Saturday 14 November 2026
Trading day 2026-11-14
SA records 12.8 hours of negative prices as NEM average reaches $109.2/MWh
NSW recorded the highest regional average at $138.1/MWh, reaching a maximum of $230.6/MWh at 16:30. SA recorded the lowest average at $87.8/MWh, reaching a minimum of -$148.4/MWh at 12:25. AEMO issued a notice at 12:20 stating prices for the 12:25 interval were subject to review. SA experienced negative prices for 53.5 per cent of the day, while VIC and TAS both recorded 3.7 hours.
NSW recorded the highest demand peak of 9172 MW at 17:05, while QLD reached 7726 MW at 18:55. The NEM renewable share averaged 42.7 per cent, reaching an instantaneous peak of 64.8 per cent at 12:30. Coal contributed 49.9 per cent of the generation mix, followed by rooftop solar at 14.5 per cent and wind at 11.3 per cent. Batteries discharged 17,511 MWh with a net of -4224 MWh across the trading day.
FCAS costs were highest for the raise regulation service at $49,934, with no price spikes recorded. Total emissions were 310,059 tCO2, which was 22.4 per cent above the same weekday last week.
AEMO issued a notice at 05:50 cancelling a forecast LOR2 in TAS for 20 November, and updated a forecast LOR1 at 14:34. AEMO issued multiple notices between 12:00 and 13:55 stating prices were subject to review.
Today · Pre-dispatch forecasts show SA reaching $527.17/MWh at 19:00, with NSW and QLD exceeding $298/MWh at the same time. AEMO projects an LOR1 in TAS from 08:00 on 20 November.
In context · The NEM average of $109.2/MWh was above the 7-day average of $92.8/MWh, ranking third for the week. The NEM average was higher than the $50.0/MWh recorded on the same weekday last week.
Prices
Trading day · 04:00 → 04:00 AEST · 30-min average
| Region | Avg | VWAP | Min | Max | Neg | Cap |
|---|---|---|---|---|---|---|
| NSW | $138 | $140 | $24 | $231 | 0 | 0 |
| QLD | $130 | $131 | $41 | $186 | 0 | 0 |
| SA | $88 | $110 | -$148 | $262 | 154 | 0 |
| VIC | $94 | $98 | -$60 | $217 | 44 | 0 |
| TAS | $93 | $95 | -$46 | $199 | 44 | 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 | $5,019 | 0 | $20 | 15 Nov, 01:45 |
| LOWERREG | $909 | 0 | $5 | 14 Nov, 06:55 |
| RAISE6SEC | $304 | 0 | $0 | 14 Nov, 07:10 |
| RAISE60SEC | $244 | 0 | $0 | 14 Nov, 08:55 |
| LOWER60SEC | $93 | 0 | $0 | 14 Nov, 14:55 |
| RAISE5MIN | $91 | 0 | $0 | 14 Nov, 05:45 |
| LOWER6SEC | $40 | 0 | $0 | 14 Nov, 15:15 |
| LOWER5MIN | $27 | 0 | $0 | 14 Nov, 16:35 |
| Total | $6,727 | |||
Cost = NSW RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $5,700 | 0 | $20 | 15 Nov, 01:45 |
| LOWERREG | $4,362 | 0 | $5 | 14 Nov, 06:55 |
| LOWER6SEC | $1,018 | 0 | $5 | 14 Nov, 11:15 |
| LOWER60SEC | $1,013 | 0 | $3 | 14 Nov, 11:00 |
| RAISE6SEC | $430 | 0 | $0 | 14 Nov, 07:10 |
| RAISE60SEC | $309 | 0 | $0 | 14 Nov, 12:40 |
| RAISE5MIN | $86 | 0 | $0 | 14 Nov, 12:40 |
| LOWER5MIN | $71 | 0 | $0 | 14 Nov, 16:35 |
| Total | $12,989 | |||
Cost = QLD RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $6,428 | 0 | $20 | 15 Nov, 01:45 |
| LOWERREG | $606 | 0 | $5 | 14 Nov, 06:55 |
| RAISE6SEC | $518 | 0 | $0 | 14 Nov, 07:10 |
| RAISE60SEC | $429 | 0 | $0 | 14 Nov, 08:55 |
| RAISE5MIN | $150 | 0 | $0 | 14 Nov, 05:45 |
| LOWER60SEC | $65 | 0 | $0 | 14 Nov, 14:55 |
| LOWER6SEC | $33 | 0 | $0 | 14 Nov, 15:15 |
| LOWER5MIN | $16 | 0 | $0 | 14 Nov, 16:35 |
| Total | $8,245 | |||
Cost = VIC RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $8,090 | 0 | $20 | 15 Nov, 01:45 |
| LOWERREG | $3,661 | 0 | $5 | 14 Nov, 06:55 |
| RAISE6SEC | $721 | 0 | $0 | 14 Nov, 07:10 |
| RAISE60SEC | $523 | 0 | $0 | 14 Nov, 08:55 |
| RAISE5MIN | $154 | 0 | $0 | 14 Nov, 05:45 |
| LOWER60SEC | $151 | 0 | $0 | 14 Nov, 14:55 |
| LOWER6SEC | $85 | 0 | $0 | 14 Nov, 15:15 |
| LOWER5MIN | $47 | 0 | $0 | 14 Nov, 16:35 |
| Total | $13,433 | |||
Cost = SA RRP × cleared MW per 5-min interval.
| Service | Cost | Spikes | Peak | When |
|---|---|---|---|---|
| RAISEREG | $24,697 | 0 | $79 | 15 Nov, 03:15 |
| LOWERREG | $5,250 | 0 | $8 | 14 Nov, 15:05 |
| RAISE6SEC | $3,734 | 0 | $71 | 14 Nov, 19:40 |
| RAISE60SEC | $538 | 0 | $0 | 14 Nov, 05:25 |
| LOWER6SEC | $273 | 0 | $3 | 14 Nov, 19:30 |
| LOWER60SEC | $173 | 0 | $3 | 14 Nov, 19:30 |
| LOWER5MIN | $17 | 0 | $1 | 14 Nov, 19:30 |
| RAISE5MIN | $13 | 0 | $0 | 14 Nov, 06:35 |
| Total | $34,695 | |||
Cost = TAS RRP × cleared MW per 5-min interval.
Battery dispatch
Peak moment
Fleet discharged 1,496 MW at 19:30 as NSW spot hit $157/MWh.
Peak moment
Fleet discharged 1,160 MW at 19:00 as QLD spot hit $152/MWh.
Peak moment
Fleet discharged 741 MW at 00:30 as VIC spot hit $136/MWh.
Peak moment
Fleet discharged 217 MW at 06:30 as SA spot hit $162/MWh.
Peak moment
Fleet discharged 3,082 MW at 20:30 as TAS spot hit $122/MWh.
Fleet net dispatch · spot-price overlay · 30-min average
Regional dispatch ranking
| Region | Discharged | Net |
|---|---|---|
#1NSW | 7,018MWh | -1,904 |
#2QLD | 5,091MWh | -649 |
#3VIC | 3,837MWh | -1,124 |
#4SA | 1,564MWh | -547 |
Generation Mix
- Coal47.2% · 100.6 GWh
- Gas5.0% · 10.7 GWh
- Hydro6.6% · 14.1 GWh
- Wind7.4% · 15.7 GWh
- Solar (utility)13.1% · 27.9 GWh
- Solar (rooftop)17.4% · 37.1 GWh
- Battery3.3% · 7.0 GWh
- Coal65.2% · 134.4 GWh
- Gas2.7% · 5.5 GWh
- Hydro3.6% · 7.4 GWh
- Wind5.3% · 10.9 GWh
- Solar (utility)9.3% · 19.1 GWh
- Solar (rooftop)11.4% · 23.5 GWh
- Battery2.5% · 5.1 GWh
- Other0.1% · 0.2 GWh
- Coal52.4% · 77.3 GWh
- Gas2.3% · 3.4 GWh
- Hydro2.7% · 4.0 GWh
- Wind20.1% · 29.6 GWh
- Solar (utility)7.7% · 11.3 GWh
- Solar (rooftop)12.2% · 18.0 GWh
- Battery2.6% · 3.8 GWh
- Gas31.2% · 10.5 GWh
- Wind29.3% · 9.8 GWh
- Solar (utility)4.0% · 1.3 GWh
- Solar (rooftop)30.9% · 10.4 GWh
- Battery4.7% · 1.6 GWh
- Hydro73.7% · 18.7 GWh
- Wind19.4% · 4.9 GWh
- Solar (rooftop)6.9% · 1.8 GWh
Renewables
- NSW 44.0%
- VIC 47.8%
- QLD 35.0%
- SA 61.5%
- TAS 96.0%
Interconnectors
| Region (proxy) | Net flow | Direction changes | Hours at limit |
|---|---|---|---|
| N-Q-MNSP1 | +20.9 GWh | 4 | — |
| NSW1-QLD1 | −21.7 GWh | 20 | — |
| VIC1-NSW1 | +13.9 GWh | 16 | — |
| V-SA | −7.9 GWh | 19 | — |
| T-V-MNSP1 | −2.4 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 | 93.1k tCO₂ | 0.428 tCO₂/MWh |
| QLD | 120.2k tCO₂ | 0.577 tCO₂/MWh |
| SA | 4.9k tCO₂ | 0.144 tCO₂/MWh |
| VIC | 91.9k tCO₂ | 0.618 tCO₂/MWh |
| TAS | 0 tCO₂ | 0.000 tCO₂/MWh |