commodity demand tas — TAS1

Tasmania is currently priced at $112.76/MWh with demand sitting at 988.8 MW as of 16:30 AEST, tracking the morning ramp-up that began around 15:00 AEST from an overnight trough near 725–740 MW. The demand-price relationship over the past 24 hours is pronounced: when demand fell to its nadir around 01:30–02:10 AEST, prices briefly went negative at -$15/MWh as hydro and wind generation exceeded load, confirming a surplus dispatch condition at those volumes. The subsequent recovery in demand through the 15:00–16:30 AEST window — from ~820 MW to ~989 MW — has driven prices from the mid-$90s into the low-$110s, a ~$15–20/MWh lift on roughly 170 MW of demand growth.

The overnight and shoulder periods tell a clear story: demand below approximately 850 MW unlocks soft pricing in the $65–$90/MWh range, while sustained demand above 1,000 MW — seen through yesterday's morning peak of ~1,078 MW — consistently held prices in the $100–$126/MWh band. The sharpest price spikes (up to $126.18/MWh at 21:25 AEST yesterday) coincided with demand above 1,020 MW, pointing to a supply-side constraint or Basslink flow limitation activating higher-cost dispatch once that threshold is crossed.

Today's demand trajectory is upward. The current 988.8 MW is still short of the 1,020–1,080 MW range that generated elevated pricing yesterday morning, but with the standard weekday business ramp still progressing, demand is on track to test that zone within the next 1–2 hours. Forecasts provide no forward demand figures (all forecast_demand values are zero), limiting forward curve confidence, but the price forecast signal around $84/MWh for the overnight period (07:00–08:00 AEST) reflects the expected demand softening back toward the 800–850 MW trough typical of late evening. No market notices are active.

For demand-side managers, the window between roughly 07:00–13:00 AEST tonight — when demand historically drops below 800 MW and prices ease into the $75–$88/MWh range — represents the lowest-cost load opportunity of the day. The current 100% renewable generation mix (hydro 197 MW, wind 109 MW, gas OCGT offline) and 0 tCO2/MWh intensity hold across all historical carbon data, so load-shifting decisions carry no carbon penalty differential across time periods.