Australian Energy Market Operator
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Operational Demand in a region is demand that is met by local scheduled generating units, semi-scheduled generating units, and non-scheduled intermittent generating units of aggregate capacity 30 MW, and by generation imports to the region. It excludes the demand met by non-scheduled non-intermittent generating units, non-scheduled intermittent generating units of aggregate capacity 30 MW, exempt generation (e.g. rooftop solar, gas tri-generation, very small wind farms, etc), and demand of local scheduled loads. The exceptions are Yarwun, Angaston, Port Stanvac, and Morton s Lane which are included.
Probability of Exceedance (POE) demand is a generalised approach to defining the probability of exceedance of electricity demand forecasts. The demand is expressed as the probability the forecast would be met or exceeded, e.g. a 50% POE demand implies there is a 50% probability of the forecast being met or exceeded.
Daily Actual Operational Demand Update – filename: public_actual_operational_demand_update_daily*.csv (approx. size 2Mb)
This file is published when there is a retrospective change made by AEMO to the actual operational demand data record (for example: due to SCADA data quality). Data published here overrides the original data published in real-time (Half-hourly Actual Operational Demand and Daily Actual Operational Demand files) for the same trading interval.
Half-hourly Actual Operational Demand – filename: public_actual_operational_demand_hh*.csv (approx. size 200kb)
This file contains the historical operational demand information (30-minute average of 4-second instantaneous demand) by region for the previous trading interval.
Daily Actual Operational Demand – filename: public_actual_operational_demand_daily*.csv (approx. size 2Mb)
This file contains the historical operational demand information (30-minute average of 4-second instantaneous demand) by region covering all trading intervals of the previous trading day.
Half-hourly Forecast Operational Demand – filename: public_forecast_operational_demand_hh*.csv (approx. size 31Mb)
This file contains the 30-minute forecast operational demand information by region covering from the pre-dispatch timeframe. Three types of POE demand forecasts (10%, 50% and 90% POE) are reported under the columns headed OPERATIONAL_DEMAND_POE10 , OPERATIONAL_DEMAND_POE50 , and OPERATIONAL_DEMAND_POE90 , respectively.
- two week rolling window for the Half-hourly Actual and Forecast Operational Demand files
- two month rolling window for the Daily Actual Operational Demand files
- all Daily Actual Operational Demand Update files
- weekly files for the Half-hourly Actual and Forecast Operational Demand
- monthly files for the Daily Actual Operational Demand
The National Electricity Market registration classification of Yarwun Power Station Unit 1 (dispatchable unit ID: YARWUN_1) is market non-scheduled generating unit. However, it is a condition of the registration of this unit that the Registered Participant complies with some of the obligations of a Scheduled Generator. This unit is dispatched as scheduled generating unit with respect to its dispatch offers, targets and generation outputs. Accordingly, information about YARWUN_1 is reported as scheduled generating unit information.
This data is provided for information only and is not intended for commercial use. AEMO does not guarantee the accuracy of the data or its availability at all times.
Note 1: Between midnight and 14:00 hrs EST, the last day of the 7-day outlook only covers the period midnight to 04:00 hrs because Short-term PASA only covers six trading days.
Note 2: Values in the 7-day outlook table and 7-day outlook peak data report are rounded, and there could be +/- 1 MW differences when verifying the equation: Scheduled Capacity – Scheduled Demand – Net Interchange = Scheduled Reserve. However values in the 7-day outlook full data reports are not rounded.
Explanation of Terms
The total forecast generating capacity, available to the region at the time of its forecast daily peak demand (as limited by any network constraints), based on:
- The offered maximum availability of all scheduled generation within that region, as limited by any offered daily energy limitations.
The unconstrained intermittent generation forecasts of all semi-scheduled generation within that region.
This figure does not include net import from other regions.
The forecast daily peak demand for the region, based on weather-adjusted forecasts by AEMO with a 50% probability of exceedance, to be met by scheduled and semi-scheduled generation (either locally or via interconnector imports).
The forecast maximum net interchange which maximises the spare capacity for the study region. Positive interchange means export and negative interchange means import.
The scheduled capacity for a region, less net interchange with other regions, which is in excess of its scheduled demand.
The time of the forecast daily peak demand for the region, expressed as half-hour ending in Eastern Standard Time (EST) in Australia.
The information in the 7-day outlook table above is extracted from the latest LOR (Lack of Reserve) runs of the Pre-dispatch PASA and Short-term PASA processes.
The information is also provided in the following 7-day outlook full data report: http://www.nemweb.com.au/REPORTS/CURRENT/SEVENDAYOUTLOOK_FULL
Previous versions of the 7-day outlook full data reports are available from: http://www.nemweb.com.au/REPORTS/ARCHIVE/SEVENDAYOUTLOOK_FULL
The LRC (Low Reserve Condition) reports produced from the Short-term PASA process are available from: http://www.nemweb.com.au/REPORTS/CURRENT/Short_Term_PASA_Reports/