Australia’s highest- and lowest-intensity power stations, FY2024-25

Headline numbers

For FY2024-25, NGER facilities connected to the National Electricity Market reported 122.9 Mt CO₂e of scope 1 emissions against 194.0 TWh of electricity production — an average emission intensity of 0.634 tCO₂e/MWh. That is down from 0.655 in FY2023-24 — a 3.2 per cent fall, driven entirely by higher output rather than absolute emissions reductions: scope 1 totals were essentially flat year-on-year (123.1 Mt → 122.9 Mt), while NEM production grew by 6.1 TWh.

Western Australia's WEM is steadier. The 46 reporting WEM facilities produced 18.7 TWh and emitted 11.0 Mt CO₂e in FY2024-25 — an intensity of 0.589 tCO₂e/MWh, essentially unchanged from 0.594 the prior year. The WEM's coal-heavy fleet (Muja, Collie, Bluewaters) continues to set the floor.

The fuel-by-fuel picture

Aggregating reported facility data by primary fuel and weighting by production gives a cleaner view than the all-of-grid average. Three of the 411 NEM facilities — all Victorian brown coal — emitted at more than 1.2 tCO₂e/MWh. Sixteen black coal facilities sit between 0.88 and 1.0. Gas-fired generation across CCGT, OCGT, and peaking units averaged 0.57. Wind, solar, and hydro report essentially zero scope 1 intensity at the meter — combustion-free generation produces no on-site fuel emissions.

Ten highest-emission-intensity facilities

Filtered to facilities producing more than 500 GWh in FY2024-25, every entry in the top ten is coal-fired. Victorian brown coal occupies the top three slots; the remainder are black-coal stations across NSW, QLD, and WA.

Ten lowest-emission-intensity facilities

Filtered to facilities producing more than 500 GWh, every entry in the top ten by production with sub-0.01 reported scope 1 intensity is wind, solar, or hydro. Coopers Gap (QLD, wind) and Gordon Hydro (TAS) top the list at more than 1 TWh of combustion-free generation.

Year-on-year movers

At the facility level, FY2024-25 intensities are remarkably stable against FY2023-24. Filtering to facilities producing more than 1 TWh both years, only two showed material intensity moves: Yallourn (VIC, brown coal) climbed from 1.292 to 1.350 — consistent with a fleet that is running fewer hours per unit ahead of its scheduled retirement, with fixed maintenance loads dragging on per-MWh efficiency. Alinta's Pinjarra cogeneration facility (WA, gas) improved from 0.784 to 0.720.

The bigger picture: NEM-wide intensity is falling because output is growing on the renewable side, not because the coal fleet is materially less intensive year-on-year. That is precisely the dynamic the AEMO Integrated System Plan models — and it is the one a time-matched scope 2 calculation captures that an annual average will not.

How to use the full dataset

gridIQ surfaces the complete FY2024-25 NGER register, along with the prior year, at /emissions-directory. Browse by facility, fuel, state, or grid; download the table; cross-link from a dispatchable unit (DUID) to its parent reporting entity via the generator directory. If you have a contracted generator or a PPA off-taker, look up its FY24-25 intensity and capacity factor in one place.

For Scope 2 reporting under AASB S2 / ASRS, the annual register here is the starting point — but it is not enough on its own. A reporting entity that operates across the day will see materially different location-based and market-based numbers depending on when consumption occurred. gridIQ computes both methods on time-matched 30-minute intervals using the live AEMO generation mix and DCCEEW factor versions.

Source: Clean Energy Regulator NGER publication, effective February 2026 (FY2024-25 reporting period). Intensity figures are scope 1 emissions divided by electricity production for each facility as reported. Facilities producing under 500 GWh are excluded from the top-ten tables to focus on grid-scale generation.