity -- at 9014.7psia and GOR=1.618 for undersaturated oil have been approximated: -- It has been assumed that there is a linear relation between the GOR -- and the FVF when keeping the pressure constant at 9014.7psia. -- From Odeh we know that (at 9014.7psia) the FVF is 2.357 at GOR=2.984 -- for saturated oil and that the FVF is 1.579 at GOR=1.27 for undersaturated oil, -- so it is possible to use the assumption described above. -- An equivalent approximation for the viscosity has been used. / SOLUTION -- ------------------------------------------------------------------------- EQUIL -- Item 1: datum depth (ft) -- Item 2: pressure at datum depth (psia) -- - Odeh's table 1 says that initial reservoir pressure is -- 4800 psi at 8400ft, which explains choice of item 1 and 2 -- Item 3: depth of water-oil contact (ft) -- - chosen to be directly under the reservoir -- Item 4: oil-water capillary pressure at the water oil contact (psi) -- - given to be 0 in Odeh's paper -- Item 5: depth of gas-oil contact (ft) -- - chosen to be directly above the reservoir -- Item 6: gas-oil capillary pressure at gas-oil contact (psi) -- - given to be 0 in Odeh's paper -- Item 7: RSVD-table -- Item 8: RVVD-table -- Item 9: Set to 0 as this is the only value supported by OPM -- Item #: 1 2 3 4 5 6 7 8 9 8400 4800 8450 0 8300 0 1 0 0 / RSVD -- Dissolved GOR is initially constant with depth through the reservoir. -- The reason is that the initial reservoir pressure given is higher ---than the bubble point presssure of 4014.7psia, meaning that there is no -- free gas initially present. 8300 1.270 8450 1.270 / -- initial reservoir temperature (°F) RTEMPVD 8300 150 8450 200 / SUMMARY -- ------------------------------------------------------------------------- -- 1a) Oil rate vs time FOPR -- Field Oil Production Rate -- 1b) GOR vs time WGOR -- Well Gas-Oil Ratio 'PROD' / -- Using FGOR instead of WGOR:PROD results in the same graph FGOR -- 2a) Pressures of the cell where the injector and producer are located BPR 1 1 1 / 10 10 3 / / -- 2b) Gas saturation at grid points given in Odeh's paper BGSAT 1 1 1 / 1 1 2 / 1 1 3 / 10 1 1 / 10 1 2 / 10 1 3 / 10 10 1 / 10 10 2 / 10 10 3 / / -- 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 -- ------------------------------------------------------------------------- RPTSCHED 'PRES' 'SGAS' 'RS' 'WELLS' / RPTRST 'BASIC=1' / -- If no resolution (i.e. case 1), the two following lines must be added: --DRSDT -- 0 / -- Since this is Case 2, the two lines above have been commented out. -- if DRSDT is set to 0, GOR cannot rise and free gas does not -- dissolve in undersaturated oil -> constant bubble point pressure WELSPECS -- Item #: 1 2 3 4 5 6 'PROD' 'G1' 10 10 8400 'OIL' / 'INJ' 'G1' 1 1 8335 'GAS' / / -- Coordinates in item 3-4 are retrieved from Odeh's figure 1 and 2 -- Note that the depth at the midpoint of the well grid blocks -- has been used as reference depth for bottom hole pressure in item 5 COMPDAT -- Item #: 1 2 3 4 5 6 7 8 9 'PROD' 10 10 3 3 'OPEN' 1* 1* 0.5 / 'INJ' 1 1 1 1 'OPEN' 1* 1* 0.5 / / -- Coordinates in item 2-5 are retreived from Odeh's figure 1 and 2 -- Item 9 is the well bore internal diameter, -- the radius is given to be 0.25ft in Odeh's paper WCONPROD -- Item #:1 2 3 4 5 9 'PROD' 'OPEN' 'ORAT' 20000 4* 1000 / / -- It is stated in Odeh's paper that the maximum oil prod. rate -- is 20 000stb per day which explains the choice of value in item 4. -- The items > 4 are defaulted with the exception of item 9, -- the BHP lower limit, which is given to be 1000psia in Odeh's paper WCONINJE -- Item #:1 2 3 4 5 6 7 'INJ' 'GAS' 'OPEN' 'RATE' 100000 1* 9014 / / -- Stated in Odeh that gas inj. rate (item 5) is 100MMscf per day -- BHP upper limit (item 7) should not be exceeding the highest -- pressure in the PVT table=9014.7psia (default is 100 000psia) -- well injection temperature WTEMP 'INJ' 200 / -- 'PROD' 60 / / TSTEP --Advance the simulater once a month for TEN 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 31 28 31 30 31 30 31 31 30 31 30 31 / --Advance the simulator once a year for TEN years: --10*365 / END