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DAPR 2023
DAPR MAP 2023

Disclaimer

The DAPRM (Distribution Annual Planning Report Map) is an interactive geospatial map that has been developed to provide indicative information regarding Ergon Energy’s regulated network topology, forecast loads and capacities, and network constraints. The DAPRM is an information service available to the public.

Users of this service must acknowledge and accept that:

  • The information obtained from the DAPRM is intended as general in nature, may be based on assumptions that change with time and may not necessarily be complete. Information contained in, or obtained from, the DAPRM should not be relied upon.
  • Ergon Energy makes no representation or warranty as to the accuracy or completeness of any information obtained from the DAPRM. The DAPRM is not a substitute for independent advice and research.
  • Ergon Energy does not accept any responsibility for any loss or damage, however caused, which any person or entity may suffer in connection with the information contained in, or obtained from, the DAPRM.

Note

Grayed out layers are only available at certain zoom levels.

Note

  • Data applies to the current year only. Data will be updated annually in line with the release of the Distribution Annual Planning Report (DAPR).
  • Some data layers may need to be enabled, or are only available at certain zoom levels. Please see for Layer options

About this map

This mapping portal forms part of our Distribution Annual Planning Report (DAPR) and presents:

  • the topology of our regulated network, including transmission network connection points, substations, sub-transmission network and distribution feeders.
  • forecast loads for transmission network
  • connection points, forecast loads and capacity information for each of our substations and sub-transmission feeders
  • distribution feeders that are forecast to have capacity constraints in the next 2 years
  • substation constraints that are forecast to emerge in the next 5 years

As a Distribution Network Service Provider (DNSP), we are required to publish this information under Rule 5.13 and Schedule 5.8 of the National Electricity Rules (NER).

FORECAST INFORMATION

Subtransmission Feeder Forecasts 10PoE (.xlsx)
Subtransmission Feeder Forecasts 50Poe (.xlsx)

The subtransmission line tables include the following information:

  • Planning Region
    • Ergon Energy Ecorp Asset ID
    • Ergon Energy operational number
  • Subtransmission line description
  • Summer capacity & load forecasts for 5 years
    • Rating (Amps)
    • Loading (Amps)
    • Power Factor

Definitions

SD: Summer Day (9am to 5pm)
SE: Summer Evening (5pm to 10pm)
SNM: Summer Night/Morning (10pm to 9am)
Summer: December to March

Comments

  • Poor power factors of some feeders
    Where the power factors are very low it is because (in general) the feeder is part of a ring network with circulating reactive power. The active power is swamped by the reactive power in these cases. There are some radial feeders where the power factor is also very low. This is as a result of very little active power being supplied by these feeders combined with a lot of line charging reactive power which once again swamps the active power component.
  • Missing power factors
    This is a result of unloaded feeders that are only energised from one side. There is some line charging which accounts for the non-zero loading in amperes but there is no active power supplied by the feeder.
Substation Forecasts (.xlsx)

The subtransmission line tables include the following information:

  • Planning Region
    • Ergon Energy Ecorp Asset ID
    • Ergon Energy operational number
  • Subtransmission line description
  • Summer capacity & load forecasts for 5 years
    • Rating (Amps)
    • Loading (Amps)
    • Power Factor

Definitions

SD: Summer Day (9am to 5pm)
SE: Summer Evening (5pm to 10pm)
SNM: Summer Night/Morning (10pm to 9am)
Summer: December to March

Comments

  • Poor power factors of some feeders
    Where the power factors are very low it is because (in general) the feeder is part of a ring network with circulating reactive power. The active power is swamped by the reactive power in these cases. There are some radial feeders where the power factor is also very low. This is as a result of very little active power being supplied by these feeders combined with a lot of line charging reactive power which once again swamps the active power component.
  • Missing power factors
    This is a result of unloaded feeders that are only energised from one side. There is some line charging which accounts for the non-zero loading in amperes but there is no active power supplied by the feeder.

Transmission Connection Point Forecasts (.xlsx)

The Transmission Connection Point Forecasts include the following information for 50 PoE and 10 PoE in summer and winter:

  • Ergon Energy region
  • TNI: National Electricity Market - Transmission Node Identity
  • TCP Name: Name of the Transmission Connection Point
  • Forecast Peak Load (MW)
  • Forecast Peak Load (MVARu) (VARu = Volt Amps Reactive Uncompensated, i.e. with stated compensation not active)
  • Forecast Compensation (MVAR)

Exclusions
Forecast capacity is not given this spreadsheet. In the majority of cases, the capacity at the TCP is controlled by the Transmission Network Service Provider, and hence reported by them. In the relatively few cases where Ergon Energy asset boundary at the TCP is inclusive of power transformers, the substation capacity will appear in the Zone or Bulk Supply Substations Forecasts tables. The forecast loads are given exclusive of any connected embedded generation.

Distribution Feeder Limitations (.xlsx)

The Distribution Feeder Limitations tables include the following information for each constrained distribution feeder:

  • Ergon Energy region
  • Distribution feeder name, ID & location
  • Load exceedance after 2 yrs (MVA)
  • Forecast season that exceedance occurs (Summer / Winter)
  • Forecast year that exceedance occurs
  • Forecast month/s that exceedance occurs
  • Load reduction needed to delay the exceedance by 12 months (MW) (assumed power factor of 0.9)

Solutions
Suggested solutions, in order or preference, are included under the 'Solutions' tab.

Connection points for possible load reduction
In all cases, the connection point to apply load reduction would be downsteam of the substation exit feeder cable and/or first section of line.

Exclusions
Dedicated customer connection assets are excluded from the analysis.

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