-- The jacobian and residual in the reservoir is updated directly
-- The sparsity pattern are provided to the well matrices.
-- Some cleaning in updateWellState()
-- isRS and phaseCondition is removed and hydroCarbonState in the state
is used instead
-- input of pressurediffs to computeHydrostaticCorrection() is changed
to double from Vector in WellHelpers.hpp
-- a new updateState is implemented based on dune vectors
-- the old is kept for comparision in this PR
-- the updateState is not identical.
Tested on spe1, spe9 and norne and it improves the convergence compares
to the old one.
- unused code is removed
- the scaled normed is stored in residual_norm_history for usage in
stabilized newton
- number of linear iterations is outputted
- linear solver tolerance is reduced to 0.01
- make compute wellFlux local
- rewrite ADB::V to std::vector<double>
remove the now unnecessary inclusion of
"NewtonIterationBlackoilInterleaved.cpp" (mind the .cpp extension!)
and include "dune/istl/solvers.hh" instead.
1) The wellsolution is stored in wellVariables as a vector of DenseAD
objects. The wellVariables is computed from the wellstate in
setWellVariables()
2) BHP and well fluxes are not stored directly but calculated based on
the wellVariables
3) The initial well accumulation term is stored as a vector of doubles.
4) addWellFluxEq() uses DenseAd flux and accumulation terms
5) computePropertiesForWellConnectionPressures() no longer uses state as
input. The wellstate is used to get the bhp pressure.
6) The current wellcontrol is set when updated in updateWellControls()
in order to use well_controls_get_current_type(wc) insted of
well_controls_iget_type(wc, currentIdx)
Tested on SPE1, SPE9 and Norne.
Effects the convergence but the results are identical.
Start using the well model desribed in SPE 12259 "Enhancements to the
Strongly Coupled, Fully Implicit Well Model: Wellbore CrossFlow Modeling
and Collective Well Control"
The new well model uses three well primary variables: (the old one had
4)
1) bhp for rate controlled wells or total_rate for bhp controlled wells
2) flowing fraction of water Fw = g_w * Q_w / (g_w * Q_w + q_o * Q_o +
q_g + Q_g)
3) flowing fraction of gas Fg = g_g * Q_g / (g_w * Q_w + q_o * Q_o +
q_g + Q_g)
where g_g = 0.01 and q_w = q_o = 1;
Note 1:
This is the starting point of implementing a well model using denseAD
The plan is to gradually remove Eigen from the well model and instead
use the fluidState object provided by the Ebos simulator
Note 2:
This is still work in progress and substantial cleaning and testing is
still needed.
Note 3: Runs SPE1, SPE9 and norne until 950 days.
there was a screw-up with the output directory (to set it you need to
modify the EclipseState by means of the IOConfig object? WTF?) and it
seems like the FlowMain.hpp was modified since FlowMainEbos.hpp was
added so there was some terminal output missing.
for the gas-only case with vaporized oil enabled, the oil pressure was
used, but ebos uses the gas pressure as a primary variable in that
case. (the reason is that it is faster to check if oil appears if the
gas pressure is available in that case.) This patch corrects that and
does no longer use the PrimaryVariables::set$FOO_PV() methods because
these methods are hard to keep in sync with the indices for the
primary-variables-as-a-Dune::FieldVector feature (which is actually
quite important for the linear solver).
