Rock-Fluid Data view

The master table for the view contains a row for each rock-fluid region. It contains the following columns.

Name Name of the rock-fluid region.

Active Determines whether rock-fluid region is active. Inactive regions are not written to the deck.

Region ID ID of region used in the deck.

Important Make sure you undertake the following rules before assigning the Region ID. An error message is displayed if a rule is broken.

1. The Region ID must have a value greater than or equal to 1.

2. The active Region ID numbers must start with 1 and have values increasing by 1.

3. Active models must not have unique Region ID numbers.

The Parameters tab is used to set additional parameters for the rock-fluids, such as:

KROIL parameters Introduce sub keywords which indicate how Kro is evaluated.

JFUNC Activate the Leverett J Function option.

NONDARCY Use non-Darcy reservoir flow options. The available options are GEERTSMA, FGI, FG2, and GENERAL.

Non Darcy Forchheimer Weight Factor A weighting factor which controls how much the non-Darcy Forchheimer number is allowed to change over a timestep. The default is 1.00. Excellent results are obtained when a value of 0.50 is used. Values above 0.50 are not recommended.

Interfacial Tension Effects (SIGMA) In case of GEM™ simulation case, specify the value for the surface tension when two phases are present. After clicking into the field, click the ellipsis button () to open a dialog where you can specify additional parameters for the interfacial tension effect.

The JFUNC tab is used to set the parameters for the Leverett-J function applicable for all rock types, such as:

JFUNC Select the option you want to use the Leverett-J Function for. If you select BOTH then oil-water and oil-gas capillary pressure table entries and their corresponding endpoints are interpreted as J function for all rock types.

JF_PCLIMIT Check the adjacent checkbox if you want to specify the limits for capillary pressure computed from J-function and grid block properties. The entry fields below are available only when you activate this option.

PCOW_LIMIT Enter the upper limit for the oil-water capillary pressure.

PCOG_LIMIT Enter the lower limit for the oil-gas capillary pressure.

The Parameters tab is used to select the three phase relative permeability model, wettability option, and additional options for water-oil and liquid-gas relative permeability:

Middle Phase Relative Permeability Calculations

Three-phase model option Select the three-phase relative permeability modeling method from the drop down menu.

Wettability option Select from five wettability options - WATWET, OILWET, INTMED1, INTMED2 and INTMED3

Optional Keywords for Water-Oil Relative Permeability Table (SWT)

Interpolation type Indicate the type of interpolation that will be used for the SWT table intervals. Click on the ellipsis in the entry field to open the SWT settings dialog. Select Interpolation type as SMOOTHEND and then select the subkeyword from linear (LINEAR), quadratic (QUAD) or cubic (CUBIC) interpolation method.

PCGW Check the checkbox if you want to allow specifying gas-water capillary pressure values in the SWT table.

Optional Keywords for Water-Oil Relative Permeability Table (SLT)

NOSWC Liquid saturation does not contain connate water saturation Swc and is all oil.

Interpolation type Indicate the type of interpolation that will be used for the SWT table intervals. Click on the ellipsis in the entry field to open the SWT settings dialog. Select Interpolation type as SMOOTHEND and then select the subkeyword from linear (LINEAR), quadratic (QUAD) or cubic (CUBIC) interpolation method.

WATERGAS Check the checkbox if you want to allow specifying Kwrg, relative permeability to water in presence of gas.

The SWT tab is used to define a water-oil relative permeability table.

Sw Water saturation.

Krw Relative permeability to water at the given water saturation.

Krow Relative permeability to oil of the given water saturation.

Pcow Water-oil capillary pressure on drainage curve.

Pcowi Water-oil capillary pressure on the imbibition curve.

Sorm Irreducible oil saturation due to water blocking at the given water saturation.

The SGT tab is used to define a liquid-gas relative permeability table dependent on gas saturation. SGT controls the use of a wide variety of relative permeability regression and optimization functions.

Sg Gas saturation.

Krg Relative permeability to gas.

Krog Relative permeability to oil.

Pcog Gas-oil capillary pressure.

Pcogi Imbibition Gas-Oil capillary pressure

The SLT tab is used to define a liquid-gas relative permeability table dependent on liquid saturation. SLT controls the use of a wide variety of relative permeability regression and optimization functions.

Sl Total liquidation saturation.

Krg Relative permeability to gas.

Krog Relative permeability to oil.

Pcog Gas-Oil capillary pressure.

Pcogi Imbibition Gas-Oil capillary pressure.

When data is input into the NONDARCY tab, this signals the use of the non-Darcy reservoir flow option. The table is used to specify the phase and associated factors for non-Darcy flow.

Phase Specify the phase for the reservoir.

Alpha Specify the alpha value for the phase.

N1 Specify the first coefficient for the phase.

N2 Specify the second coefficient for the phase.

Forch Specify the maximum Forchheimer number for the phase.

The GEM™ simulator accepts adsorption data for each adsorbing component using the table in this tab. In the simulation this data is used to predict multicomponent adsorption. See your CMG and GEM™ simulator installation for details on the mixing rule used to predict adsorption.

Active A checked box indicates that the component will be considered in the simulation.

Component Name The component for which the adsorption data is being specified.

Binary Component Indicates to the simulator that exactly two adsorbing components are present.

ADSORBTMAX The maximum number of moles of adsorbed component per unit mass of rock.

Mole Fraction Provide the mole fraction for the component.