Commodity Demand — NSW1: Saturday 6 June 2026

$122.3/MWh at 7,602 MW — NSW spot price is elevated as demand climbs through what is shaping up as a classic winter evening ramp. The settlement period at 06:30 AEST (20:30 UTC) captures demand that has risen steadily from a trough of around 5,690 MW in the early hours, tracing a textbook winter diurnal curve. The price-demand relationship through the day has been tight: when demand peaked at approximately 9,647 MW around 17:40 AEST, prices held in the $107–$131/MWh band; as demand softened through the afternoon to roughly 6,900–7,100 MW, prices eased to $76–$89/MWh. The current 7,602 MW reading, still climbing at this interval, is already pushing the spot price back above $120/MWh — a clear signal that the dispatch stack is tightening as evening heating load builds in 8°C conditions with a heating demand index of 10.

Today's demand profile has moved through three distinct phases. Overnight troughed near 5,690 MW with prices dropping to $23.95/MWh and briefly sub-$14/MWh. The morning ramp from around 14:30 AEST (04:30 UTC) was steep, with demand lifting from 5,921 MW to the 9,300–9,650 MW plateau by 17:40 AEST, dragging prices from the low $40s to above $130/MWh at the 16:30 AEST peak interval. A notable softening through mid-afternoon — demand falling from the 9,600 MW range back toward 6,900 MW between roughly 20:00 and 01:00 AEST — saw prices compress to the $76–$92/MWh range. Demand is now rebuilding through the evening, and the current trajectory puts upward pressure on price as dispatchable capacity is progressively committed.

Forecast prices for the 07:00 AEST (21:00 UTC) interval have been revised sharply upward through the day — from $97–$100/MWh in earlier runs to $118.54/MWh in the most recent dispatch forecast — consistent with demand climbing back toward the 7,600–8,000 MW range as households activate heating. The 07:30 AEST (21:30 UTC) forecast sits at $118.64/MWh. Load window modelling shows prices softening to the $56–$92/MWh range from around 08:00 AEST (22:00 UTC) onwards as evening demand rolls off, with overnight troughs potentially as low as sub-$1/MWh in the 10:30–13:00 AEST window when demand bottoms out and battery and hydro dispatch economics shift. Sunday's lower commercial and industrial activity compared to a typical weekday is a moderating factor on daytime peak demand, though the cold minimum of 7.6°C and a low wind potential of 0.7 for the day will sustain residential heating load and limit any wind-driven supply response.

Generation at the current interval is led by black coal at 5,394 MW, hydro at 907 MW, and battery dispatch at 318 MW — the battery contribution is consistent with peak-period arbitrage execution. Wind sits at 83 MW and solar at just 25 MW, with cloud cover at 8%