A firm VIC-NSW interconnector flow (714 MW, sitting at its export limit) was the defining feature overnight, dragging NSW1 prices down while VIC1 traded as low as $12.50/MWh against NSW1's $90/MWh. A high-value NEM-wide binding constraint (F_T+NIL_ML_RECL_L6, shadow price $2,944/MWh) restricted dispatch flexibility for part of the period, and QLD1 briefly printed negative prices (−$3.73/MWh) around 23:00 UTC amid strong solar and steady coal output. Demand has eased from yesterday's evening peaks across most regions heading into today; watch NSW1 and QLD1 through the morning ramp for any repeat tightening.
Tasmania was the standout region overnight: a $8.352 million shadow price binding constraint (T_BLINK_TV_NGZ) held through multiple settlement intervals while the region ran on 100% renewable generation (hydro plus wind, no gas online). Prices still moved sharply within this constrained, all-renewable environment, spiking from $30/MWh to $90/MWh in one interval and again from $36/MWh to $60/MWh in another — a reminder that low-emissions supply doesn't remove price volatility. SA1 also saw a moderate spike to $376/MWh for two intervals before easing back to $130/MWh.
WA1 recorded the highest average price of any region over the past 24 hours at $103/MWh, with a peak of $132/MWh. No specific WEM events were flagged in today's data beyond these top-line figures.
No LOR conditions are forecast across the NEM in the next 48 hours. East coast gas hub prices eased slightly day-on-day, with STTM Sydney at $10.99/GJ (down from $11.19/GJ) and STTM Brisbane at $11/GJ (down from $11.41/GJ); STTM Adelaide sits at $10.66/GJ. LGC prices continue their gradual climb, reaching $8.50 for the week ending 14 August, up from $5.85 four weeks earlier.