VIC1 experienced sustained negative pricing at $−0.05/MWh across two consecutive intervals (15:30–15:35 on 11 June 2026), with prices oscillating near zero throughout the broader period. The region had substantial wind generation (approximately 4,976 MW combined) and brown coal (3,694 MW), creating a supply-surplus environment that suppressed wholesale prices.
The negative pricing reflects typical oversupply conditions driven by high renewable generation during the afternoon period, insufficient local demand absorption, and the need to maintain system stability. Multiple binding constraints with marginal values ranging from $3.32 to $7.08/MWh indicate that network or system security limitations (rather than demand-side factors) were constraining dispatch and preventing generators from reducing output, forcing continued generation into a saturated market and pushing prices into negative territory.
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.