NSW150.001 Hz
PRICE:--/MWh
DEMAND:7.70GW

NSW1 REGIONAL MARKET DESK

Institutional 5-minute spot telemetry, generator unit dispatch stacks, and FCAS co-optimization for NSW1.

CURRENT SPOT PRICE
$0.00 AUD/MWh
REGIONAL DEMAND
7.70 GW
UNIT 1: PRICE & FORECAST TELEMETRY
4 MODULES
24H MONTE CARLO PROBABILISTIC SPOT FORECAST
RENEWABLE PLANT DISPATCH & PROJECTION FORECASTS
GENERATING FORECAST...
UNIT 2: FREQUENCY & GRID STABILITY TELEMETRY
3 MODULES
AEMO MINIMUM SYSTEM INERTIA SECURITY

Mandatory regional inertia floor to contain RoCoF and maintain synchronous stability

Live Regional Inertia22.37 GW·s
Security Floor11.5 GW·s
Inertia Margin+94.6% [SECURE]

AEMO GRID FREQUENCY & ROCOF TELEMETRY

OU-CALIBRATED PHYSICAL SIMULATION (4s)

Sub-Second Oscillation, Inertia & Wholesale Price Correlation

NORMAL OPERATING FREQUENCY BAND (NOFB)
GRID FREQUENCY
50.000 Hz
Nominal: 50.000 Hz
RoCoF (dF / dt)
+0.000 Hz/s
Tolerance: < ±0.5 Hz/s
SYSTEM INERTIA
— GW·s
Floor: 60.0 GW·s
FFR BATTERY RESERVE
— MW
Fast Frequency Response
HIGH-RESOLUTION OSCILLATION WAVEFORM (CLICK ANY POINT TO INSPECT TELEMETRY)NOFB BAND: 49.850 Hz 50.150 Hz
GRID FREQUENCY (Hz)
AEMO SUB-SECOND DISPATCH TELEMETRY • CLICK POINT TO AUDIT EVENTS
RECENT FREQUENCY CONTINGENCY TRIPS & FFR ACTIVATIONS (CLICK TO INSPECT TIMESPOT)
  • TABLE
  • CARDS
Contingency / Incident EventTimestampDurationNadir FreqMax RoCoFFFR ResponseAction

FREQUENCY RESPONSE LAYERS & GENERATOR TIMEFRAME INSPECTOR

Sub-second to 30-minute Grid Stabilization Matrix • Primary, Secondary & Tertiary Response Profiles

AEMO NEM FCAS PROTOCOL SYNC
GRID DISTURBANCE TIMELINE SLIDER
ACTIVE TIMEFRAME:PRIMARY RESPONSE (PFR) (2s - 60s)
INERTIA (0-2s)
PRIMARY / PFR (2-60s)
SECONDARY / SFR (1-5m)
TERTIARY / TFR (5-30m+)
Phase Action: Autonomous Governor Droop & Fast Inverter (6s/60s FCAS)6 Seconds post-trip
RESPONSE LAYER:
  • ALL LAYERS
  • INERTIAL
  • PFR
  • SFR
  • TFR
FILTER GENERATOR:

BESS (Battery Energy Storage)

Startup / Activation Latency: < 50 ms
Battery
INERTIAL (0-2s)OPTIMAL (HIGH)

Grid-Forming Virtual Synthetic Inertia

PRIMARY PFR (2-60s)OPTIMAL (HIGH)

Fastest 6s/60s PFR injection (< 200ms)

SECONDARY SFR (1-5m)OPTIMAL (HIGH)

99% linear tracking of 4s AGC signals

TERTIARY TFR (5-30m+)MODERATE

Limited by storage capacity (MWh)

Ramp Speed100% in < 200 ms
Droop Sensitivity0.1% - 1.0% Virtual
AEMO MARKET PARTICIPATION:RAISE 6SECRAISE 60SECRAISE REGLOWER 6SECLOWER REG
Constraint: Constrained by total MWh State of Charge (SOC) and thermal degradation.

Pumped & Conventional Hydro

Startup / Activation Latency: 10 - 30s (Spinning) / 2m (Cold)
Hydro
INERTIAL (0-2s)OPTIMAL (HIGH)

Heavy physical water turbine mass (H ≈ 3-5s)

PRIMARY PFR (2-60s)OPTIMAL (HIGH)

Fast hydraulic gate governor (3s-10s)

SECONDARY SFR (1-5m)OPTIMAL (HIGH)

High ramp rate AGC regulation balancing

TERTIARY TFR (5-30m+)OPTIMAL (HIGH)

Sustained multi-hour energy replacement

Ramp Speed20 - 50 MW / min
Droop Sensitivity3% - 5% Governor
AEMO MARKET PARTICIPATION:RAISE 6SECRAISE 60SECRAISE 5MINRAISE REG
Constraint: Constrained by upper/lower reservoir water storage head.

Open Cycle Gas Turbine (OCGT)

Startup / Activation Latency: 5 - 15 mins (Cold)
Gas
INERTIAL (0-2s)MODERATE

Physical inertia only when synchronized

PRIMARY PFR (2-60s)MODERATE

Requires spinning head-room allocation

SECONDARY SFR (1-5m)OPTIMAL (HIGH)

Rapid thermal ramp to take over from BESS

TERTIARY TFR (5-30m+)OPTIMAL (HIGH)

Continuous peak spot generation

Ramp Speed15 - 30 MW / min
Droop Sensitivity4% - 5% Governor
AEMO MARKET PARTICIPATION:RAISE 60SECRAISE 5MINRAISE REGSPOT DISPATCH
Constraint: High fuel consumption cost ($/GJ) and start-up thermal stress.

Combined Cycle Gas Turbine (CCGT)

Startup / Activation Latency: 1 - 4 hours (Cold)
Gas
INERTIAL (0-2s)OPTIMAL (HIGH)

Gas + Steam combined physical turbine mass

PRIMARY PFR (2-60s)MODERATE

Gas turbine responds; steam stage delayed

SECONDARY SFR (1-5m)MODERATE

Ramp-rate constrained by HRSG boiler

TERTIARY TFR (5-30m+)OPTIMAL (HIGH)

Highly efficient baseline replacement

Ramp Speed5 - 15 MW / min
Droop Sensitivity4% - 5% Governor
AEMO MARKET PARTICIPATION:RAISE 5MINRAISE REGSPOT DISPATCH
Constraint: Slow cold startup times and boiler thermal stress limits.

Black Coal Steam Thermal

Startup / Activation Latency: 6 - 12 hours (Cold)
Coal
INERTIAL (0-2s)OPTIMAL (HIGH)

Highest grid physical inertia (H ≈ 4-6s)

PRIMARY PFR (2-60s)MODERATE

AEMO Mandatory PFR droop active

SECONDARY SFR (1-5m)LIMITED / SLOW

Slow steam & pulverizer thermal lag

TERTIARY TFR (5-30m+)OPTIMAL (HIGH)

Bulk base-load energy provider

Ramp Speed1 - 3 MW / min
Droop Sensitivity3% - 5% Mandatory
AEMO MARKET PARTICIPATION:MANDATORY PFRRAISE 5MINSPOT DISPATCH
Constraint: Slow ramp rates, high minimum generation floor, long start-up.

Brown Coal Heavy Steam

Startup / Activation Latency: 12 - 24 hours (Cold)
Coal
INERTIAL (0-2s)OPTIMAL (HIGH)

Massive turbine rotor synchronous inertia

PRIMARY PFR (2-60s)LIMITED / SLOW

Slow boiler pressure recovery

SECONDARY SFR (1-5m)LIMITED / SLOW

Prefers constant flat base-load output

TERTIARY TFR (5-30m+)OPTIMAL (HIGH)

Provides base energy replacement

Ramp Speed1 - 2 MW / min
Droop Sensitivity4% - 5% Mandatory
AEMO MARKET PARTICIPATION:MANDATORY PFRSPOT DISPATCH
Constraint: Inflexible unit commitment, sensitive to rapid ramp cycling.

Utility-Scale Solar PV

Startup / Activation Latency: < 1 second
Solar
INERTIAL (0-2s)NONE

Zero physical mechanical inertia

PRIMARY PFR (2-60s)MODERATE

Fast Lower PFR; Raise requires headroom

SECONDARY SFR (1-5m)MODERATE

Inverter AGC tracking if curtailed

TERTIARY TFR (5-30m+)LIMITED / SLOW

Driven by GHI solar weather input

Ramp SpeedFast Inverter Ramp
Droop SensitivityInverter Fast Response
AEMO MARKET PARTICIPATION:LOWER 6SECLOWER REGSPOT DISPATCH
Constraint: Zero generation at night; Raise response requires pre-curtailment.

Wind Turbines (Inverter)

Startup / Activation Latency: < 1 second
Wind
INERTIAL (0-2s)MODERATE

Emulated kinetic blade inertia (1-3s)

PRIMARY PFR (2-60s)MODERATE

Active power injection via fast inverters

SECONDARY SFR (1-5m)MODERATE

Inverter AGC regulation tracking

TERTIARY TFR (5-30m+)LIMITED / SLOW

Output constrained by wind availability

Ramp SpeedFast Pitch Control
Droop SensitivitySynthetic Fast Droop
AEMO MARKET PARTICIPATION:LOWER 6SECLOWER REGSPOT DISPATCH
Constraint: Variable resource availability dependent on ambient wind speeds.

FCAS & SPOT ENERGY CO-OPTIMIZATION WORKBENCH

8-Market Ancillary Services Enablement & Yield Solver (NSW1)

AEMO CO-OPTIMIZER ACTIVE
8 FCAS SERVICE BUCKET PRICES & ENABLEMENT QUEUEFETCHING LIVE AEMO RATES…
RAISE 6SECRAISE
Fast Contingency (6s)
— /MWReq: —
RAISE 60SECRAISE
Slow Contingency (60s)
— /MWReq: —
RAISE 5MINRAISE
Delayed Contingency (5m)
— /MWReq: —
RAISE REGRAISE
Continuous Regulation
— /MWReq: —
LOWER 6SECLOWER
Fast Contingency (6s)
— /MWReq: —
LOWER 60SECLOWER
Slow Contingency (60s)
— /MWReq: —
LOWER 5MINLOWER
Delayed Contingency (5m)
— /MWReq: —
LOWER REGLOWER
Continuous Regulation
— /MWReq: —
BESS ASSET CAPACITY ALLOCATION (100 MW)
SPOT ENERGY ARBITRAGE40 MW
FCAS REGULATION & CONTINGENCY60 MW
Lower Enablement Limit (LEL): 10 MW
Upper Enablement Limit (UEL): 90 MW
Asset Ramp Rate Capacity: 50 MW/min
SOLVER YIELD PROJECTION (HOURLY)
Energy Spot Revenue (40 MW @ $/MWh):$0 / hr
FCAS Reserve Revenue (60 MW @ $42.50/MW):$0 / hr
TOTAL COMBINED CO-OPTIMIZED YIELD
$0 AUD / hour
+24.5% Net Revenue Uplift vs Single-Market Dispatch
ANCILLARY SERVICES (FCAS) MARKETS
LOADING FCAS MARKETS...
UNIT 3: REGIONAL ASSETS, GENERATION & TRANSMISSION TOPOLOGY
4 VIEWPORT MODULES
SPOT PRICE, DEMAND & RESIDUAL LOAD
Spot Price
$0.00/MWh
Total Demand
7.70GW
Residual Load
4.12GW
Demand - (Solar + Wind)
Inertia Floor
11.5GW·s
AEMO SECURITY BOUND
GENERATION FUEL MIX COMPOSITION
9.2GW Total
Coal
Solar
Wind
Gas
Hydro
REGIONAL FLEET DISPATCH SUMMARY
FuelOutput (MW)Share
Coal		4300.046.9%
Solar		2400.026.2%
Wind		1180.012.9%
Gas		760.08.3%
Hydro		520.05.7%
INTRA-REGIONAL SUBSTATION TOPOLOGY MAP
Intra-Regional TopologyReal-time PyPSA AC Power Flow
Uncongested
Heavy Load
Congested
No topology data available
REGISTERED GENERATION STATIONS & DUIDs
StationDUIDFuelCapacity / Output
Eraring Power StationER03COAL2880.0 MW
Bayswater Power StationBW02COAL2640.0 MW
Liddell Transition FacilityLDBESSG1COAL2000.0 MW
Tumut 3 Pumped StorageUPPTUMUTHYDRO1800.0 MW
Murray 1 Hydro StationMURRAYHYDRO1513.8 MW
Murray 2 Hydro StationMURRAYHYDRO1513.8 MW
Mount Piper Power StationMT_PIPERCOAL1400.0 MW
Vales Point B Power StationVP5COAL1320.0 MW
New England Solar & BESSNEWENSF2SOLAR1226.0 MW
Waratah Super BatteryWTAHB1L1BATTERY850.0 MW
Tallawarra A & B Power StationTALWA1GAS760.0 MW
Limondale Solar FarmLIMBESSL1SOLAR736.0 MW
Colongra Gas PeakerCG2GAS724.0 MW
Uranquinty Power StationURANQ12GAS664.0 MW
Wellington Solar FarmWELLSF1SOLAR652.0 MW
Shoalhaven Pumped Hydro SchemeSHPUMPHYDRO534.0 MW
Capital Wind FarmCAPBES1LWIND515.2 MW
Riverina BESS 1 & 2RIVERINASFBATTERY467.4 MW
Uungula Wind FarmUUNGULAWFWIND414.0 MW
Darlington Point Solar FarmDARLSF1SOLAR399.0 MW
Rye Park Wind FarmRYEPARK1WIND396.0 MW
Smithfield Energy FacilitySITHE01GAS333.2 MW
Tumut 1 Underground HydroUPPTUMUTHYDRO330.0 MW
Broken Hill Solar & BESSGB01SOLAR301.0 MW
Tumut 2 Underground HydroUPPTUMUTHYDRO286.0 MW
Sapphire Wind FarmSAPHWF1WIND270.0 MW
Guthega High-Alpine HydroGUTHEGAHYDRO260.0 MW
Bango Wind FarmBANGOWF1WIND243.8 MW
Sunraysia Solar FarmSUNRSF1SOLAR228.0 MW
Collector Wind FarmCOLWF01WIND226.0 MW
Silverton Wind FarmSTWF1WIND198.9 MW
White Rock Wind FarmWRSF1WIND197.0 MW
Coleambally Solar FarmCOLEASF1SOLAR180.0 MW
Gullen Range Wind & SolarGULLRSF1WIND175.0 MW
Finley Solar FarmFINLYSF1SOLAR162.4 MW
Blowering Dam HydroSNOWY6HYDRO160.0 MW
Redbank Power StationREDBANK1COAL150.0 MW
Crudine Ridge Wind FarmCRURWF1WIND141.0 MW
Boco Rock Wind FarmBOCORWF1WIND113.2 MW
Bodangora Wind FarmBODWF1WIND113.2 MW
Taralga Wind FarmTARALGA1WIND106.8 MW
Hume Dam HydroelectricHUMENSWHYDRO58.0 MW
Appin & Tower Coal Mine GasAPPINGAS55.6 MW
UNIT 4: PROJECTED ASSESSMENT OF SYSTEM ADEQUACY (ST / MT / LT PASA)
3 HORIZON VIEWPORTS
PROJECTED ASSESSMENT OF SYSTEM ADEQUACY (PASA)
RESERVE MARGINS, GENERATOR OUTAGES & 10-YEAR RELIABILITY ADEQUACY
7-DAY LOR RISK STATUS
NORMAL
MINIMUM RESERVE MARGIN
0 MW
PEAK DEMAND (P10 HIGH)
0.00 GW
HORIZON & STEPS
7 DAYS / 30-MIN STEPS
ST-PASA 7-DAY DEMAND BANDS (P10/P50/P90) vs AVAILABLE CAPACITY
ST-PASA LOW RESERVE & LOR ALERT LOG
Interval (AEST)P50 Demand (MW)P10 Demand (MW)Avail Cap (MW)Reserve MarginStatus