diff --git a/spe1_solvent/SPE1CASE2_CO2SOL.DATA b/spe1_solvent/SPE1CASE2_CO2SOL.DATA
new file mode 100644
index 000000000..d28beaefe
--- /dev/null
+++ b/spe1_solvent/SPE1CASE2_CO2SOL.DATA
@@ -0,0 +1,445 @@
+-- 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
+-- Copyright (C) 2023 Norce
+
+RUNSPEC
+-- -------------------------------------------------------------------------
+
+TITLE
+   SPE1 - CASE 2 - Case with SOLVENT and CO2SOL
+
+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
+DISGASW
+SOLVENT
+CO2SOL
+
+-- 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 3 1 2 /
+
+UNIFIN
+UNIFOUT
+
+GRID
+-- -------------------------------------------------------------------------
+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
+-- -------------------------------------------------------------------------
+
+ROCK
+-- Item 1: reference pressure (psia)
+-- Item 2: rock compressibility (psi^{-1})
+
+-- Using values from table 1 in Odeh:
+	14.7 3E-6 /
+
+SWFN
+-- 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: water-oil capillary pressure (psi) 
+
+0.12	0    		 	0
+0.18	4.64876033057851E-008	0
+0.24	0.000000186		0
+0.3	4.18388429752066E-007	0
+0.36	7.43801652892562E-007	0
+0.42	1.16219008264463E-006	0
+0.48	1.67355371900826E-006	0
+0.54	2.27789256198347E-006	0
+0.6	2.97520661157025E-006	0
+0.66	3.7654958677686E-006	0
+0.72	4.64876033057851E-006	0
+0.78	0.000005625		0
+0.84	6.69421487603306E-006	0
+0.91	8.05914256198347E-006	0
+1	0.00001			0 /
+
+
+SGFN
+-- Column 1: gas saturation
+-- Column 2: gas relative permeability
+-- Column 3: oil-gas capillary pressure (psi)
+-- 	     - stated to be zero in Odeh's paper
+
+-- Values in column 1-2 are taken from table 3 in Odeh's paper:
+0	0	0
+0.001	0	0
+0.02	0	0
+0.05	0.005	0
+0.12	0.025	0
+0.2	0.075	0
+0.25	0.125	0
+0.3	0.190	0
+0.4	0.410	0
+0.45	0.60	0
+0.5	0.72	0
+0.6	0.87	0
+0.7	0.94	0
+0.85	0.98	0 
+0.88	0.984	0 /
+--1.00	1.0	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)
+
+-- Column 1: oil saturation
+-- Column 2: oil relative permeability when oil, gas and connate water are present
+-- Column 3: oil relative permeability when only oil and water are present
+--  - we will use the same values for column 2 and column 3 as given
+--  in Odeh's paper. This is not really correct, but since only the first 
+--  two values are of importance, this does not really matter
+
+SOF3
+--  SOIL     KROW     KROG
+    0        0        0
+    0.03     0        0	
+    0.18     0        0
+    0.28     0.0001   0.0001
+    0.38     0.001    0.001
+    0.43     0.01     0.01
+    0.48     0.021    0.021
+    0.58     0.09     0.09
+    0.63     0.2      0.2
+    0.68     0.35     0.35
+    0.76     0.7      0.7
+    0.83     0.98     0.98
+    0.86     0.997    0.997
+    0.879    1        1
+    0.88     1        1    /
+
+SSFN 
+ 0.0 0.0 0.0
+ 0.5 0.4 0.8 
+ 1.0 1.0 1.0
+/
+
+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.
+/
+	
+-- 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
+-- -------------------------------------------------------------------------	 
+
+-- 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 /
+/
+
+BOKR
+1 1 1/
+/
+
+BWKR
+1 1 1/
+/
+
+-- 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' 'SSOL' 'SWAT' 'SOIL' 'WELLS' 'KRN' 'KRG' 'KRO' 'KRW'/
+
+RPTRST
+	'BASIC=1' /
+
+
+-- If no resolution (i.e. case 1), the two following lines must be added:
+--DRSDT
+-- 0 /
+-- 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' 'BHP' 1* 4* 4000 /
+/
+-- 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'	10000 1* 9014 /
+/
+
+WSOLVENT
+'INJ'  0.0/
+/
+
+TSTEP
+--Advance the simulater once a month for ONE years: 
+31 28 31 30 31 30 31 31 30 31 30 31 /
+
+END
diff --git a/spe1_solvent/SPE1CASE2_H2SOL.DATA b/spe1_solvent/SPE1CASE2_H2SOL.DATA
new file mode 100644
index 000000000..0a2825777
--- /dev/null
+++ b/spe1_solvent/SPE1CASE2_H2SOL.DATA
@@ -0,0 +1,445 @@
+-- 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
+-- Copyright (C) 2023 Norce
+
+RUNSPEC
+-- -------------------------------------------------------------------------
+
+TITLE
+   SPE1 - CASE 2 - Case with SOLVENT and H2SOL
+
+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
+DISGASW
+SOLVENT
+H2SOL
+
+-- 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 3 1 2 /
+
+UNIFIN
+UNIFOUT
+
+GRID
+-- -------------------------------------------------------------------------
+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
+-- -------------------------------------------------------------------------
+
+ROCK
+-- Item 1: reference pressure (psia)
+-- Item 2: rock compressibility (psi^{-1})
+
+-- Using values from table 1 in Odeh:
+	14.7 3E-6 /
+
+SWFN
+-- 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: water-oil capillary pressure (psi) 
+
+0.12	0    		 	0
+0.18	4.64876033057851E-008	0
+0.24	0.000000186		0
+0.3	4.18388429752066E-007	0
+0.36	7.43801652892562E-007	0
+0.42	1.16219008264463E-006	0
+0.48	1.67355371900826E-006	0
+0.54	2.27789256198347E-006	0
+0.6	2.97520661157025E-006	0
+0.66	3.7654958677686E-006	0
+0.72	4.64876033057851E-006	0
+0.78	0.000005625		0
+0.84	6.69421487603306E-006	0
+0.91	8.05914256198347E-006	0
+1	0.00001			0 /
+
+
+SGFN
+-- Column 1: gas saturation
+-- Column 2: gas relative permeability
+-- Column 3: oil-gas capillary pressure (psi)
+-- 	     - stated to be zero in Odeh's paper
+
+-- Values in column 1-2 are taken from table 3 in Odeh's paper:
+0	0	0
+0.001	0	0
+0.02	0	0
+0.05	0.005	0
+0.12	0.025	0
+0.2	0.075	0
+0.25	0.125	0
+0.3	0.190	0
+0.4	0.410	0
+0.45	0.60	0
+0.5	0.72	0
+0.6	0.87	0
+0.7	0.94	0
+0.85	0.98	0 
+0.88	0.984	0 /
+--1.00	1.0	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)
+
+-- Column 1: oil saturation
+-- Column 2: oil relative permeability when oil, gas and connate water are present
+-- Column 3: oil relative permeability when only oil and water are present
+--  - we will use the same values for column 2 and column 3 as given
+--  in Odeh's paper. This is not really correct, but since only the first 
+--  two values are of importance, this does not really matter
+
+SOF3
+--  SOIL     KROW     KROG
+    0        0        0
+    0.03     0        0	
+    0.18     0        0
+    0.28     0.0001   0.0001
+    0.38     0.001    0.001
+    0.43     0.01     0.01
+    0.48     0.021    0.021
+    0.58     0.09     0.09
+    0.63     0.2      0.2
+    0.68     0.35     0.35
+    0.76     0.7      0.7
+    0.83     0.98     0.98
+    0.86     0.997    0.997
+    0.879    1        1
+    0.88     1        1    /
+
+SSFN 
+ 0.0 0.0 0.0
+ 0.5 0.4 0.8 
+ 1.0 1.0 1.0
+/
+
+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.
+/
+	
+-- 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
+-- -------------------------------------------------------------------------	 
+
+-- 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 /
+/
+
+BOKR
+1 1 1/
+/
+
+BWKR
+1 1 1/
+/
+
+-- 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' 'SSOL' 'SWAT' 'SOIL' 'WELLS' 'KRN' 'KRG' 'KRO' 'KRW'/
+
+RPTRST
+	'BASIC=1' /
+
+
+-- If no resolution (i.e. case 1), the two following lines must be added:
+--DRSDT
+-- 0 /
+-- 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' 'BHP' 1* 4* 4000 /
+/
+-- 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'	10000 1* 9014 /
+/
+
+WSOLVENT
+'INJ'  0.0/
+/
+
+TSTEP
+--Advance the simulater once a month for ONE years: 
+31 28 31 30 31 30 31 31 30 31 30 31 /
+
+END