I have posed this important test case below to Power Globers, a world wide group
of power system engineers.  If these results can be verified using a sequential
frequency and duraion Monte Carlo model, then we have taken an important step
forward in modeling the generation and transmission adequacy by bringing
together transmission modeling currently in use world wide by engineers with
probabilistic generation installed capacity adequacy.  This makes studies with
these two considered together a simple engineering process for the first time.
Because the RTS programs on my web page already handle precisely the modeling
of sequential events variable energy resources wind hydro and solar, we will be
able to design electric grids that minimize the use of fossil fuels and especially
the capacity needed in fossil fuels to keep the lights on.  The problem with
energy only models is that they allow our grids to get into a lights outage
condition too often.  The RTS programs spedifically address the question of
capacity needed to keep the lights on.  Unfortunately we are too highly dependent
on the use of fossil fuels to keep the lights on.  We need to engineer the grid
so it will be reliable without dependence on fossil fuels capacities.  Please use
the RTS programs I have posted on line to move the world forward in these efforts.

Sincerely,
Gene Preston
11/30/2016

Subject: request the running of a special 96 RTS test case
To:           POWER-GLOBE@LISTSERV.NODAK.EDU


The 1996 RTS is three areas.  It's an overly reliable system.
To make it less reliable and to stress the transmission system I have found
one easy way to do this is to remove the 300 MW hydro generators from area 3
and to remove the four 76 MW coal generators from area 3.  I get the
following indices for this case:

Total System - no transmission constraints
MAX GENR  =  9611 MW
PERIOD    =  8736 HOURS
PEAK DEMD =  8550 MW (substation loads)
RESERVE   =  12.4 %
LOLE      = 0.592 d/y (shared loss of load system wide)
LOLEV     = 0.729 events/y
LOLH      = 2.573 h/y

Area 3 with transmission constraints
MAX GENR  =  3446 MW
PERIOD    =  8736 HOURS
PEAK DEMD =  2850 MW (substation loads)
LOLE      = 1.097 d/y (shared loss of load within area 3)
LOLEV     = 1.468 events/y
LOLH      = 6.810 h/y
TIE LINES = 4.237 h/y (hours the transmission import tie lines increase area 3 LOLP)

There are no transmission outages within areas to cause individual substation loss of load.  
Only the tie lines from area 3 to the other areas is tested for N-0 and N-1.
Do not calculate area 1 and 2 loss of load for the area 3 loss of load calculation.

Could someone with a suitable program run this modified system and share their results?  
The input data I used is included in this file: http://egpreston.com/RTS2.zip  
Transmission losses were not included in the above indices calculations.

Thanks,
Gene Preston

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