TAS1 experienced sustained negative pricing at –$0.58/MWh across two consecutive intervals (14:10 and 14:15 on 12 September 2026), following a period of near-zero pricing. The region's generation mix comprised primarily hydro (353–394 MW), wind (199–210 MW), and gas-fired generation (124–125 MW), with minimal demand absorption.
The negative pricing was driven by a binding constraint (F_T+LREG_0050) with marginal values between $10.68–$11.26/MWh, indicating a transmission or operational limit that forced dispatch of lower-merit generation or restricted export capability. High renewable output (hydro and wind totalling ~562–768 MW) combined with this binding constraint likely created excess generation that could not be economically cleared within regional boundaries, necessitating negative pricing to incentivise consumption or reduce output.
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.