Friday 10 July 2026
Trading day 2026-07-10
New South Wales average price leads NEM amid moderate demand peaks
Regional average prices ranged from 81.20 dollars in Tasmania to 100.50 dollars in New South Wales, with Tasmania seeing a brief volatility peak of 450.30 dollars. South Australia and Victoria recorded 32 negative price intervals combined, contrasting with the consistently positive pricing observed in the northern regions.
Coal-fired generation provided 58.1 percent of the total energy mix, while combined solar and wind assets contributed 23.4 percent of daily supply. Hydroelectric generation added a further 9.9 percent, and the renewable share reached an instantaneous peak of 55.4 percent at 11:30.
Battery storage systems discharged 17,097 megawatt hours to the grid, maintaining a net consumption position of 306 megawatt hours for the day. Total emissions were recorded at 408,548 tonnes of carbon dioxide, representing a 29.4 percent increase compared to the same day last week.
FCAS costs were concentrated in Tasmania, where the Raise Regulation service peaked at 368.00 dollars. Interconnector flows showed significant movement from Queensland into New South Wales, while Victoria exported net energy to both South Australia and New South Wales.
Today · Predispatch forecasts indicate a peak price of 319.04 dollars in Queensland at 19:30, with other regions expecting maximums below 150.00 dollars.
Why it matters · The daily average of 100.40 dollars sits 3.3 percent below the seven-day average, breaking a two-day trend of prices exceeding 120.00 dollars. This pricing occurred despite a significant 29.4 percent rise in emissions and a relatively low 34.1 percent renewable share compared to recent peak performance.
Prices
Trading day · 04:00 → 04:00 AEST · 30-min average
| Region | Avg | VWAP | Min | Max | Neg | Cap |
|---|---|---|---|---|---|---|
| NSW | $101 | $102 | $52 | $175 | 0 | 0 |
| QLD | $83 | $85 | $47 | $151 | 0 | 0 |
| SA | $89 | $91 | -$6 | $159 | 20 | 0 |
| VIC | $85 | $89 | -$1 | $161 | 12 | 0 |
| TAS | $81 | $84 | -$1 | $450 | 2 | 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 | $4,302 | 0 | $12 | 10 July, 09:40 |
| LOWERREG | $884 | 0 | $3 | 10 July, 06:30 |
| RAISE6SEC | $214 | 0 | $0 | 10 July, 07:40 |
| RAISE60SEC | $156 | 0 | $0 | 10 July, 07:45 |
| LOWER60SEC | $83 | 0 | $0 | 10 July, 13:25 |
| RAISE5MIN | $74 | 0 | $0 | 10 July, 07:05 |
| LOWER5MIN | $53 | 0 | $0 | 10 July, 16:00 |
| LOWER6SEC | $49 | 0 | $0 | 10 July, 13:25 |
| Total | $5,815 | |||
Cost = NSW RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $4,985 | 0 | $12 | 10 July, 09:40 |
| LOWERREG | $2,292 | 0 | $3 | 10 July, 06:30 |
| RAISE6SEC | $406 | 0 | $0 | 10 July, 07:45 |
| RAISE60SEC | $225 | 0 | $0 | 10 July, 07:45 |
| LOWER60SEC | $174 | 0 | $0 | 10 July, 13:25 |
| LOWER6SEC | $93 | 0 | $0 | 10 July, 13:25 |
| RAISE5MIN | $74 | 0 | $0 | 10 July, 07:05 |
| LOWER5MIN | $59 | 0 | $0 | 10 July, 16:00 |
| Total | $8,309 | |||
Cost = QLD RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $6,647 | 0 | $12 | 10 July, 09:40 |
| LOWERREG | $1,866 | 0 | $3 | 10 July, 06:30 |
| RAISE6SEC | $425 | 0 | $0 | 10 July, 07:40 |
| RAISE60SEC | $362 | 0 | $0 | 10 July, 07:45 |
| RAISE5MIN | $157 | 0 | $0 | 10 July, 07:05 |
| LOWER60SEC | $126 | 0 | $0 | 10 July, 13:25 |
| LOWER6SEC | $63 | 0 | $0 | 10 July, 13:25 |
| LOWER5MIN | $40 | 0 | $0 | 10 July, 16:00 |
| Total | $9,687 | |||
Cost = VIC RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $5,363 | 0 | $12 | 10 July, 09:40 |
| LOWERREG | $2,425 | 0 | $3 | 10 July, 06:30 |
| RAISE6SEC | $394 | 0 | $0 | 10 July, 07:40 |
| RAISE60SEC | $285 | 0 | $0 | 10 July, 07:45 |
| LOWER60SEC | $166 | 0 | $0 | 10 July, 13:25 |
| RAISE5MIN | $110 | 0 | $0 | 10 July, 07:05 |
| LOWER6SEC | $104 | 0 | $0 | 10 July, 13:25 |
| LOWER5MIN | $86 | 0 | $0 | 10 July, 16:00 |
| Total | $8,934 | |||
Cost = SA RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $19,472 | 0 | $368 | 10 July, 10:05 |
| LOWER6SEC | $6,217 | 0 | $107 | 10 July, 23:55 |
| LOWERREG | $5,847 | 0 | $50 | 10 July, 05:05 |
| RAISE6SEC | $4,950 | 0 | $83 | 10 July, 12:35 |
| RAISE60SEC | $680 | 0 | $3 | 10 July, 23:35 |
| LOWER60SEC | $249 | 0 | $0 | 10 July, 12:35 |
| RAISE5MIN | $33 | 0 | $0 | 10 July, 12:35 |
| LOWER5MIN | $33 | 0 | $0 | 10 July, 12:35 |
| Total | $37,480 | |||
Cost = TAS RRP × cleared MW per 5-min interval.
Battery dispatch
Peak moment
Fleet discharged 1,559 MW at 18:00 as NSW spot hit $141/MWh.
Peak moment
Fleet discharged 1,417 MW at 18:00 as QLD spot hit $126/MWh.
Peak moment
Fleet discharged 827 MW at 08:30 as VIC spot hit $143/MWh.
Peak moment
Fleet discharged 253 MW at 19:00 as SA spot hit $106/MWh.
Peak moment
Fleet discharged 3,842 MW at 18:00 as TAS spot hit $119/MWh.
Fleet net dispatch · spot-price overlay · 30-min average
Regional dispatch ranking
| Region | Discharged | Net |
|---|---|---|
#1QLD | 5,985MWh | -743 |
#2NSW | 5,448MWh | +1,040 |
#3VIC | 4,340MWh | -397 |
#4SA | 1,325MWh | -206 |
Generation Mix
- Coal69.9% · 155.6 GWh
- Gas1.7% · 3.7 GWh
- Hydro5.9% · 13.1 GWh
- Wind3.4% · 7.6 GWh
- Solar (utility)8.3% · 18.5 GWh
- Solar (rooftop)7.5% · 16.8 GWh
- Battery2.4% · 5.4 GWh
- Other0.9% · 1.9 GWh
- Coal64.8% · 136.4 GWh
- Gas3.6% · 7.5 GWh
- Hydro2.3% · 4.8 GWh
- Wind8.2% · 17.2 GWh
- Solar (utility)8.9% · 18.8 GWh
- Solar (rooftop)9.3% · 19.5 GWh
- Battery2.8% · 6.0 GWh
- Other0.2% · 0.3 GWh
- Coal60.3% · 113.1 GWh
- Gas5.3% · 10.0 GWh
- Hydro8.0% · 15.0 GWh
- Wind13.9% · 26.1 GWh
- Solar (utility)3.7% · 6.9 GWh
- Solar (rooftop)6.5% · 12.3 GWh
- Battery2.3% · 4.3 GWh
- Gas53.8% · 20.1 GWh
- Wind19.4% · 7.2 GWh
- Solar (utility)5.9% · 2.2 GWh
- Solar (rooftop)17.2% · 6.4 GWh
- Battery3.6% · 1.3 GWh
- Gas0.5% · 0.2 GWh
- Hydro91.7% · 36.4 GWh
- Wind5.8% · 2.3 GWh
- Solar (rooftop)1.9% · 0.8 GWh
Renewables
- NSW 23.3%
- VIC 35.0%
- QLD 35.9%
- SA 39.9%
- TAS 116.1%
Interconnectors
| Region (proxy) | Net flow | Direction changes | Hours at limit |
|---|---|---|---|
| N-Q-MNSP1 | +43.6 GWh | 0 | — |
| NSW1-QLD1 | −53.8 GWh | 0 | — |
| VIC1-NSW1 | +19.2 GWh | 9 | — |
| V-SA | −10.0 GWh | 11 | — |
| T-V-MNSP1 | +6.3 GWh | 7 | — |
Per-region net of NETINTERCHANGE proxied to a representative interconnector. Full per-interconnector decomposition + hours-at-limit needs DINTERCONNECTOR parsing (follow-up).
Emissions
| NSW | 137.4k tCO₂ | 0.616 tCO₂/MWh |
| QLD | 121.3k tCO₂ | 0.568 tCO₂/MWh |
| SA | 9.5k tCO₂ | 0.250 tCO₂/MWh |
| VIC | 140.3k tCO₂ | 0.743 tCO₂/MWh |
| TAS | 141 tCO₂ | 0.004 tCO₂/MWh |