Generation and Load
Data is provided in comma delimited flat file format to enable access to a range of market data. Recent files are stored in a directory for current reports, and older files are moved into the archive reports directory.
Actual Generation and Load Data
Actual generation and load data - filename: public_dispatchSCADA_*.csv (approx. size 16Kb)
This file contains actual generation data for each scheduled generation unit, semi-scheduled generation unit, and non-scheduled generating units or non-scheduled generating systems (a non-scheduled generating system comprising non-scheduled generating units). This file also contains actual load for each scheduled load. The actual generation and load data in the file is reported under a column headed 'SCADAVALUE'. (Please see note)
Non-Scheduled Generation Data
Non-Scheduled Generation Data - filename: public_next_day_actual_gen_*.csv (approx. size 600Kb)
The metered power outputs from most large non-scheduled generating units and generating systems are provided to AEMO in real time to assist in maintaining the security of the power system. Under Clause 3.13.4(r) of the National Electricity Rules AEMO is also required to publish such data to Registered Participants, in a daily file covering all intervals of the previous trading day.
The output values in these files are sampled from SCADA at 5-minute intervals and reported under the column headed 'MWH_READING'. Note that these figures should be read as instantaneous power in MW rather than MWh. They may be used to estimate energy production, but are not the same as the half-hourly energy metering results used to determine market settlements. (Please see note)
The below link contains the correct data for non-scheduled generator, Woolnorth between 11/3/2013 to 17/7/2013 1735 hrs.
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. Please see Demand Terms in EMMS Data Model, available on the AEMO website, for the list of exceptions that 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
AEMO plans to discontinue the publication of this data from 1 July 2015.
Historical Demand in a region is Scheduled Demand less demand of local scheduled loads. In other words, it is the demand that is met by local scheduled generating units, semi-scheduled generating units, and by generation imports to the region, excluding the demand met by non-scheduled generating units, exempt generation, and demand of local scheduled loads. The exceptions are Yarwun, Angaston, and Port Stanvac, which are included.
Note that Historical Demand differs from Operational Demand in that significant non-scheduled intermittent generating units in the region are not included in the Historical Demand calculation.
Historical Demand - filename: public_histdemand_*.csv (approx. size 2Mb)
This file contains historical demand information (4 second SCADA demand average over half hour interval), by region for each trading interval for that calendar day.
These files reflect data that are available at the time of publication.
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.
The Tumut 3 Pumps (dispatchable unit ID: SNOWYP) are not classified as scheduled load in the National Electricity Market. However, they are required to comply with some of the obligations of a Market Customer in respect of a scheduled load. The Tumut 3 Pumps are dispatched as if they were scheduled loads with respect to their dispatch bids, targets and consumption. Accordingly, information about SNOWYP is reported as market scheduled load 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.