VIC1 experienced sustained negative pricing over three intervals (05:15–05:25 on 8 August 2026), with prices bottoming at −$6.50/MWh during the earlier part of the event window before moderating to around −$0.10/MWh. The negative pricing occurred during a period of high renewable generation (approximately 5,656 MW of wind and solar output) combined with significant brown coal generation (2,555 MW), indicating an oversupply situation.
The binding constraints in the region, particularly those with marginal values between $3.46 and $6.80/MWh, indicate that transmission or service capability limits were actively constraining dispatch, forcing down the marginal price as generation had to be curtailed or repositioned. High concurrent wind and solar output during off-peak hours (05:00–05:35) created an excess generation scenario that, when coupled with these binding constraint limits on export or service delivery, drove prices negative as generators competed to remain online and avoid shutdown costs.
Causal analysis generated by gridIQ's synthesis model from live AEMO market data: dispatch prices, generation mix, interconnector flows and market notices in the interval surrounding the event.