perolofl's profile - activity

Use tool in menu: Power Flow - Convert Loads and Genertors...

To write the relay slot value (1 or 2) in DOCU and DYDA.

How do you simulate without seeing the progress output? You can always run the script inside PSSE.

@Engineer Power System: Which version of PSSE are you using?

It is better to write in English in this forum!

For in-line fault in a dynamic simulation, see post how can i set the fualt location in PSS/E.

The record "260 'USRMDL' 1 'PLBVFU1' 1 1 3 4 3 6 1 1 'BA1_Play_RT' 1.0 1.0 0.01 0.01 /" is ok for me.

Something is wrong with the simulations if the two results are not identical up to 3.5 seconds. Check the output in progress properly!

What is the name of plb-file? Show your dyre-record.

Yes, as shown above!

Skip the python script and run everything in the GUI. Check the progress window and dynamics spreadsheet.

You don't have any generator and electrical model for the wind generator...

Please also read the the messages in progress window!

Use elementary block WSHOUT_MODEn. See Program Application Guide, Vol 2.

It might be:

• The generators are out of service in saved case
• The generators in the .dyr file are not present in the saved case

I am trying to test frequency ride through in PSSE for 0.3Hz step/down from 60 Hz. My PLBVFU1 model looks like

"260 'USRMDL' 1 'PLBVFU1' 1  1  3  4  3  6  1  1 'BA3_Play_RT' 1.0 60.0 0.00 0.00 /"

in dyr file, also my plb file is

@!time, V(kV), f(Hz) 
@!6.5 TO 6.8 FAULT
0.0         1.0     60.0
6.5         1.0     60.0
6.5001      1.0     60.3
6.8         1.0     60.3
6.8001      1.0     60.3    
12.0        1.0     60.0.

When I plot them in PSSE, I don't see frequency from 60 Hz to 60.3 Hz, instead plot starts from 1 goes to 0.005 and back to 1.

Can anyone help is finding the issue, also how can I plot 60 Hz data in PSSE. Am testing these models against PSCAD where frequency is in 60 Hz. Because of this difference, I can't plot both the PSSE and PSCAD values on same plot for MQT's.

PSSE doesn't plot the frequency in Hz, it shows instead the per unit speed deviation. This means that 60 Hz is 0 pu speed deviation and 0.005 pu = (1+0.005)60 = 60.3 Hz.

There are many posts here describing this, for example: Frequency zero

Seems you need a user written model.

What do you want to do?

Yes, it should be 101, 102, 103. IC=104 is for pitch control model.

The following Fortran-90 code works:

integer :: IERR, IARRAY(99), TDIM=99
REAL :: RXVALUE 
CALL FINDSHORTESTDISTANCEBETWEENTWOBUS(0, 101, 3001, TDIM, IARRAY,RXVALUE, IERR)

Note that IARRAY must have the length of TDIM. You shouldn't set TDIM to 9999 and the array to length 6.

I also noted that TDIM must be a variable, not hard coded.

In .dyr-file, what IC code is used for the electrical model?

Maybe you can show the code?

Use the Line Fault tool. The fault is always applied at the from bus end of the line, so enter 29 as from bus:

Can you show your code and describe the problem?

API: psspy.machine_chng_4(ibus,id,[_i,owner]).

In what way is the data locked? Describe what happens.

It is not possible to change the owner name, just the owner number.

You can change the owner in Machine spreadsheet.

Governor model TGOV2 and TGOV3 have fast valving.

The frequency filter time constant is shown in "Dynamic Solution Parameters".

Personally, I prefer to set D to zero in the generator model and to model the load frequency dependency with a load model, e.g. LDFRAL.

Sounds strange, Have you tested Edit - Reset Workspace?

Still not clear, you mention output file, pdev/odev. Do you want something like "Run time = 20.000 s" in progress window?

It is confusing when you write "using a simple user written model". Why not just use psspy.dsrval('DELT')? It is better to use Python instead of PSAS/IDEV for the contingency.

Can you show a raw data file of your test system?

I believe you haven't activated Network frequency dependence in Dynamic Simulation Options:

It is a very bad practice to save the converted case (generators and loads) in a "converted saved case". In your example with suffix .cnv instead of .sav.

There is no real reason to do this. It is better to start every simulation from a normal saved case and a snapshot/dyre file. You can remove the save statement.

The actual simulation time is available in variable TIME (GET_TIME() in rev 36) in a user written model.

EDIT:

The following Python code after the simulation will print the actual time to progress window:

ierr, run_time = psspy.dsrval('TIME')
psspy.progress(f'Run time = {run_time:.3f} s\n')

The trip disconnects the branch. The branch fault is a part if the branch data (line shunt at ibus side). Disconnecting the branch means that the fault is no longer connected to the system. Tripping branch means tripping line and shunt fault. There is no need for clear fault in this contingency.

Clear fault just removes the fault shunt inserted by dist_branch_fault.

Branch faults are modelled with a large line shunt on the faulted line. Tripping the line, means that the fault is isolated from the rest of the system, i.e. the fault is cleared at time 1.05 when the line is tripped.

Does psspy.distclearfault(1) put the tripped branch between bus 40809 and bus 41450 back into service after clearing the fault on the branch in the following code?

psspy.run(0,1.0,500,50,0)
psspy.dist_branch_fault(ibus=40809, jbus=41450, id = '1', units = 3, basekv = 0.0, values1 = 0, values2=0)
psspy.run(0,1.05,500,6,0)
psspy.dist_branch_trip(ibus = 40809, jbus =41450, id = '1')
psspy.run(0,1.10,500,6,0)
ierr = psspy.dist_clear_fault(1)
psspy.run(0,15,500,6,0)

@Yoyo: The code returns all branches and 2W-transformers connected to ibus. Change to nxtbrn3 to also get the 3W-transformers.

Always the same answer. The source code is needed, and an appropriate compiler.

I see now your other post regarding gewt.dll. The file is not linked for rev 35.5!

Have you compiled and linked gewt.dll yourself?

No other model is needed. The only possible auxiliary models are a stabiliser which will modulate VOTHSG or a compensator model to change the measured voltage.

The active power output is changed manually in the simulation with VAR(L).

I am an undergraduate doing a research project on BESS. i used a generator as a conventional machine and used the cbest model with below parameters,

1       PMAX (pu on MBASE)
1.1     OutEff (>= 1) Output Efficiency                                 
0.9     InpEff (<= 1) Input Efficiency                                                                  
1.2     IACMAX (pu)
100     KAVR, AVR gain
0       T1, AVR time constant (sec)
1       T2, AVR time constant (sec)
0.05    T3, AVR time constant (sec) ( >0 )
10      T4, AVR time constant (sec)
1       VMAX, AVR speed limit (pu)
-1      VMIN, AVR speed limit (pu) ( <0 )
0.025   DROOP (pu)

Is it enough to model the bess or do i need to select a model for exciter, governor, stabilizer,..