Monday 14 September 2026
Trading day 2026-09-14
Renewable share nears seventy-three percent as regional prices remain below fifty-five dollars
Average regional prices ranged from thirty-nine dollars and ninety cents in Victoria to fifty-two dollars and sixty cents in New South Wales. Queensland and New South Wales recorded significant negative price intervals during daylight hours while South Australia and Victoria avoided sub-zero pricing. Tasmania saw the highest price volatility with a maximum spot price of two hundred and thirteen dollars and ten cents.
Demand peaked across the mainland between 18:05 and 19:05 with New South Wales reaching eight thousand eight hundred and one megawatts. Total energy consumption for the day was highest in New South Wales at three hundred and thirty-one gigawatt hours. Coal provided forty-seven percent of the generation mix while combined solar and wind contributed nearly forty-two percent of total output.
Renewable generation reached an instantaneous peak of seventy-two point nine percent at 11:50 during the midday solar window. Batteries dispatched nineteen thousand six hundred and fifty-eight megawatt hours with a net positive discharge of four hundred and twenty-four megawatt hours. Tasmania dominated FCAS costs with multiple services peaking at the market cap during brief intervals.
Interconnector flows showed significant movement from Victoria into New South Wales and from Queensland into New South Wales via the Directlink. Total system emissions were two hundred and eighty-six thousand nine hundred and fifty-three tonnes of carbon dioxide. Hydro generation remained a minor contributor at five point one percent of the total NEM generation mix.
Today · Forecasts indicate a peak price of three hundred and nineteen dollars in Queensland at 19:30 tonight.
Why it matters · The daily average of forty-seven dollars sits four percent below the seven-day average, extending a period of moderate pricing despite high demand peaks. This stability occurred as a high renewable share and significant battery discharge offset the impact of extreme FCAS volatility in the Tasmanian region.
Prices
Trading day · 04:00 → 04:00 AEST · 30-min average
| Region | Avg | VWAP | Min | Max | Neg | Cap |
|---|---|---|---|---|---|---|
| NSW | $53 | $54 | -$9 | $85 | 24 | 0 |
| QLD | $40 | $45 | -$9 | $82 | 64 | 0 |
| SA | $50 | $51 | $5 | $156 | 0 | 0 |
| VIC | $40 | $42 | $0 | $157 | 0 | 0 |
| TAS | $43 | $45 | -$59 | $213 | 4 | 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 | $2,381 | 0 | $16 | 14 Sept, 16:35 |
| LOWER5MIN | $848 | 0 | $10 | 14 Sept, 15:50 |
| LOWERREG | $694 | 0 | $10 | 14 Sept, 16:15 |
| LOWER60SEC | $176 | 0 | $2 | 14 Sept, 15:55 |
| RAISE6SEC | $124 | 0 | $0 | 14 Sept, 06:25 |
| RAISE60SEC | $116 | 0 | $0 | 14 Sept, 07:40 |
| LOWER6SEC | $80 | 0 | $1 | 14 Sept, 14:40 |
| RAISE5MIN | $36 | 0 | $0 | 14 Sept, 05:55 |
| Total | $4,455 | |||
Cost = NSW RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $7,705 | 0 | $16 | 14 Sept, 16:35 |
| LOWERREG | $6,022 | 0 | $10 | 14 Sept, 16:15 |
| LOWER5MIN | $1,211 | 0 | $10 | 14 Sept, 15:50 |
| LOWER60SEC | $492 | 0 | $2 | 14 Sept, 15:55 |
| RAISE6SEC | $324 | 0 | $0 | 14 Sept, 06:25 |
| RAISE60SEC | $257 | 0 | $0 | 14 Sept, 07:40 |
| LOWER6SEC | $178 | 0 | $1 | 14 Sept, 14:40 |
| RAISE5MIN | $46 | 0 | $0 | 14 Sept, 05:55 |
| Total | $16,235 | |||
Cost = QLD RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $7,848 | 0 | $16 | 14 Sept, 16:35 |
| LOWERREG | $3,148 | 0 | $10 | 14 Sept, 16:15 |
| LOWER5MIN | $1,413 | 0 | $10 | 14 Sept, 15:50 |
| LOWER60SEC | $613 | 0 | $2 | 14 Sept, 15:55 |
| RAISE6SEC | $225 | 0 | $0 | 14 Sept, 06:25 |
| RAISE60SEC | $222 | 0 | $0 | 14 Sept, 07:40 |
| LOWER6SEC | $158 | 0 | $1 | 14 Sept, 14:40 |
| RAISE5MIN | $72 | 0 | $0 | 14 Sept, 05:55 |
| Total | $13,698 | |||
Cost = VIC RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| LOWERREG | $4,634 | 0 | $10 | 14 Sept, 16:15 |
| RAISEREG | $2,915 | 0 | $16 | 14 Sept, 16:35 |
| RAISE60SEC | $1,585 | 0 | $5 | 14 Sept, 05:20 |
| RAISE6SEC | $1,548 | 0 | $5 | 14 Sept, 05:45 |
| LOWER5MIN | $1,375 | 0 | $10 | 14 Sept, 15:50 |
| LOWER60SEC | $657 | 0 | $2 | 14 Sept, 15:55 |
| LOWER6SEC | $651 | 0 | $2 | 14 Sept, 21:25 |
| RAISE5MIN | $152 | 0 | $0 | 15 Sept, 03:10 |
| Total | $13,517 | |||
Cost = SA RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| LOWER6SEC | $963,317 | 6 | $23,200 | 14 Sept, 14:40 |
| RAISE6SEC | $412,900 | 2 | $23,190 | 14 Sept, 14:40 |
| LOWERREG | $209,376 | 2 | $23,200 | 14 Sept, 14:40 |
| RAISEREG | $206,545 | 2 | $23,200 | 14 Sept, 14:40 |
| RAISE60SEC | $1,682 | 0 | $3 | 14 Sept, 14:40 |
| LOWER60SEC | $408 | 0 | $1 | 14 Sept, 13:15 |
| LOWER5MIN | $179 | 0 | $2 | 14 Sept, 16:30 |
| RAISE5MIN | $160 | 0 | $0 | 14 Sept, 05:35 |
| Total | $1.79M | |||
Cost = TAS RRP × cleared MW per 5-min interval.
Battery dispatch
Peak moment
Fleet discharged 1,408 MW at 18:00 as NSW spot hit $72/MWh.
Peak moment
Fleet discharged 1,444 MW at 18:30 as QLD spot hit $76/MWh.
Peak moment
Fleet discharged 895 MW at 07:00 as VIC spot hit $46/MWh.
Peak moment
Fleet discharged 201 MW at 22:00 as SA spot hit $50/MWh.
Peak moment
Fleet discharged 3,720 MW at 18:30 as TAS spot hit $57/MWh.
Fleet net dispatch · spot-price overlay · 30-min average
Regional dispatch ranking
| Region | Discharged | Net |
|---|---|---|
#1NSW | 7,095MWh | -605 |
#2VIC | 5,608MWh | +1,781 |
#3QLD | 5,237MWh | -993 |
#4SA | 1,717MWh | +241 |
Generation Mix
- Coal50.9% · 100.7 GWh
- Gas0.6% · 1.2 GWh
- Hydro2.4% · 4.8 GWh
- Wind12.2% · 24.1 GWh
- Solar (utility)13.9% · 27.5 GWh
- Solar (rooftop)16.3% · 32.2 GWh
- Battery3.6% · 7.1 GWh
- Other0.2% · 0.4 GWh
- Coal50.7% · 96.6 GWh
- Gas1.8% · 3.5 GWh
- Hydro1.8% · 3.5 GWh
- Wind11.1% · 21.2 GWh
- Solar (utility)14.2% · 27.0 GWh
- Solar (rooftop)17.5% · 33.4 GWh
- Battery2.8% · 5.2 GWh
- Coal59.0% · 90.9 GWh
- Gas0.1% · 0.2 GWh
- Hydro2.8% · 4.3 GWh
- Wind20.9% · 32.2 GWh
- Solar (utility)3.3% · 5.1 GWh
- Solar (rooftop)9.0% · 13.9 GWh
- Battery3.6% · 5.6 GWh
- Other1.2% · 1.8 GWh
- Gas17.3% · 6.2 GWh
- Wind48.4% · 17.5 GWh
- Solar (utility)8.3% · 3.0 GWh
- Solar (rooftop)20.5% · 7.4 GWh
- Battery4.8% · 1.7 GWh
- Other0.7% · 0.2 GWh
- Gas10.3% · 3.3 GWh
- Hydro58.3% · 18.5 GWh
- Wind26.8% · 8.5 GWh
- Solar (rooftop)4.6% · 1.4 GWh
Renewables
- NSW 43.9%
- VIC 42.6%
- QLD 50.9%
- SA 72.9%
- TAS 106.0%
Interconnectors
| Region (proxy) | Net flow | Direction changes | Hours at limit |
|---|---|---|---|
| N-Q-MNSP1 | +18.7 GWh | 16 | — |
| NSW1-QLD1 | −33.4 GWh | 6 | — |
| VIC1-NSW1 | +17.4 GWh | 12 | — |
| V-SA | −7.3 GWh | 14 | — |
| T-V-MNSP1 | +8.5 GWh | 12 | — |
Per-region net of NETINTERCHANGE proxied to a representative interconnector. Full per-interconnector decomposition + hours-at-limit needs DINTERCONNECTOR parsing (follow-up).
Emissions
| NSW | 87.8k tCO₂ | 0.433 tCO₂/MWh |
| QLD | 86.6k tCO₂ | 0.447 tCO₂/MWh |
| SA | 3.1k tCO₂ | 0.084 tCO₂/MWh |
| VIC | 107.5k tCO₂ | 0.694 tCO₂/MWh |
| TAS | 2.0k tCO₂ | 0.063 tCO₂/MWh |