mirror of
https://github.com/OPM/opm-simulators.git
synced 2024-12-23 16:00:01 -06:00
fabdfbafcb
since the unit code within opm-parser is now a drop-in replacement, this simplifies things and make them less error-prone. unfortunately, this requires quite a few PRs. (most are pretty trivial, though.)
410 lines
17 KiB
C++
410 lines
17 KiB
C++
/*
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Copyright 2012 SINTEF ICT, Applied Mathematics.
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This file is part of the Open Porous Media project (OPM).
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OPM is free software: you can redistribute it and/or modify
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it under the terms of the GNU General Public License as published by
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the Free Software Foundation, either version 3 of the License, or
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(at your option) any later version.
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OPM is distributed in the hope that it will be useful,
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but WITHOUT ANY WARRANTY; without even the implied warranty of
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MERCHANTABILITY or FITNESS FOR A PARTICULAR PURPOSE. See the
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GNU General Public License for more details.
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You should have received a copy of the GNU General Public License
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along with OPM. If not, see <http://www.gnu.org/licenses/>.
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*/
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#include "config.h"
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#include <opm/core/utility/miscUtilitiesBlackoil.hpp>
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#include <opm/core/grid.h>
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#include <opm/core/wells.h>
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#include <opm/core/linalg/blas_lapack.h>
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#include <opm/core/props/BlackoilPropertiesInterface.hpp>
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#include <opm/core/simulator/BlackoilState.hpp>
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#include <opm/core/simulator/WellState.hpp>
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#include <opm/common/ErrorMacros.hpp>
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#include <opm/parser/eclipse/Units/Units.hpp>
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#include <algorithm>
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#include <cmath>
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#include <functional>
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#include <limits>
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#include <iostream>
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#include <iterator>
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namespace Opm
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{
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/// @brief Computes injected and produced surface volumes of all phases.
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/// Note 1: assumes that only the first phase is injected.
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/// Note 2: assumes that transport has been done with an
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/// implicit method, i.e. that the current state
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/// gives the mobilities used for the preceding timestep.
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/// Note 3: Gives surface volume values, not reservoir volumes
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/// (as the incompressible version of the function does).
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/// Also, assumes that transport_src is given in surface volumes
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/// for injector terms!
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/// @param[in] props fluid and rock properties.
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/// @param[in] state state variables (pressure, sat, surfvol)
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/// @param[in] transport_src if < 0: total resv outflow, if > 0: first phase surfv inflow
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/// @param[in] dt timestep used
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/// @param[out] injected must point to a valid array with P elements,
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/// where P = s.size()/src.size().
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/// @param[out] produced must also point to a valid array with P elements.
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void computeInjectedProduced(const BlackoilPropertiesInterface& props,
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const BlackoilState& state,
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const std::vector<double>& transport_src,
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const double dt,
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double* injected,
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double* produced)
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{
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const int num_cells = transport_src.size();
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if (props.numCells() != num_cells) {
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OPM_THROW(std::runtime_error, "Size of transport_src vector does not match number of cells in props.");
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}
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const int np = props.numPhases();
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if (int(state.saturation().size()) != num_cells*np) {
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OPM_THROW(std::runtime_error, "Sizes of state vectors do not match number of cells.");
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}
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const std::vector<double>& press = state.pressure();
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const std::vector<double>& temp = state.temperature();
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const std::vector<double>& s = state.saturation();
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const std::vector<double>& z = state.surfacevol();
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std::fill(injected, injected + np, 0.0);
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std::fill(produced, produced + np, 0.0);
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std::vector<double> visc(np);
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std::vector<double> mob(np);
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std::vector<double> A(np*np);
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std::vector<double> prod_resv_phase(np);
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std::vector<double> prod_surfvol(np);
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for (int c = 0; c < num_cells; ++c) {
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if (transport_src[c] > 0.0) {
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// Inflowing transport source is a surface volume flux
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// for the first phase.
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injected[0] += transport_src[c]*dt;
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} else if (transport_src[c] < 0.0) {
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// Outflowing transport source is a total reservoir
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// volume flux.
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const double flux = -transport_src[c]*dt;
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const double* sat = &s[np*c];
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props.relperm(1, sat, &c, &mob[0], 0);
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props.viscosity(1, &press[c], &temp[c], &z[np*c], &c, &visc[0], 0);
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props.matrix(1, &press[c], &temp[c], &z[np*c], &c, &A[0], 0);
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double totmob = 0.0;
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for (int p = 0; p < np; ++p) {
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mob[p] /= visc[p];
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totmob += mob[p];
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}
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std::fill(prod_surfvol.begin(), prod_surfvol.end(), 0.0);
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for (int p = 0; p < np; ++p) {
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prod_resv_phase[p] = (mob[p]/totmob)*flux;
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for (int q = 0; q < np; ++q) {
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prod_surfvol[q] += prod_resv_phase[p]*A[q + np*p];
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}
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}
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for (int p = 0; p < np; ++p) {
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produced[p] += prod_surfvol[p];
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}
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}
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}
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}
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/// @brief Computes total mobility for a set of saturation values.
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/// @param[in] props rock and fluid properties
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/// @param[in] cells cells with which the saturation values are associated
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/// @param[in] p pressure (one value per cell)
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/// @param[in] temp temperature (one value per cell)
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/// @param[in] z surface-volume values (for all P phases)
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/// @param[in] s saturation values (for all phases)
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/// @param[out] totmob total mobilities.
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void computeTotalMobility(const Opm::BlackoilPropertiesInterface& props,
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const std::vector<int>& cells,
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const std::vector<double>& press,
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const std::vector<double>& temp,
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const std::vector<double>& z,
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const std::vector<double>& s,
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std::vector<double>& totmob)
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{
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std::vector<double> pmobc;
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computePhaseMobilities(props, cells, press, temp, z, s, pmobc);
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const std::size_t np = props.numPhases();
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const std::vector<int>::size_type nc = cells.size();
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totmob.clear();
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totmob.resize(nc, 0.0);
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for (std::vector<int>::size_type c = 0; c < nc; ++c) {
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for (std::size_t p = 0; p < np; ++p) {
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totmob[ c ] += pmobc[c*np + p];
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}
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}
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}
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/*
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/// @brief Computes total mobility and omega for a set of saturation values.
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/// @param[in] props rock and fluid properties
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/// @param[in] cells cells with which the saturation values are associated
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/// @param[in] p pressure (one value per cell)
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/// @param[in] z surface-volume values (for all P phases)
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/// @param[in] s saturation values (for all phases)
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/// @param[out] totmob total mobility
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/// @param[out] omega fractional-flow weighted fluid densities.
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void computeTotalMobilityOmega(const Opm::BlackoilPropertiesInterface& props,
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const std::vector<int>& cells,
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const std::vector<double>& p,
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const std::vector<double>& z,
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const std::vector<double>& s,
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std::vector<double>& totmob,
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std::vector<double>& omega)
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{
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std::vector<double> pmobc;
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computePhaseMobilities(props, cells, p, z, s, pmobc);
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const std::size_t np = props.numPhases();
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const std::vector<int>::size_type nc = cells.size();
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totmob.clear();
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totmob.resize(nc, 0.0);
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omega.clear();
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omega.resize(nc, 0.0);
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const double* rho = props.density();
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for (std::vector<int>::size_type c = 0; c < nc; ++c) {
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for (std::size_t p = 0; p < np; ++p) {
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totmob[ c ] += pmobc[c*np + p];
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omega [ c ] += pmobc[c*np + p] * rho[ p ];
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}
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omega[ c ] /= totmob[ c ];
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}
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}
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*/
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/// @brief Computes phase mobilities for a set of saturation values.
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/// @param[in] props rock and fluid properties
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/// @param[in] cells cells with which the saturation values are associated
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/// @param[in] p pressure (one value per cell)
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/// @param[in] T temperature (one value per cell)
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/// @param[in] z surface-volume values (for all P phases)
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/// @param[in] s saturation values (for all phases)
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/// @param[out] pmobc phase mobilities (for all phases).
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void computePhaseMobilities(const Opm::BlackoilPropertiesInterface& props,
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const std::vector<int>& cells,
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const std::vector<double>& p,
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const std::vector<double>& T,
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const std::vector<double>& z,
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const std::vector<double>& s,
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std::vector<double>& pmobc)
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{
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const int nc = props.numCells();
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const int np = props.numPhases();
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assert(int(s.size()) == nc * np);
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std::vector<double> mu(nc*np);
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props.viscosity(nc, &p[0], &T[0], &z[0], &cells[0], &mu[0], 0);
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pmobc.clear();
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pmobc.resize(nc*np, 0.0);
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double* dpmobc = 0;
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props.relperm(nc, &s[0], &cells[0],
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&pmobc[0], dpmobc);
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std::transform(pmobc.begin(), pmobc.end(),
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mu.begin(),
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pmobc.begin(),
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std::divides<double>());
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}
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/// Computes the fractional flow for each cell in the cells argument
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/// @param[in] props rock and fluid properties
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/// @param[in] cells cells with which the saturation values are associated
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/// @param[in] p pressure (one value per cell)
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/// @param[in] T temperature (one value per cell)
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/// @param[in] z surface-volume values (for all P phases)
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/// @param[in] s saturation values (for all phases)
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/// @param[out] fractional_flow the fractional flow for each phase for each cell.
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void computeFractionalFlow(const Opm::BlackoilPropertiesInterface& props,
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const std::vector<int>& cells,
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const std::vector<double>& p,
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const std::vector<double>& T,
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const std::vector<double>& z,
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const std::vector<double>& s,
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std::vector<double>& fractional_flows)
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{
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const int num_phases = props.numPhases();
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computePhaseMobilities(props, cells, p, T, z, s, fractional_flows);
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for (std::vector<int>::size_type i = 0; i < cells.size(); ++i) {
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double phase_sum = 0.0;
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for (int phase = 0; phase < num_phases; ++phase) {
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phase_sum += fractional_flows[i * num_phases + phase];
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}
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for (int phase = 0; phase < num_phases; ++phase) {
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fractional_flows[i * num_phases + phase] /= phase_sum;
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}
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}
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}
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/// Computes the surface volume densities from saturations by the formula
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/// z = A s
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/// for a number of data points, where z is the surface volume density,
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/// s is the saturation (both as column vectors) and A is the
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/// phase-to-component relation matrix.
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/// @param[in] n number of data points
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/// @param[in] np number of phases, must be 2 or 3
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/// @param[in] A array containing n square matrices of size num_phases^2,
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/// in Fortran ordering, typically the output of a call
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/// to the matrix() method of a BlackoilProperties* class.
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/// @param[in] saturation concatenated saturation values (for all P phases)
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/// @param[out] surfacevol concatenated surface-volume values (for all P phases)
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void computeSurfacevol(const int n,
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const int np,
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const double* A,
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const double* saturation,
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double* surfacevol)
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{
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// Note: since this is a simple matrix-vector product, it can
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// be done by a BLAS call, but then we have to reorder the A
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// matrix data.
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std::fill(surfacevol, surfacevol + n*np, 0.0);
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for (int i = 0; i < n; ++i) {
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for (int col = 0; col < np; ++col) {
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for (int row = 0; row < np; ++row) {
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surfacevol[i*np + row] += A[i*np*np + row + col*np] * saturation[i*np + col];
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}
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}
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}
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}
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/// @brief Computes saturation from surface volume
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void computeSaturation(const BlackoilPropertiesInterface& props,
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BlackoilState& state)
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{
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const int np = props.numPhases();
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const int nc = props.numCells();
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std::vector<double> allA(nc*np*np);
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std::vector<int> allcells(nc);
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for (int c = 0; c < nc; ++c) {
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allcells[c] = c;
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}
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//std::vector<double> res_vol(np);
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const std::vector<double>& z = state.surfacevol();
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props.matrix(nc, &state.pressure()[0], &state.temperature()[0], &z[0], &allcells[0], &allA[0], 0);
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// Linear solver.
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MAT_SIZE_T n = np;
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MAT_SIZE_T nrhs = 1;
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MAT_SIZE_T lda = np;
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std::vector<MAT_SIZE_T> piv(np);
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MAT_SIZE_T ldb = np;
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MAT_SIZE_T info = 0;
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//double res_vol;
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double tot_sat;
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const double epsilon = std::sqrt(std::numeric_limits<double>::epsilon());
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for (int c = 0; c < nc; ++c) {
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double* A = &allA[c*np*np];
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const double* z_loc = &z[c*np];
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double* s = &state.saturation()[c*np];
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for (int p = 0; p < np; ++p){
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s[p] = z_loc[p];
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}
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dgesv_(&n, &nrhs, &A[0], &lda, &piv[0], &s[0], &ldb, &info);
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tot_sat = 0;
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for (int p = 0; p < np; ++p){
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if (s[p] < epsilon) // saturation may be less then zero due to round of errors
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s[p] = 0;
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tot_sat += s[p];
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}
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for (int p = 0; p < np; ++p){
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s[p] = s[p]/tot_sat;
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}
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}
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}
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/// Compute two-phase transport source terms from well terms.
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/// Note: Unlike the incompressible version of this function,
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/// this version computes surface volume injection rates,
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/// production rates are still total reservoir volumes.
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/// \param[in] props Fluid and rock properties.
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/// \param[in] wells Wells data structure.
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/// \param[in] well_state Well pressures and fluxes.
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/// \param[out] transport_src The transport source terms. They are to be interpreted depending on sign:
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/// (+) positive inflow of first (water) phase (surface volume),
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/// (-) negative total outflow of both phases (reservoir volume).
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void computeTransportSource(const BlackoilPropertiesInterface& props,
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const Wells* wells,
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const WellState& well_state,
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std::vector<double>& transport_src)
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{
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int nc = props.numCells();
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transport_src.clear();
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transport_src.resize(nc, 0.0);
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// Well contributions.
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if (wells) {
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const int nw = wells->number_of_wells;
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const int np = wells->number_of_phases;
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if (np != 2) {
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OPM_THROW(std::runtime_error, "computeTransportSource() requires a 2 phase case.");
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}
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std::vector<double> A(np*np);
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for (int w = 0; w < nw; ++w) {
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const double* comp_frac = wells->comp_frac + np*w;
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for (int perf = wells->well_connpos[w]; perf < wells->well_connpos[w + 1]; ++perf) {
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const int perf_cell = wells->well_cells[perf];
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double perf_rate = well_state.perfRates()[perf];
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if (perf_rate > 0.0) {
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// perf_rate is a total inflow reservoir rate, we want a surface water rate.
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if (wells->type[w] != INJECTOR) {
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std::cout << "**** Warning: crossflow in well "
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<< w << " perf " << perf - wells->well_connpos[w]
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<< " ignored. Reservoir rate was "
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<< perf_rate/Opm::unit::day << " m^3/day." << std::endl;
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perf_rate = 0.0;
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} else {
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assert(std::fabs(comp_frac[0] + comp_frac[1] - 1.0) < 1e-6);
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perf_rate *= comp_frac[0]; // Water reservoir volume rate.
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props.matrix(1, &well_state.perfPress()[perf], &well_state.temperature()[w], comp_frac, &perf_cell, &A[0], 0);
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perf_rate *= A[0]; // Water surface volume rate.
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}
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}
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transport_src[perf_cell] += perf_rate;
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}
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}
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}
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}
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} // namespace Opm
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