IEEE Electrification - September 2022 - 75

market, creates both opportunities and challenges. While
Tasmania can rapidly respond to the energy needs of the
mainland, ready access to low-cost mainland energy
sources can at times eliminate the need for any synchronous
generation in Tasmania.
With the commissioning of the Wild Cattle Hill (148 MW)
and Granville Harbour (112 MW) Wind Farms in 2020, the
installed capacity of wind generation increased to 568 MW.
On 16 January 2021, a combination of low spot prices on
the mainland (refer to Figure 3), coupled with excellent
wind conditions in Tasmania, resulted in our record
instantaneous system nonsynchronous penetration (SNSP)
ratio of 91.6%. [The SNSP is the ratio of IBR supply (HVdc
imports plus on-island wind generation) to demand drawn
from the transmission system.] The peak SNSP of 91.6%
was recorded on 16 January 2021 at 3:55 p.m. and comprised
390 MW of HVdc import and 525 MW of on-island
wind generation supplying an operational demand of 997 MW.
The balance of demand not supplied by wind and HVdc
import was supplied by on-island hydrogeneration.
Importantly, high SNSP outcomes have been sustained
for significant periods of time and are not " transient " in
nature. On 16 January, operation above 80% SNSP was sustained
continuously by high wind and HVdc import conditions
for nearly 8 h, as shown in Figure 4.
For the calendar year 2021 (see Figure 5), the 95th percentile
SNSP was 67.3%, meaning that 5% of all operating
periods were above this value. The 99th percentile was
79.6%. While 1% of the time does not sound like much, it
equates to three and one half days per year when Tasmanian
customers are being supplied from at least 80%
nonsynchronous generation. The average SNSP over the
year was 23.8%.
System Security Challenges and
Solutions So Far
The Tasmanian power system has long had unique performance
challenges, particularly in relation to system
frequency control. These challenges arise from the relatively
large contingency sizes in Tasmania compared to
the size of the system as well as the dominance of hydrogeneration,
which can exhibit slow governor control
action limited by hydraulic time constants. The situation
is further exacerbated when system inertia is reduced
by hydrogeneration coming offline due to energy market
outcomes, as described previously. The ongoing integration
of wind generation and the resulting high instantaneous
penetration of IBRs have created several new
challenges, some of which will be outlined in the following
discussions.
Figure 3. The NEM spot market at 3:55 p.m. on Saturday, 16 January 2021.
IEEE Electrification Magazine / SEPTEMBER 2022
75

IEEE Electrification - September 2022

Table of Contents for the Digital Edition of IEEE Electrification - September 2022

Contents
IEEE Electrification - September 2022 - Cover1
IEEE Electrification - September 2022 - Cover2
IEEE Electrification - September 2022 - Contents
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IEEE Electrification - September 2022 - Cover3
IEEE Electrification - September 2022 - Cover4
https://www.nxtbook.com/nxtbooks/pes/electrification_december2022
https://www.nxtbook.com/nxtbooks/pes/electrification_september2022
https://www.nxtbook.com/nxtbooks/pes/electrification_june2022
https://www.nxtbook.com/nxtbooks/pes/electrification_march2022
https://www.nxtbook.com/nxtbooks/pes/electrification_december2021
https://www.nxtbook.com/nxtbooks/pes/electrification_september2021
https://www.nxtbook.com/nxtbooks/pes/electrification_june2021
https://www.nxtbook.com/nxtbooks/pes/electrification_march2021
https://www.nxtbook.com/nxtbooks/pes/electrification_december2020
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