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Regulatory test consultations

We're always working to identify limitations or constraints in our distribution network. When we propose to establish a new, large distribution asset to address a constraint, Registered Participants and Interested Parties are invited to offer alternative solutions that satisfy the Regulatory Investment Test for Distribution (RIT-D).

We analyse the different options and prepare a report or request for proposal. Our current consultation reports can be viewed below.

Further information about how we're managing the network can be found in our Distribution Annual Planning Report.

Our requirements under the National Electricity Rules

Under the National Electricity Rules, if we're proposing to establish a new, large distribution asset to address a constraint, then we're required to:

  • consult with Registered Participants, the Australian Energy Market Operator (AEMO) and Interested Parties on the anticipated limitation and options to address the constraint, within the time frame required for corrective action
  • carry out a detailed economic cost effectiveness analysis of options to identify solutions that satisfy the Regulatory Test
  • prepare a report for affected Registered Participants, the AEMO and Interested Parties which includes an assessment of all identified options, details of the preferred solution and the recommended action to be taken.

Register for information and alerts

When you register you'll receive periodic communications about our research and projects, including notification of upcoming RIT-D consultation opportunities.

Register now for project updates

Contact us

For any other enquiries and to find out more about our demand management programs please contact us at demandmanagement@ergon.com.au.

Current consultations

Click on an area below to view the current consultations.

Barcaldine

Report typeDescriptionDate issuedSubmission closes
Request for proposal (PDF 1.3 mb)Invitation to submit non-network solutions to address identified network constraints.29 Sep 20203 Nov 2020

Barcaldine, Blackall and Longreach

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options
(PDF 331.5 kb)
Barcaldine 132/66/22kV Bulk Supply Substation (T072 BARC) is a bulk supply point for the Central West Region of Queensland, supplying Longreach and Blackall substations via 66kV feeders and the Barcaldine region via 22kV feeders.  T072 BARC supplies a total of 6323 customers and a maximum demand of 20MVA.  It’s 22kV bus supplies 2206 customers in Barcaldine with a maximum demand of 7MVA.  

T072 BARC has in recent years become the National Electricity Market (NEM) connection point for several utility scale solar farms: Dunblane 7.2MW, Barcaldine 20MW and Longreach 14MW.  These solar farms rely on the electrical infrastructure at T072 BARC to provide a reliable connection capacity to the National Electricity Market (NEM).  

A condition assessment of T072 BARC has identified assets that are recommended for replacement. These assets are forecast to reach retirement based on a combination of Condition Based Risk Management (CBRM) modelling and known issues with problematic plant, which are required to be replaced or decommissioned to manage the safety and network risks associated with unplanned failure.

The internal investigations undertaken on the feasibility of the non-network solutions revealed that it is unlikely to find a complete non-network solution or a hybrid (combined network and non-network) solution to provide the magnitude of network support required in the Central West Region of Queensland to address the identified need.

The preferred network option is to replace the assets in poor condition. This notice of no non-network options is therefore published in accordance with rule 5.17.4(d) of the National Electricity Rules. As the next step in the RIT-D process, Ergon Energy will now proceed to publish a Final Project Assessment Report.
30 Jun 2020

Chinchilla

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options
(PDF 866.7 kb)

Chinchilla 132/110/33kV Substation (CHIN) is located in the township of Chinchilla in south-west Queensland. The substation supplies the 33kV sub-transmission network in Chinchilla and the surrounding area, and provides electricity supply to approximately 6,500 customers.

A substation condition assessment of Chinchilla Substation was completed and has identified some primary and secondary plant and equipment that are recommended for retirement based on Condition Based Risk Management (CBRM) analysis.

Ergon Energy has determined that network investment is essential in this case for it to continue to provide electricity to the consumers in the Chinchilla supply area in a reliable, safe and cost-effective manner.

An internal assessment has been carried out and it has been determined that no non-network solutions can potentially meet the identified need or form a significant part of the solution. This Notice has hence been prepared by Ergon Energy in accordance with the requirements of clause 5.17.4(d) of the NER.

30 Oct 2020N/A

Cloncurry

Report typeDescription Date issued Submission closes
Non-Network Options Report (PDF 1.5 mb)Cloncurry 66/11kV Substation (CLON) and North Cloncurry 66/11kV Substation (NOCL) are normally supplied from Chumvale 220/66kV Substation (CHUM) via a single circuit 66kV sub-transmission feeder. Chumvale Substation is supplied by a single circuit 220kV feeder from the Mica Creek 'C' Substation (MICC) at Mt Isa. There is also a single circuit 66kV sub-transmission feeder from Mount Isa's Duchess Road 132/11/66kV Substation (DURO) to a normally open isolation point (designated DR-CC-1), which is located outside Chumvale Substation.

The thermal rating of the DR-CC-1 66kV feeder is no longer adequate to supply Cloncurry and Ergon Energy would not comply with the Safety Net requirements based on credible contingencies benchmarked against 50% POE load in the present configuration.

This report represents the first stage of the consultation process in relation to the application of the Regulatory Investment Test for Distribution (RIT-D) on potential credible options to address the identified need at Cloncurry.

Ergon Energy has prepared this Non-Network Options Report in accordance with the requirements of clause 5.17.4(e) of the National Electricity Rules (NER) and seeks information from interested parties about possible alternate solutions to address the need for investment.
14 Feb 202015 May 2020

East Bundaberg

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options Report
(PDF 329.4 kb)

Bundaberg is a regional city located 360km north of Brisbane with a population of approximately 93,000 people. East Bundaberg 66/11kV Zone Substation (EABU) is located on the eastern edge of Bundaberg city and supplies a diverse mix of industrial, residential, and agricultural zones. There are approximately 8900 customers connected to the distribution network, including a number of major commercial and industrial customers located in Bundaberg and further north at Burnett Heads.

A condition assessment of East Bundaberg Zone Substation (EABU) has identified assets that are recommended for replacement. These assets are forecast to reach retirement based on a combination of Condition Based Risk Management (CBRM) modelling and known issues with problematic plant, which are required to be replaced or decommissioned to manage the safety and network risks associated with unplanned failure.

The internal investigations undertaken on the feasibility of the non-network solutions revealed that it is unlikely to find a complete non-network solution or a hybrid (combined network and non-network) solution to provide the magnitude of network support required in the East Bundaberg area to address the identified need.

The preferred network option is to replace the assets in poor condition. This notice of no non-network options is therefore published in accordance with rule 5.17.4(d) of the National Electricity Rules. As the next step in the RIT-D process, Ergon Energy will now proceed to publish a Final Project Assessment Report.

22 Jun 2020

Maryborough

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options (PDF 430.4 kb)Maryborough 132/66kV substation (MARYSS) T59 is a Bulk Supply Point which supplies approximately 50,000 customers and 125MVA of peak load through connected Zone Substations. The 75MW Susan River Solar Farm is also connected to the 66kV network through a dedicated substation. MARYSS is located west of Maryborough and supplies the majority of the Fraser Coast Local Government Area, including the major regional centres of Maryborough and Hervey Bay as well as several smaller towns.

The purpose of this project is to address poor condition assets, compliance Safety Net provisions of the Distribution Authority, and compliance with performance standards as set out in the National Electricity Rules.

The internal investigations undertaken on the feasibility of the non-network solutions revealed that it is unlikely to find a complete non-network solution or a hybrid (combined network and non-network) solution to provide the magnitude of network support required in the Maryborough area to address the identified need.

The preferred network option is to replace assets in poor condition, install bus couplers to address Safety Net and upgrade protection to meet NER Network Performance requirements. This notice of no non-network options is therefore published in accordance with rule 5.17.4(d) of the National Electricity Rules. As the next step in the RIT-D process, Ergon Energy will now proceed to publish a Final Project Assessment Report.
26 Feb 2020

Pialba

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options
(PDF 356.0 kb)

Pialba 66/11kV substation (PIALSS) is a Zone Substation which supplies approximately 5200 customers and 16MVA of peak load. PIALSS is located near the centre of Hervey Bay town and supplies the CBD area, the Hervey Bay Hospital, and the main shopping centre. There is also an extensive distribution network that supplies residential customers in the surrounding suburbs.

A condition assessment of PIALSS has identified assets that are recommended for replacement. These assets are forecast to reach retirement based on a combination of Condition Based Risk Management (CBRM) modelling and known issues with problematic plant, which are required to be replaced or decommissioned to manage the safety and network risks associated with unplanned failure.

The internal investigations undertaken on the feasibility of the non-network solutions revealed that it is unlikely to find a complete non-network solution or a hybrid (combined network and non-network) solution to provide the magnitude of network support required in the Hervey Bay area to address the identified need.

The preferred network option is to replace the assets in poor condition. This notice of no non-network options is therefore published in accordance with rule 5.17.4(d) of the National Electricity Rules. As the next step in the RIT-D process, Ergon Energy will now proceed to publish a Final Project Assessment Report.

3 Apr 2020

Pittsworth

Report typeDescriptionDate issuedSubmission closes
Final Project Assessment Report
(PDF 1.5 mb)
Broxburn 33/11kV substation (BROX) has two 5MVA 33/11kV transformers supplying the township of Pittsworth and surrounding rural areas including some relatively significant chicken farm loads. Peak demand was 10.46MVA in February 2018 which exceeded the substation nameplate capacity and is expected to exceed the emergency cyclic capacity by 2022.

Based on load forecasts, the substation is expected to exceed its emergency cyclic capacity with both transformers in service by 2022. Without addressing these emerging constraints proactively, during peak load times this will result in forced load shedding.

A significant number of primary plant within BROX is at the end of life. If this aged equipment is not replaced before the nominated end of life, there will be an increased likelihood of plant failure. As well as presenting safety risks, the unplanned, sporadic and uncontrolled nature of such failures increases the costs of rectification. The proposed investment under this project addresses these limitations in an economic, efficient and safe manner.
1 October 2020 
Draft Project Assessment Report
(PDF 1.2 mb)

Ergon Energy Corporation Limited (Ergon Energy) has prepared this Draft Project Assessment Report (the Report) in accordance with the requirements of clause 5.17.4(i) of the National Electricity Rules (NER).

This report represents the second stage of the consultation process in relation to the application of the Regulatory Investment Test for Distribution (RIT-D) on potential credible options to address the identified need.

  
Non-Network Options Report (PDF 1.2 mb)

Broxburn substation 33/11kV supplies the township of Pittsworth. Maximum demand in 2018 exceeded the substation nameplate capacity and is expected to exceed the emergency cyclic capacity by 2022. The two transformers at Broxburn substation were manufactured in the 1960s that they are near end of life including associated high voltage switches.

Ergon Energy has proposed to address these limitations by installing a 10MVA skid transformer and completed by December 2021.

This report is an invitation to registered participants and interested parties to make submissions about possible alternate solutions to address the identified limitations.

1 Jul 201910 Jan 2020

Pleystowe

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options (PDF 844.9 kb)

Pleystowe 33/11kV Substation is located on the southern bank of the Pioneer River approximately 13km west of Mackay and 2.5km north-west of Walkerston. Plewstowe substation supplies the township of Walkerston and the surrounding area.

Pleystowe Substation is presently supplied via two incoming 33kV feeders from T038 Mackay Substation, and there are two outgoing 33kV feeders from Pleystowe Substation which provide supply to Farleigh 33/11kV Substation and the Pleystowe Mill.

Pleystowe Substation was established in 1964 according to applicable design and construction standards during that time. It has an outdoor 33kV and 11kV switchyard with steel structures, three 5MVA 33/11kV power transformers, and a small protection and control building.

A substation condition assessment of Pleystowe Substation was completed in 2019 and has identified some primary and secondary plant and equipment that are recommended for retirement based on Condition Based Risk Management (CBRM) analysis.

Ergon Energy has determined that network investment is essential in this case for it to continue to provide electricity to the consumers in the Pleystowe supply area in a reliable, safe and cost-effective manner.

An internal assessment has been carried out and it has been determined that no non-network solutions can potentially meet the identified need or form a significant part of the solution. This Notice has hence been prepared by Ergon Energy in accordance with the requirements of clause 5.17.4(d) of the NER.

9 Oct 2020N/A

Point Vernon (Hervey Bay)

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options (PDF 373.2 kb)

Point Vernon 66/11kV Zone Substation (POVE) supplies 10,700 customers. POVE is energised radially from Pialba 66/11kV Zone Substation (PIAL) via a 5.1km single circuit concrete pole 66kV feeder (M023). Load at POVE peaked at 21MVA in February 2020 and is forecast to increase to approximately 23MVA by 2032. Proposed residential and commercial developments in the suburbs of Dundowran, Craignish, Toogoom and Eli Waters are continuing and may result in load growth in excess of the forecast.

The purpose of this project is to address compliance with the Safety Net provisions of the Distribution Authority.

The internal investigations undertaken on the feasibility of the non-network solutions revealed that it is unlikely to find a complete non-network solution or a hybrid (combined network and non-network) solution to provide the magnitude of network support required in the Point Vernon area to address the identified need.

The preferred network option is to extend a new 66kV feeder to POVE to address Safety Net requirements. This notice of no non-network options is therefore published in accordance with rule 5.17.4(d) of the National Electricity Rules. As the next step in the RIT-D process, Ergon Energy will now proceed to publish a Draft Project Assessment Report.

10 Jun 2020

Turkinje

Report typeDescriptionDate issuedSubmission closes
Notice of No Non-Network Options Report asset_summary_857556%

A condition assessment of the Turkinje (TURK) 132/66kV Substation (T055) 66kV primary plant and secondary systems has identified assets that are nearing the end of their technical services lives with identified condition, safety and obsolescence issues.

These primary plant and secondary system assets:

  • are forecast to reach the end of their technical services lives based on a combination of Condition Based Risk Management (CBRM) modelling and known issues with problematic assets, which are required to be replaced or decommissioned to manage the safety and network risks associated with unplanned failure
  • include 66kV circuit breakers, 66kV voltage and current transformers, electromechanical and static protection relays, porcelain post and segmented porcelain insulators used on rotary isolators

Failure of the primary plant and secondary systems is a risk to network security which may lead to a breach of legislated Safety Net requirements and exposes customers to the risks and consequences of an increasingly unreliable electricity supply. Catastrophic failure of plant or secondary systems presents a safety risk to staff as well as to the general public.

Planning studies have confirmed there is an enduring need for the 66kV to maintain the supply of electricity in the Tablelands area.

The purpose of this project is to address the risk to safety and network security posed by poor condition and problematic assets.

7 Oct 2020

Closed consultations

View the Closed consultations webpage to see the list of Regulatory Test Consultations that have now concluded.