VIC1 experienced sustained negative pricing at −$2.99/MWh across two consecutive intervals (02:15–02:20 on 16 August 2026), following a rapid price decline from $1.01/MWh. The region had high renewable generation (1,450 MW combined wind and solar) alongside substantial brown coal output (3,440 MW), creating supply surplus conditions.
The negative pricing reflects excess generation relative to regional demand during a low-demand overnight period. Multiple binding constraints with positive marginal values (ranging from $3.35 to $3.44) indicate that physical network or system strength limitations prevented efficient dispatch of surplus renewable and thermal generation, forcing generators to accept negative prices to remain online. The high proportion of must-run thermal capacity (brown coal) combined with variable renewable output and constrained export capability likely created downward pressure on prices.
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.