From b559955c0083debc70a5d9c708e24ff2f5c88184 Mon Sep 17 00:00:00 2001 From: =?UTF-8?q?Atgeirr=20Fl=C3=B8=20Rasmussen?= Date: Wed, 14 Feb 2018 11:10:03 +0100 Subject: [PATCH] Add case with no wells for automated testing. --- spe1/SPE1CASE2_NOWELLS.DATA | 327 ++++++++++++++++++++++++++++++++++++ 1 file changed, 327 insertions(+) create mode 100644 spe1/SPE1CASE2_NOWELLS.DATA diff --git a/spe1/SPE1CASE2_NOWELLS.DATA b/spe1/SPE1CASE2_NOWELLS.DATA new file mode 100644 index 0000000..5c4bbf8 --- /dev/null +++ b/spe1/SPE1CASE2_NOWELLS.DATA @@ -0,0 +1,327 @@ +-- 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 +/ + + +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 / +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 / + +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 / + +SUMMARY +-- ------------------------------------------------------------------------- + + +-- 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 / +/ + + +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 + + +TSTEP +--Advance the simulater once a month for five months +31 28 31 30 31 +/ + +END