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
LOADING STATIONS...
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
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