2021 Investor Day Presentation
Future dry year flexibility scenarios
(3) Onslow-Manorburn (simple) pumped storage
585MW of (new or old) Southland load with no flexibility
A simple 4,000GWh storage and 1,000MW power station.
scheme:
25% losses: 750MW available for hydro management
and 250MW for intermittency management
Reservoir release rules determined by dynamic needs of
the power system, dispatched according to water-value:
Mean dry-year pumping load is 650GWh - 'trickle
charge' overnight in summer
Mean generation / releases are 325GWh. This will
increase as Lake Onslow fills. Intermittency
management contributes an extra ~125GWh
■ There is a clear seasonal need for generation
In extremes, up to an extra 1,500GWh of generation is
dispatched back into the market
# of years
Annual
Onslow-Manorburn Generation
output
Southland Stimulation; 750MW generator; trickle-charge pumping; No thermal
100
100%
90%
90
80
70
60
Count
50
— SumProb
40
40
30
20
10
80%
70%
60%
50%
40%
30%
20%
10%
0%
<0 0 135 135 - 270-
270 405
405- 540- 675- 810-
945 1,080 1,215 1,350 1,485 1,620 1,755 1,890 -
540 675 810 945 1,080 1,215 1,350 1,485 1,620 1,755 1,890 2,000
annual generation [GWh]
sum prob (
years)
Source: Meridian
The estimated $4B+¹ Onslow scheme can be a viable
dry year mechanism, along-side other sources of
flexibility
¹estimated cost, not including further required investment in transmission
Meridian.
11 MAY 2021
2021 INVESTOR DAY PRESENTATION
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