TAS1 experienced high renewable penetration at 86.6% during the early morning period of 5 September 2026, with wind and hydro generation combined accounting for approximately 803–867 MW of output. Regional pricing exhibited significant volatility, ranging from negative values (−$0.14/MWh) to elevated levels ($22.30–$22.33/MWh), reflecting rapid swings in system conditions over the ten-minute window.
The renewable-driven generation mix and price volatility were constrained by binding constraint F_T+RREG_0050, which carried a persistent marginal value of $5.44/MWh across four settlement intervals, indicating a systemic limitation on renewable export or system stability. A secondary binding constraint F_TASCAP_RREG_0220 with a marginal value of $4.99/MWh also acted during the period, suggesting multiple constraints were limiting the system's ability to absorb or dispatch the high renewable output, resulting in price spikes particularly evident at 06:55–07:00 as fossil-fuel capacity (GAS_OCGT at ~124 MW) became relatively scarce and constraint-driven scarcity pricing emerged.
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.