Monday 8 June 2026
Trading day 2026-06-08
Tasmanian prices lead NEM as southern regions record negative price intervals
Average prices across the mainland varied widely, with New South Wales and Queensland settling near 67 dollars per megawatt hour. South Australia and Victoria remained the lowest priced regions, each recording two negative price intervals and averages below 35 dollars. Tasmania maintained the highest regional average and peak price, reaching 113.6 dollars per megawatt hour during the evening demand period.
System demand peaked across all regions between 17:45 and 18:35, with New South Wales reaching a maximum load of 9,946 megawatts. Coal-fired generation provided 53.9 percent of the total energy mix, while wind and solar combined for 34.1 percent of daily output. Hydroelectric generation contributed 7.2 percent to the mix, and gas generation remained low at 2.7 percent.
Batteries discharged 12,135 megawatt hours throughout the day, though the fleet remained a net consumer with a balance of negative 3,628 megawatt hours. FCAS costs were dominated by regulation services, with the highest single peak price of 16 dollars occurring in the New South Wales Raise Regulation market.
Interconnector flows showed significant movement from Victoria into New South Wales and South Australia. Queensland exported a net 31,115 megawatt hours to New South Wales, while Tasmania exported 9,555 megawatt hours to the mainland via the Basslink interconnector.
Today · Predispatch forecasts indicate a price peak of 319.04 dollars per megawatt hour in Queensland at 19:30, with other regions peaking between 61.84 and 145.00 dollars.
Why it matters · The daily average price of 49.0 dollars sits 18.5 percent below the weekly average, breaking a three-day trend of rising prices. This lower price environment occurred despite a slight increase in emissions, as negative pricing in southern regions coincided with a high 54.1 percent instantaneous renewable peak.
Prices
Trading day · 04:00 → 04:00 AEST · 30-min average
| Region | Avg | VWAP | Min | Max | Neg | Cap |
|---|---|---|---|---|---|---|
| NSW | $67 | $69 | $24 | $114 | 0 | 0 |
| QLD | $67 | $69 | $23 | $111 | 0 | 0 |
| SA | $32 | $35 | -$2 | $103 | 2 | 0 |
| VIC | $34 | $38 | -$2 | $103 | 2 | 0 |
| TAS | $83 | $84 | $69 | $114 | 0 | 0 |
Min · Max are 5-minute dispatch extremes; the price chart plots 30-minute averages, so its peak reads lower.
Demand
FCAS
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $5,955 | 0 | $16 | 8 June, 16:05 |
| LOWERREG | $1,289 | 0 | $5 | 8 June, 19:50 |
| RAISE6SEC | $291 | 0 | $0 | 8 June, 17:35 |
| LOWER60SEC | $246 | 0 | $1 | 8 June, 14:50 |
| RAISE60SEC | $230 | 0 | $0 | 8 June, 17:45 |
| RAISE5MIN | $119 | 0 | $0 | 8 June, 17:35 |
| LOWER6SEC | $73 | 0 | $0 | 8 June, 15:35 |
| LOWER5MIN | $55 | 0 | $0 | 8 June, 09:05 |
| Total | $8,259 | |||
Cost = NSW RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $6,384 | 0 | $16 | 8 June, 16:05 |
| LOWERREG | $3,887 | 0 | $5 | 8 June, 19:50 |
| RAISE6SEC | $550 | 0 | $0 | 8 June, 17:35 |
| LOWER60SEC | $497 | 0 | $1 | 8 June, 14:50 |
| RAISE60SEC | $352 | 0 | $0 | 8 June, 17:45 |
| RAISE5MIN | $146 | 0 | $0 | 8 June, 17:35 |
| LOWER6SEC | $115 | 0 | $0 | 8 June, 15:35 |
| LOWER5MIN | $79 | 0 | $0 | 8 June, 09:05 |
| Total | $12,011 | |||
Cost = QLD RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $7,532 | 0 | $16 | 8 June, 16:05 |
| LOWERREG | $2,586 | 0 | $5 | 8 June, 19:50 |
| RAISE6SEC | $430 | 0 | $0 | 8 June, 17:35 |
| RAISE60SEC | $383 | 0 | $0 | 8 June, 17:45 |
| LOWER60SEC | $334 | 0 | $1 | 8 June, 14:50 |
| RAISE5MIN | $150 | 0 | $0 | 8 June, 17:35 |
| LOWER6SEC | $57 | 0 | $0 | 8 June, 15:35 |
| LOWER5MIN | $40 | 0 | $0 | 8 June, 09:05 |
| Total | $11,512 | |||
Cost = VIC RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $5,202 | 0 | $16 | 8 June, 16:05 |
| LOWERREG | $3,886 | 0 | $5 | 8 June, 19:50 |
| LOWER60SEC | $270 | 0 | $1 | 8 June, 14:50 |
| RAISE6SEC | $176 | 0 | $0 | 8 June, 17:35 |
| RAISE60SEC | $121 | 0 | $0 | 8 June, 17:45 |
| LOWER6SEC | $61 | 0 | $0 | 8 June, 15:35 |
| RAISE5MIN | $58 | 0 | $0 | 8 June, 17:35 |
| LOWER5MIN | $32 | 0 | $0 | 8 June, 09:05 |
| Total | $9,804 | |||
Cost = SA RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $9,599 | 0 | $6 | 8 June, 06:00 |
| LOWERREG | $5,487 | 0 | $13 | 9 June, 01:05 |
| LOWER6SEC | $4,682 | 0 | $3 | 8 June, 04:05 |
| RAISE6SEC | $1,126 | 0 | $0 | 8 June, 04:05 |
| RAISE60SEC | $1,123 | 0 | $0 | 8 June, 04:05 |
| LOWER60SEC | $911 | 0 | $1 | 8 June, 04:35 |
| LOWER5MIN | $71 | 0 | $3 | 8 June, 04:35 |
| RAISE5MIN | $5 | 0 | $0 | 8 June, 04:45 |
| Total | $23,005 | |||
Cost = TAS RRP × cleared MW per 5-min interval.
Battery dispatch
Peak moment
Fleet discharged 782 MW at 18:00 as NSW spot hit $100/MWh.
Peak moment
Fleet discharged 1,372 MW at 18:00 as QLD spot hit $96/MWh.
Peak moment
Fleet discharged 897 MW at 18:00 as VIC spot hit $90/MWh.
Peak moment
Fleet discharged 625 MW at 18:30 as SA spot hit $87/MWh.
Peak moment
Fleet discharged 3,589 MW at 18:00 as TAS spot hit $88/MWh.
Fleet net dispatch · spot-price overlay · 30-min average
Regional dispatch ranking
| Region | Discharged | Net |
|---|---|---|
#1QLD | 4,304MWh | -1,355 |
#2VIC | 3,135MWh | -600 |
#3NSW | 2,928MWh | -1,339 |
#4SA | 1,768MWh | -335 |
Generation Mix
- Coal61.4% · 123.2 GWh
- Gas1.7% · 3.4 GWh
- Hydro6.5% · 13.0 GWh
- Wind7.8% · 15.6 GWh
- Solar (utility)11.6% · 23.2 GWh
- Solar (rooftop)9.6% · 19.4 GWh
- Battery1.5% · 2.9 GWh
- Coal55.4% · 101.9 GWh
- Gas5.3% · 9.8 GWh
- Hydro2.6% · 4.7 GWh
- Wind15.2% · 27.9 GWh
- Solar (utility)8.8% · 16.2 GWh
- Solar (rooftop)10.4% · 19.2 GWh
- Battery2.3% · 4.3 GWh
- Coal65.5% · 106.1 GWh
- Hydro3.0% · 4.9 GWh
- Wind17.9% · 29.0 GWh
- Solar (utility)4.5% · 7.3 GWh
- Solar (rooftop)7.2% · 11.6 GWh
- Battery1.9% · 3.1 GWh
- Gas8.3% · 3.5 GWh
- Wind65.5% · 27.4 GWh
- Solar (utility)6.4% · 2.7 GWh
- Solar (rooftop)15.6% · 6.5 GWh
- Battery4.2% · 1.8 GWh
- Hydro83.6% · 21.8 GWh
- Wind13.7% · 3.6 GWh
- Solar (rooftop)2.7% · 0.7 GWh
Renewables
- NSW 27.6%
- VIC 32.3%
- QLD 33.9%
- SA 94.0%
- TAS 88.3%
Interconnectors
| Region (proxy) | Net flow | Direction changes | Hours at limit |
|---|---|---|---|
| N-Q-MNSP1 | +7.5 GWh | 35 | — |
| NSW1-QLD1 | −31.1 GWh | 8 | — |
| VIC1-NSW1 | +28.9 GWh | 0 | — |
| V-SA | +8.7 GWh | 19 | — |
| T-V-MNSP1 | −9.6 GWh | 0 | — |
Per-region net of NETINTERCHANGE proxied to a representative interconnector. Full per-interconnector decomposition + hours-at-limit needs DINTERCONNECTOR parsing (follow-up).
Emissions
| NSW | 110.0k tCO₂ | 0.556 tCO₂/MWh |
| QLD | 93.2k tCO₂ | 0.507 tCO₂/MWh |
| SA | 1.6k tCO₂ | 0.037 tCO₂/MWh |
| VIC | 124.0k tCO₂ | 0.772 tCO₂/MWh |
| TAS | 0 tCO₂ | 0.000 tCO₂/MWh |