Commodity Demand — TAS1: Sunday 17 May 2026

Tasmania is sitting at 1,163 MW at $110.22/MWh at 06:35 AEST, with demand climbing steadily from the post-midnight trough of around 947 MW (06:00 AEST) as the Monday morning load-up accelerates. The trajectory through today's history is instructive: demand crested near 1,321 MW between 18:00–19:00 AEST during the morning peak, where spot prices consistently printed $126–$176/MWh, with isolated intervals reaching $197/MWh. That demand-price relationship is clear — every 100 MW step above 1,250 MW correlates with price premiums of $20–$80/MWh above the $96–$110/MWh base band that holds when demand sits below 1,200 MW. Current demand at 1,163 MW is still within the lower-pressure zone, but the rate of climb — up roughly 200 MW in the past 90 minutes — signals the evening peak is building.

The forward price outlook is materially more elevated than current spot. Forecasts for the 07:00–09:30 AEST half-hours (21:00–23:30 UTC) are converging in the $147–$164/MWh range, with the 08:00 AEST interval (22:00 UTC) carrying forecast prices of $172–$254/MWh across successive forecast runs — a wide band that reflects genuine dispatch uncertainty as demand approaches the 1,200–1,300 MW zone. The 08:30–10:00 AEST window (00:30–02:00 AEST Tuesday) sees forecasts reaching $199–$277/MWh, consistent with Tasmania's typical evening residential and heating demand peak under tonight's overcast 12.9°C conditions and near-zero wind potential. Today's weather profile — 100% cloud cover, heating demand index at 5.1, and wind potential at zero — removes any relief from variable generation: hydro at 1,251 MW and gas OCGT at 58 MW are carrying the load, with wind contributing only 16 MW.

The key price risk today centres on whether demand clears 1,300 MW during the 07:30–09:30 AEST window. The data from this morning's equivalent period shows that sustained demand above 1,300 MW triggered the most volatile pricing of the day — $136–$188/MWh with isolated spikes to $197/MWh — and the evening peak under heating load typically matches or exceeds morning peak levels. The gas OCGT dispatch (58 MW currently) is already active, indicating the hydro stack is approaching its economic dispatch ceiling; any further demand lift will pressure marginal costs upward and is consistent with the $200+ forecasts sitting in the dispatch queue for the 08:00–10:00 AEST period. Demand-side managers with flexible load above 1 MW should treat the 07:00–10:00 AEST window as high-risk for contract exposure.

There are no Tasmania-specific market notices in force, but the active Forecast LOR1 in Queensland today (17:00–19:00 AEST, minimum reserve 1,014 MW against a requirement of 1,194 MW) introduces a broader NEM interconnector risk. Basslink flows between Tasmania and Victoria can shift depending on Victorian and Queensland dispatch pressures; if mainland stress pulls Tasmanian exports higher this evening,