Braemar 2 Power Station (BRAEMAR7)

Coal · NewGen Braemar 2 Partnership comprising Arrow Braemar 2 Pty Ltd and Arrow Southern Generation Pty Ltd · Turbine - OCGT

Dispatch stats Financials
In Service QLD1 Fossil - Coal Seam Methane NEM data · 24 hours
173 MW
Registered nameplate capacity
24 hours revenue
$0
Capacity factor
0.0%
Revenue / MWh
—
Est. SRMC
$132.25/MWh
MLF
0.9667

Stats window 29 May 2026 04:00 → 30 May 2026 04:00 AEST

Key information
Capacity
173 MW
Status In Service
Lifecycle Operating
Region QLD1
DUID BRAEMAR7
Owner NewGen Braemar 2 Partnership comprising Arrow Braemar 2 Pty Ltd and Arrow Southern Generation Pty Ltd
Commissioned —
Expected closure 2025-07-02
Closure date —
Technology Turbine - OCGT
Fuel Fossil - Coal Seam Methane

Dispatch & revenue

29 May 2026 04:00 → 30 May 2026 04:00 AEST

Revenue (× MLF)
$0
Dispatched
— MWh
Available
3,750.0 MWh
Curtailed
3,750.0 MWh
Curtailment
100.0%
of available
MLF used
0.9667
end of period

Energy flow

Dispatch target (cleared) vs availability — 5‑minute intervals. QLD1 regional price (RRP) on right axis.

Revenue (× MLF)

Estimated $ per interval using regional RRP and MLF effective on each day.

Methodology & assumptions

  • Dispatch & availability — AEMO Next Day Dispatch UNIT_SOLUTION (5‑minute intervals). Intervention intervals excluded.
  • Regional price — dispatch_price RRP matched by settlement time and NEM region (from generator registry).
  • Revenue (× MLF) — cleared MW × (5/60 h) × RRP × MLF. Chart uses MLF effective on each interval’s date; summary total uses MLF as at the end of the selected period (same as the revenue list).
  • Curtailment — estimated economic curtailment when availability exceeds dispatch target: max(0, availability − cleared) × (5/60) MWh.
  • Not settlement — estimates only. AEMO settlement applies DLF, rebids, constraints, and other factors not modelled here.
MLF history (AEMO daily)
Effective fromMLF
2024-07-01 0.9627
2025-07-01 0.9667

Financial overview

2026 real AUD. Monetary values are CPI-adjusted to 2026 real Australian dollars. Greenfield capex uses AEMO benchmarks when plant-specific cost is unknown.
Type
OCGT
Capacity
173 MW
Revenue (× MLF) (stats)
See dispatch stats link above
Est. SRMC
$132.25/MWh
Capex total (greenfield)
$869.43M

Source value
$546.00M (2008 nominal)

How this was derived
Reported estimate for the Braemar 2 project cost in 2008.

Reference
Abstract: Arrow, ERM Form Braemar 2 Power Station Partnership (medium confidence)
Capex refurbishment
—
Capex / MW
$5,025,588

Source value
$3.16M (2008 nominal)
Capex / MWh storage
—
Fixed OPEX (annual)
$17.78M

Source value
$11.17M (2008 nominal)
Fixed OPEX / MW-yr
$102,801

Source value
$64.6k (2008 nominal)

How this was derived
Benchmark fixed O&M for OCGT used as fallback.

Reference
2024 Energy Technology Cost and Technical Parameter Review (high confidence)
Variable OPEX / MWh
$7.45

Source value
$4.68 (2008 nominal)

How this was derived
Benchmark variable O&M for OCGT used as fallback.

Reference
2024 Energy Technology Cost and Technical Parameter Review (high confidence)
Fuel cost / GJ default
$12.00
Heat rate GJ/MWh
10.40

How this was derived
Benchmark heat rate for OCGT used as fallback.

Reference
2024 South West Gas-Powered Generation Forecast Methodology Report to 2034 (high confidence)

Confidence: high · Status: ai estimated · Capex basis: reported · AI checked 04 Jun 2026

Notes
Greenfield capex uses a reported project cost of A$545m–A$546m for Braemar 2; sources conflict slightly, so A$546m was selected as the nominal project cost and the 2008 announcement year was used for capex_year. No separate refurbishment cost identified. OCGT operating assumptions use AEMO/Aurecon 2024 review values for OCGT heat rate and O&M, treated as benchmark defaults rather than plant-specific data.

Sources