Friday 19 June 2026
Trading day 2026-06-19
NEM prices soften as wind generation contributes over one quarter share
Regional average prices ranged from $39.80/MWh in Victoria to $58.60/MWh in New South Wales. Negative price intervals occurred in Queensland, South Australia, and Victoria, with each region recording seven such periods. South Australia saw the highest single price spike of the day at $91.60/MWh during the evening peak.
Demand peaked across most mainland regions between 17:35 and 18:25, with New South Wales reaching a maximum of 9,820 MW. Total energy consumption for the day was highest in New South Wales at 398.4 GWh. Tasmania recorded its peak demand of 1,361 MW much earlier at 08:00.
Coal remained the primary generation source at 48.2%, while wind provided 27.2% and combined solar reached 10.9%. Batteries discharged 9,636 MWh into the grid, though the sector remained a net consumer of 1,213 MWh. Hydro generation contributed a steady 7.0% to the total daily energy requirements.
FCAS costs were led by the Lower 6 Second service at $56,604, with peak pricing for lower services concentrated in Queensland. Interconnector flows showed significant movement from Victoria into New South Wales and from New South Wales into Queensland. Total daily emissions were recorded at 310,219 tonnes of CO2.
Today · Predispatch forecasts indicate a price peak of $319.04/MWh in Queensland at 19:30, while other regions expect peaks between $61.84/MWh and $145.00/MWh.
Why it matters · The daily average price of $40.20/MWh sits below the 7-day average of $45.65/MWh, breaking a two-day trend of rising prices. This price softening occurred despite a slight increase in emissions, as high wind penetration and battery activity offset the impact of evening demand peaks.
Prices
Trading day · 04:00 → 04:00 AEST · 30-min average
| Region | Avg | VWAP | Min | Max | Neg | Cap |
|---|---|---|---|---|---|---|
| NSW | $59 | $59 | $28 | $83 | 0 | 0 |
| QLD | $48 | $52 | -$7 | $81 | 7 | 0 |
| SA | $43 | $45 | -$3 | $92 | 7 | 0 |
| VIC | $40 | $41 | -$3 | $81 | 7 | 0 |
| TAS | $42 | $43 | $2 | $78 | 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 | $6,547 | 0 | $11 | 19 June, 14:10 |
| LOWERREG | $731 | 0 | $5 | 19 June, 19:10 |
| RAISE60SEC | $236 | 0 | $0 | 19 June, 17:30 |
| RAISE6SEC | $222 | 0 | $0 | 19 June, 07:55 |
| RAISE5MIN | $52 | 0 | $0 | 19 June, 15:20 |
| LOWER60SEC | $34 | 0 | $0 | 20 June, 02:15 |
| LOWER5MIN | $16 | 0 | $0 | 19 June, 06:35 |
| LOWER6SEC | $11 | 0 | $0 | 20 June, 02:15 |
| Total | $7,850 | |||
Cost = NSW RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| LOWER6SEC | $54,385 | 0 | $27 | 19 June, 13:35 |
| LOWER60SEC | $43,696 | 0 | $20 | 19 June, 13:50 |
| LOWER5MIN | $9,245 | 0 | $13 | 19 June, 14:55 |
| RAISEREG | $6,042 | 0 | $11 | 19 June, 14:10 |
| LOWERREG | $4,548 | 0 | $16 | 19 June, 14:20 |
| RAISE6SEC | $161 | 0 | $0 | 19 June, 15:40 |
| RAISE60SEC | $82 | 0 | $0 | 19 June, 15:40 |
| RAISE5MIN | $29 | 0 | $0 | 19 June, 15:20 |
| Total | $118,187 | |||
Cost = QLD RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $8,069 | 0 | $11 | 19 June, 14:10 |
| LOWERREG | $3,610 | 0 | $5 | 19 June, 19:10 |
| RAISE60SEC | $355 | 0 | $0 | 19 June, 17:30 |
| RAISE6SEC | $256 | 0 | $0 | 19 June, 07:55 |
| RAISE5MIN | $65 | 0 | $0 | 19 June, 15:20 |
| LOWER60SEC | $30 | 0 | $0 | 20 June, 02:15 |
| LOWER5MIN | $12 | 0 | $0 | 19 June, 06:35 |
| LOWER6SEC | $8 | 0 | $0 | 20 June, 02:15 |
| Total | $12,404 | |||
Cost = VIC RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $4,414 | 0 | $11 | 19 June, 14:10 |
| LOWERREG | $4,229 | 0 | $5 | 19 June, 19:10 |
| RAISE6SEC | $303 | 0 | $0 | 19 June, 07:55 |
| RAISE60SEC | $276 | 0 | $0 | 19 June, 17:30 |
| RAISE5MIN | $69 | 0 | $0 | 19 June, 15:20 |
| LOWER60SEC | $59 | 0 | $0 | 20 June, 02:15 |
| LOWER5MIN | $21 | 0 | $0 | 19 June, 06:35 |
| LOWER6SEC | $18 | 0 | $0 | 20 June, 02:15 |
| Total | $9,389 | |||
Cost = SA RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $8,055 | 0 | $5 | 19 June, 13:00 |
| LOWERREG | $4,764 | 0 | $33 | 19 June, 16:05 |
| RAISE6SEC | $4,175 | 0 | $13 | 19 June, 13:30 |
| RAISE60SEC | $3,468 | 0 | $3 | 19 June, 06:05 |
| LOWER6SEC | $2,183 | 0 | $3 | 19 June, 04:05 |
| LOWER60SEC | $1,142 | 0 | $0 | 19 June, 04:05 |
| RAISE5MIN | $319 | 0 | $0 | 19 June, 04:05 |
| LOWER5MIN | $22 | 0 | $0 | 19 June, 04:05 |
| Total | $24,128 | |||
Cost = TAS RRP × cleared MW per 5-min interval.
Battery dispatch
Peak moment
Fleet discharged 659 MW at 18:00 as NSW spot hit $75/MWh.
Peak moment
Fleet discharged 1,075 MW at 17:30 as QLD spot hit $76/MWh.
Peak moment
Fleet discharged 717 MW at 18:00 as VIC spot hit $75/MWh.
Peak moment
Fleet discharged 216 MW at 08:30 as SA spot hit $19/MWh.
Peak moment
Fleet discharged 2,524 MW at 18:00 as TAS spot hit $69/MWh.
Fleet net dispatch · spot-price overlay · 30-min average
Regional dispatch ranking
| Region | Discharged | Net |
|---|---|---|
#1QLD | 3,889MWh | -1,234 |
#2VIC | 2,553MWh | +927 |
#3NSW | 2,111MWh | -1,066 |
#4SA | 1,083MWh | +160 |
Generation Mix
- Coal59.3% · 116.0 GWh
- Gas3.2% · 6.3 GWh
- Hydro4.1% · 8.0 GWh
- Wind24.3% · 47.5 GWh
- Solar (utility)2.8% · 5.5 GWh
- Solar (rooftop)5.1% · 10.0 GWh
- Battery1.1% · 2.1 GWh
- Coal55.2% · 102.5 GWh
- Gas9.5% · 17.7 GWh
- Hydro1.9% · 3.6 GWh
- Wind11.0% · 20.3 GWh
- Solar (utility)8.1% · 15.0 GWh
- Solar (rooftop)12.2% · 22.6 GWh
- Battery2.1% · 3.9 GWh
- Coal49.4% · 88.2 GWh
- Gas2.2% · 3.9 GWh
- Hydro4.8% · 8.6 GWh
- Wind35.9% · 64.1 GWh
- Solar (utility)1.8% · 3.2 GWh
- Solar (rooftop)4.0% · 7.1 GWh
- Battery1.4% · 2.6 GWh
- Other0.5% · 0.9 GWh
- Gas10.3% · 4.8 GWh
- Wind75.3% · 35.3 GWh
- Solar (utility)3.2% · 1.5 GWh
- Solar (rooftop)8.5% · 4.0 GWh
- Battery2.3% · 1.1 GWh
- Other0.3% · 0.2 GWh
- Gas1.4% · 0.4 GWh
- Hydro78.9% · 24.3 GWh
- Wind18.6% · 5.7 GWh
- Solar (rooftop)1.1% · 0.3 GWh
Renewables
- NSW 33.3%
- VIC 52.8%
- QLD 37.7%
- SA 90.8%
- TAS 98.0%
Interconnectors
| Region (proxy) | Net flow | Direction changes | Hours at limit |
|---|---|---|---|
| N-Q-MNSP1 | +15.6 GWh | 13 | — |
| NSW1-QLD1 | −42.8 GWh | 2 | — |
| VIC1-NSW1 | +36.9 GWh | 2 | — |
| V-SA | −6.0 GWh | 15 | — |
| T-V-MNSP1 | +1.2 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 | 106.4k tCO₂ | 0.549 tCO₂/MWh |
| QLD | 96.5k tCO₂ | 0.524 tCO₂/MWh |
| SA | 2.4k tCO₂ | 0.051 tCO₂/MWh |
| VIC | 104.7k tCO₂ | 0.595 tCO₂/MWh |
| TAS | 287 tCO₂ | 0.010 tCO₂/MWh |