Commodity Demand — TAS1: Wednesday 10 June 2026

Tasmania's spot price is at $153.51/MWh with demand sitting at 1,280 MW as of 06:30 AEST — a sharp escalation from the $80.20/MWh floor that anchored prices through the overnight trough when demand bottomed near 1,010 MW around 02:15–03:00 AEST. The price-demand relationship is clear in today's data: every sustained push above 1,250 MW correlates with prices breaking above $100/MWh, and the current trajectory is tracking that threshold with demand rising 185 MW in the 90 minutes since 05:00 AEST. The evening ramp is well underway at 6°C ambient with a heating demand index of 11.9, and there is no solar contribution to offset it.

The forecast profile is the key trading signal. Prices are expected to peak at $200.24/MWh at the 08:30 AEST half-hour, with $148–$200/MWh forecast across the 08:00–09:00 AEST window — the period that aligns with Tasmania's typical winter morning demand peak. A secondary elevation is forecast at 18:00–18:30 AEST with prices reaching $158.51–$176.95/MWh, consistent with the evening heating load. Between these peaks, the mid-morning and early afternoon periods see prices forecast to ease back toward $87.24/MWh as demand softens from its winter morning apex, mirroring the pattern observed earlier today where demand pulled back from 1,342 MW at 18:00 AEST to a 1,010 MW trough across the mid-afternoon.

An active AEMO market notice (144236) flags that constraint set F-I_ML_APD_LOAD is invoked following a short-notice outage of the APD A2 500/220 kV transformer in Victoria, with the Basslink interconnector (T-V-MNSP1) named on the left-hand side. This is a material factor for Tasmania's price outlook: any binding constraint on Basslink export capacity tightens the effective supply stack available to manage peak demand, amplifying price sensitivity at high-demand intervals. Traders should treat the $200/MWh forecast for the 08:30 AEST period as credible given this network context.

Generation is currently 1,448 MW hydro, 103 MW wind, and 58 MW gas OCGT, with total output running well above local demand — the surplus is directed to interconnector flows. As demand climbs through the morning peak toward what the history suggests could reach 1,320–1,350 MW, the OCGT remains in dispatch and the price floor lifts accordingly. The optimal demand window for flexible loads is the 01:30–05:00 AEST corridor tonight (Thursday into Friday), where prices are forecast at $87.24/MWh, before the Friday morning peak reprices above $100/MWh from 06:00 AEST onward.