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removed dissolved gas and vapporized oil from RESV injection rates

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This commit is contained in:
Tor Harald Sandve 2021-06-08 15:29:15 +02:00
parent 8ad44d046d
commit 28a567550b
7 changed files with 61 additions and 7 deletions
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4
opm/simulators/wells/BlackoilWellModel.hpp
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@ -373,6 +373,10 @@ namespace Opm {
const int pvtreg,
std::vector<double>& resv_coeff) override;
void calcInjRates(const int fipnum,
const int pvtreg,
std::vector<double>& resv_coeff) override;
void computeWellTemperature();
private:

10
opm/simulators/wells/BlackoilWellModelGeneric.cpp
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@ -768,15 +768,15 @@ checkGroupHigherConstraints(const Group& group,
->first;
}
std::vector<double> resv_coeff(phase_usage_.num_phases, 0.0);
calcRates(fipnum, pvtreg, resv_coeff);
std::vector<double> rates(phase_usage_.num_phases, 0.0);
const bool skip = switched_groups.count(group.name()) || group.name() == "FIELD";
if (!skip && group.isInjectionGroup()) {
// Obtain rates for group.
std::vector<double> resv_coeff_inj(phase_usage_.num_phases, 0.0);
calcInjRates(fipnum, pvtreg, resv_coeff_inj);
for (int phasePos = 0; phasePos < phase_usage_.num_phases; ++phasePos) {
const double local_current_rate = WellGroupHelpers::sumWellRates(group, schedule(), this->wellState(), reportStepIdx, phasePos, /* isInjector */ true);
// Sum over all processes
@ -802,7 +802,7 @@ checkGroupHigherConstraints(const Group& group,
group.getGroupEfficiencyFactor(),
schedule(),
summaryState_,
resv_coeff,
resv_coeff_inj,
deferred_logger);
if (changed.first) {
switched_groups.insert(group.name());
@ -819,6 +819,8 @@ checkGroupHigherConstraints(const Group& group,
// Sum over all processes
rates[phasePos] = -comm_.sum(local_current_rate);
}
std::vector<double> resv_coeff(phase_usage_.num_phases, 0.0);
calcRates(fipnum, pvtreg, resv_coeff);
// Check higher up only if under individual (not FLD) control.
const Group::ProductionCMode& currentControl = this->groupState().production_control(group.name());
if (currentControl != Group::ProductionCMode::FLD && group.productionGroupControlAvailable()) {

3
opm/simulators/wells/BlackoilWellModelGeneric.hpp
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@ -253,6 +253,9 @@ protected:
virtual void calcRates(const int fipnum,
const int pvtreg,
std::vector<double>& resv_coeff) = 0;
virtual void calcInjRates(const int fipnum,
const int pvtreg,
std::vector<double>& resv_coeff) = 0;
data::GuideRateValue getGuideRateValues(const Group& group) const;
data::GuideRateValue getGuideRateValues(const Well& well) const;

10
opm/simulators/wells/BlackoilWellModel_impl.hpp
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@ -1497,6 +1497,16 @@ namespace Opm {
rateConverter_->calcCoeff(fipnum, pvtreg, resv_coeff);
}
template<typename TypeTag>
void
BlackoilWellModel<TypeTag>::
calcInjRates(const int fipnum,
const int pvtreg,
std::vector<double>& resv_coeff)
{
rateConverter_->calcInjCoeff(fipnum, pvtreg, resv_coeff);
}
template <typename TypeTag>
void

35
opm/simulators/wells/RateConverter.hpp
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@ -645,6 +645,41 @@ namespace Opm {
}
}
template <class Coeff>
void
calcInjCoeff(const RegionId r, const int pvtRegionIdx, Coeff& coeff) const
{
const auto& pu = phaseUsage_;
const auto& ra = attr_.attributes(r);
const double p = ra.pressure;
const double T = ra.temperature;
const double saltConcentration = ra.saltConcentration;
const int iw = Details::PhasePos::water(pu);
const int io = Details::PhasePos::oil (pu);
const int ig = Details::PhasePos::gas (pu);
std::fill(& coeff[0], & coeff[0] + phaseUsage_.num_phases, 0.0);
if (Details::PhaseUsed::water(pu)) {
// q[w]_r = q[w]_s / bw
const double bw = FluidSystem::waterPvt().inverseFormationVolumeFactor(pvtRegionIdx, T, p, saltConcentration);
coeff[iw] = 1.0 / bw;
}
if (Details::PhaseUsed::oil(pu)) {
const double bo = FluidSystem::oilPvt().inverseFormationVolumeFactor(pvtRegionIdx, T, p, 0.0);
coeff[io] += 1.0 / bo;
}
if (Details::PhaseUsed::gas(pu)) {
const double bg = FluidSystem::gasPvt().inverseFormationVolumeFactor(pvtRegionIdx, T, p, 0.0);
coeff[ig] += 1.0 / bg;
}
}
/**
* Converting surface volume rates to reservoir voidage rates

4
opm/simulators/wells/WellInterfaceEval.cpp
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@ -132,7 +132,7 @@ getGroupInjectionControl(const Group& group,
// Make conversion factors for RESV <-> surface rates.
std::vector<double> resv_coeff(pu.num_phases, 1.0);
baseif_.rateConverter().calcCoeff(0, baseif_.pvtRegionIdx(), resv_coeff); // FIPNUM region 0 here, should use FIPNUM from WELSPECS.
baseif_.rateConverter().calcInjCoeff(0, baseif_.pvtRegionIdx(), resv_coeff); // FIPNUM region 0 here, should use FIPNUM from WELSPECS.
double sales_target = 0;
if (schedule[baseif_.currentStep()].gconsale().has(group.name())) {
@ -406,7 +406,7 @@ assembleControlEqInj_(const WellState& well_state,
}
case Well::InjectorCMode::RESV: {
std::vector<double> convert_coeff(baseif_.numPhases(), 1.0);
baseif_.rateConverter().calcCoeff(/*fipreg*/ 0, baseif_.pvtRegionIdx(), convert_coeff);
baseif_.rateConverter().calcInjCoeff(/*fipreg*/ 0, baseif_.pvtRegionIdx(), convert_coeff);
double coeff = 1.0;

2
opm/simulators/wells/WellInterfaceFluidSystem.cpp
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@ -308,7 +308,7 @@ checkGroupConstraintsInj(const Group& group,
// Make conversion factors for RESV <-> surface rates.
std::vector<double> resv_coeff(phaseUsage().num_phases, 1.0);
rateConverter_.calcCoeff(0, pvtRegionIdx_, resv_coeff); // FIPNUM region 0 here, should use FIPNUM from WELSPECS.
rateConverter_.calcInjCoeff(0, pvtRegionIdx_, resv_coeff); // FIPNUM region 0 here, should use FIPNUM from WELSPECS.
// Call check for the well's injection phase.
return WellGroupHelpers::checkGroupConstraintsInj(name(),