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black oil fluid system: correct a few method descriptions and names

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This commit is contained in:
Andreas Lauser 2015-01-26 12:56:53 +01:00
parent d074070e11
commit ea3c68694b
1 changed files with 50 additions and 40 deletions
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90
opm/material/fluidsystems/BlackOilFluidSystem.hpp
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@ -128,15 +128,14 @@ public:
/*!
* \brief Begin the initialization of the black oil fluid system.
*
* After calling this method the reference densities, all formation
* and volume factors, the oil bubble pressure, all viscosities
* and the water compressibility must be set. Before the fluid
* system can be used, initEnd() must be called to finalize the
* initialization.
* After calling this method the reference densities, all dissolution and formation
* volume factors, the oil bubble pressure, all viscosities and the water
* compressibility must be set. Before the fluid system can be used, initEnd() must
* be called to finalize the initialization.
*/
static void initBegin()
{
setWaterReferenceFormationFactor(1.0);
setWaterReferenceFormationVolumeFactor(1.0);
setWaterViscosibility(0.0);
setWaterReferencePressure(surfacePressure);
}
@ -165,7 +164,7 @@ public:
saturatedTable->getPressureColumn(),
saturatedTable->getGasSolubilityColumn());
// extract the table for the oil formation factor
// extract the table for the gas dissolution and the oil formation volume factors
for (int outerIdx = 0; outerIdx < static_cast<int>(saturatedTable->numRows()); ++ outerIdx) {
Scalar Rs = saturatedTable->getGasSolubilityColumn()[outerIdx];
@ -215,8 +214,8 @@ public:
// extend the current table using the master table. this is done by assuming
// that the current table exhibits the same ratios of the oil formation
// factors and viscosities for identical pressure rations as in the master
// table.
// volume factors and viscosities for identical pressure rations as in the
// master table.
const auto masterTable = pvtoTable.getInnerTable(masterTableIdx);
const auto curTable = pvtoTable.getInnerTable(xIdx);
for (int newRowIdx = 1;
@ -261,7 +260,7 @@ public:
auto pvtwRecord = pvtwKeyword->getRecord(regionIdx);
waterReferencePressure_[regionIdx] =
pvtwRecord->getItem("P_REF")->getSIDouble(0);
waterReferenceFormationFactor_[regionIdx] =
waterReferenceFormationVolumeFactor_[regionIdx] =
pvtwRecord->getItem("WATER_VOL_FACTOR")->getSIDouble(0);
waterCompressibility_[regionIdx] =
pvtwRecord->getItem("WATER_COMPRESSIBILITY")->getSIDouble(0);
@ -335,9 +334,11 @@ public:
/*!
* \brief Initialize the function for the oil formation volume factor
*
* The oil density/volume factor is a function of (p_o, X_o^G), but this method here
* only requires the volume factor of gas-saturated oil (which only depends on
* pressure) while the dependence on the gas mass fraction is estimated...
* The oil formation volume factor \f$B_o\f$ is a function of \f$(p_o, X_o^G)\f$ and
* represents the partial density of the oil component in the oil phase at a given
* pressure. This method only requires the volume factor of gas-saturated oil (which
* only depends on pressure) while the dependence on the gas mass fraction is
* guesstimated...
*/
static void setSaturatedOilFormationVolumeFactor(const SamplingPoints &samplePoints,
int regionIdx=0)
@ -391,7 +392,14 @@ public:
/*!
* \brief Initialize the spline for the oil formation volume factor
*
* This is a function of (Rs, po)...
* The oil formation volume factor \f$B_o\f$ is a function of \f$(p_o, X_o^G)\f$ and
* represents the partial density of the oil component in the oil phase at a given
* pressure.
*
* This method sets \f$1/B_o(R_s, p_o)\f$. Note that instead of the mass fraction of
* the gas component in the oil phase, this function depends on the gas dissolution
* factor. Also note, that the order of the arguments needs to be \f$(R_s, p_o)\f$
* and not the other way around.
*/
static void setInverseOilFormationVolumeFactor(const TabulatedTwoDFunction &invBo, int regionIdx=0)
{
@ -401,9 +409,9 @@ public:
}
/*!
* \brief Initialize the spline for the viscosity of gas-saturated oil.
* \brief Initialize the spline for the viscosity of the oil phase.
*
* This is a function of (Rs, po)...
* This is a function of \f$(R_s, p_o)\f$...
*/
static void setOilViscosity(const TabulatedTwoDFunction &muo, int regionIdx=0)
{
@ -413,11 +421,11 @@ public:
}
/*!
* \brief Initialize the oil viscosity
* \brief Initialize the phase viscosity for gas saturated oil
*
* The oil viscosity is a function of (p_o, X_o^G), but this method here only requires
* the viscosity of gas-saturated oil (which only depends on pressure) while the
* dependence on the gas mass fraction is assumed to be zero...
* The oil viscosity is a function of \f$(p_o, X_o^G)\f$, but this method only
* requires the viscosity of gas-saturated oil (which only depends on pressure) while
* there is assumed to be no dependence on the gas mass fraction...
*/
static void setSaturatedOilViscosity(const SamplingPoints &samplePoints, int regionIdx=0)
{
@ -456,7 +464,7 @@ public:
/*!
* \brief Initialize the function for the formation volume factor of dry gas
*
* \param samplePoints A container of (x,y) values
* \param samplePoints A container of \f$(p_g, B_g)\f$ values
*/
static void setGasFormationVolumeFactor(const SamplingPoints &samplePoints, int regionIdx=0)
{
@ -475,7 +483,7 @@ public:
/*!
* \brief Initialize the function for the viscosity of dry gas
*
* \param samplePoints A container of (x,y) values
* \param samplePoints A container of \f$(p_g, \mu_g)\f$ values
*/
static void setGasViscosity(const SamplingPoints &samplePoints, int regionIdx=0)
{
@ -497,17 +505,17 @@ public:
/*!
* \brief Set the water reference formation volume factor [-]
*/
static void setWaterReferenceFormationFactor(Scalar BwRef, int regionIdx=0)
static void setWaterReferenceFormationVolumeFactor(Scalar BwRef, int regionIdx=0)
{
resizeArrays_(regionIdx);
waterReferenceFormationFactor_[regionIdx] = BwRef;
waterReferenceFormationVolumeFactor_[regionIdx] = BwRef;
}
/*!
* \brief Set the water viscosity [Pa s]
* \brief Set the water reference viscosity [Pa s]
*/
static void setWaterViscosity(Scalar muWater, int regionIdx=0)
static void setWaterReferenceViscosity(Scalar muWater, int regionIdx=0)
{
resizeArrays_(regionIdx);
@ -543,7 +551,7 @@ public:
int numRegions = oilMu_.size();
for (int regionIdx = 0; regionIdx < numRegions; ++ regionIdx) {
// calculate the table which stores the inverse of the product of the oil
// formation factor and the oil viscosity
// formation volume factor and the oil viscosity
const auto& oilMu = oilMu_[regionIdx];
const auto& invOilB = inverseOilB_[regionIdx];
assert(oilMu.numX() == invOilB.numX());
@ -564,7 +572,7 @@ public:
}
// calculate the table which stores the inverse of the product of the gas
// formation factor and the gas viscosity
// formation volume factor and the gas viscosity
const auto& gasMu = gasMu_[regionIdx];
const auto& invGasB = inverseGasB_[regionIdx];
assert(gasMu.numSamples() == invGasB.numSamples());
@ -764,14 +772,14 @@ public:
Scalar pRef = waterReferencePressure_[regionIdx];
Scalar X = waterCompressibility_[regionIdx]*(pressure - pRef);
Scalar BwRef = waterReferenceFormationFactor_[regionIdx];
Scalar BwRef = waterReferenceFormationVolumeFactor_[regionIdx];
// TODO (?): consider the salt concentration of the brine
return BwRef/(1 + X*(1 + X/2));
}
/*!
* \brief Returns the gas formation factor \f$R_s\f$ for a given pressure
* \brief Returns the gas dissolution factor \f$R_s\f$ for a given pressure
*
* \param pressure The pressure of interest [Pa]
*/
@ -886,8 +894,8 @@ public:
Scalar rho_gRef = referenceDensity(gasPhaseIdx, regionIdx);
// calculate the mass of the gas component [kg/m^3] in the oil phase. This is
// equivalent to the gas formation factor [m^3/m^3] at current pressure times the
// gas density [kg/m^3] at standard pressure
// equivalent to the gas dissolution factor [m^3/m^3] at current pressure times
// the gas density [kg/m^3] at standard pressure
Scalar rho_oG = gasDissolutionFactor(pressure, regionIdx) * rho_gRef;
// we now have the total density of saturated oil and the partial density of the
@ -927,6 +935,9 @@ public:
/*!
* \brief Return the normalized formation volume factor of (potentially)
* under-saturated oil.
*
* This is the version of the method which takes the gas dissolution factor instead
* of the gas mass fraction in oil as an argument.
*/
static Scalar oilFormationVolumeFactorRs(Scalar oilPressure, Scalar Rs, int regionIdx=0)
{
@ -945,10 +956,9 @@ public:
Scalar Bo = oilFormationVolumeFactor(oilPressure, XoG, regionIdx);
Scalar rhoo = rhooRef/Bo;
// for some reason, the gas concentration is not considered in the oil formation
// volume factor. WTF? While I have no idea why this should be there, it is
// analogous to what's done in opm-autodiff which seems to be in agreement what
// the commercial simulator does...
// the oil formation volume factor just represents the partial density of the oil
// component in the oil phase. to get the total density of the phase, we have to
// add the partial density of the gas component.
Scalar Rs = XoG/(1 - XoG) * rhooRef/rhogRef;
rhoo += rhogRef*Rs/Bo;
@ -1005,7 +1015,7 @@ private:
gasDissolutionFactor_.resize(numRegions);
saturationPressureSpline_.resize(numRegions);
waterReferencePressure_.resize(numRegions);
waterReferenceFormationFactor_.resize(numRegions);
waterReferenceFormationVolumeFactor_.resize(numRegions);
waterCompressibility_.resize(numRegions);
waterViscosity__.resize(numRegions);
waterViscosibility_.resize(numRegions);
@ -1060,7 +1070,7 @@ private:
// Eclipse calculates the viscosity in a weird way: it
// calcultes the product of B_w and mu_w and then divides the
// result by B_w...
Scalar BwMuwRef = waterViscosity__[regionIdx]*waterReferenceFormationFactor_[regionIdx];
Scalar BwMuwRef = waterViscosity__[regionIdx]*waterReferenceFormationVolumeFactor_[regionIdx];
Scalar Bw = waterFormationVolumeFactor(pressure, regionIdx);
Scalar pRef = waterReferencePressure_[regionIdx];
@ -1081,7 +1091,7 @@ private:
static std::vector<TabulatedOneDFunction> inverseGasBMu_;
static std::vector<Scalar> waterReferencePressure_;
static std::vector<Scalar> waterReferenceFormationFactor_;
static std::vector<Scalar> waterReferenceFormationVolumeFactor_;
static std::vector<Scalar> waterCompressibility_;
static std::vector<Scalar> waterViscosity__;
static std::vector<Scalar> waterViscosibility_;
@ -1136,7 +1146,7 @@ BlackOil<Scalar>::waterReferencePressure_;
template <class Scalar>
std::vector<Scalar>
BlackOil<Scalar>::waterReferenceFormationFactor_;
BlackOil<Scalar>::waterReferenceFormationVolumeFactor_;
template <class Scalar>
std::vector<Scalar>