IEEE Power & Energy Magazine - September/October 2021 - 21

Fast frequency response reserve helps arrest a faster frequency
decline and is being considered by the Australian Energy Market
Commission, the NEM rule-making body.
Another major positive change to frequency management
in the NEM was the reinstatement of broad-based
primary frequency control, also known as droop control,
on all large-scale generators in 2020. This was introduced
by the Australian Energy Market Commission in
response to declining frequency
performance. These rules were
introduced with minimum specifications
as to how the control pa -
rameters are set. Generating systems
are not required to carry
headroom (the ability to increase
output) or foot room (the ability
to decrease output) beyond what
is available through normal op -
eration or purchased in the re -
serve market.
This change has resulted in a
160
140
120
100
80
60
40
20
significant improvement in the
normal-band frequency performance.
Figure 5 illustrates the
following:
✔ The frequency distribution in
the NEM in 2010 has a frequency
performance tightly
centered around 50 Hz.
✔ The primary frequency response
declines after 2010
as generators withdraw
primary frequency control
outside of market enablement
(what was enabled to
comply with the market requirements),
and the amount
of renewable generation online
increases, as seen in the
September 2020 trace.
✔ There is a marked performance
improvement in
the normal operating band
since October 2020 when
the process of re-enabling
primary frequency control
on all generators began.
This process is still currently
underway.
september/october 2021
What is not shown or quantified in this article is the
improvement in system resi l ience. Enabl ing primary
frequency control on all large generators increases the system's
ability to survive more extreme events or larger
system disturbances not covered by the market-purchased
2015
2016
2017
2025 Forecast Range
Minimum Synchronous Generation Requirements
2018
2019
0102030405060
Probability of Exceedance (%)
70 80 90 100
figure 3. The NEM historic mainland inertia and future forecast range. (Source:
AEMO; used with permission.)
Credible Risk = 750 MW, Low Load = 18,860 MW, Load Relief = 0.5
1,900
1,700
1,500
1,300
1,100
900
700
500
40,000 50,000 60,000 70,000 80,000 90,000 100,000110,000 120,000
Precontingent Inertia (MW.s)
0 MW FFR Dynamic
328 MW FFR Dynamic
656 MW FFR Dynamic
Static Requirement
492 MW FFR Dynamic
164 MW FFR Dynamic
Minimum System Strength
Requirements
figure 4. The estimated 6-s reserve requirements plotted against the NEM system
inertia precontingency for the largest credible risk of 750 MW. FFR: fast frequency
response. (Source: AEMO; used with permission.)
ieee power & energy magazine
21
6-s Reserve (R6_MW)
Inertia (GW)

IEEE Power & Energy Magazine - September/October 2021

Table of Contents for the Digital Edition of IEEE Power & Energy Magazine - September/October 2021

Contents
IEEE Power & Energy Magazine - September/October 2021 - Cover1
IEEE Power & Energy Magazine - September/October 2021 - Cover2
IEEE Power & Energy Magazine - September/October 2021 - Contents
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