| Bundaberg (PDF, 1.6 MB) | Screening for Non-Network Options Report | Ergon Energy is responsible for the electricity supply in the Bundaberg region and does so via a network of substations all connected to the T020 Bundaberg bulk supply point. In its current state T020 Bundaberg will not meet the outage restoration times required under our service Safety Net obligations should a 132kV OR 66kV bus outage occur. To comply with Safety Net at Bundaberg T020 bulk supply point restoration must be completed with an hour or unserved load must be kept under 20MVA for the current 2 hour restoration time.Our preferred option is to install bus section circuit breakers and associated equipment to reduce restoration time to within an hour to comply with Safety Net for a cost of $7.3M. As T020 Bundaberg supplies between 30 – 112 MVA to the wider Bundaberg region, any non-network option must support between 6 MVA and 96 MVA for 2 hours until restoration is completed. We are publishing this notice under cl. 5.17.4(d) of the NER as it has determined that no non-network option is, or forms a significant part of any potential credible option. | 23 Apr 2018 | 25 May 2018 |
| Bundaberg (PDF, 1.6 MB) | Final Project Assessment Report | Ergon Energy is responsible for the electricity supply in the Bundaberg region and does so via a network of substations all connected to the T020 Bundaberg bulk supply point. In its current state T020 Bundaberg will not meet the outage restoration times required under our service Safety Net obligations should a 132kV OR 66kV bus outage occur. To comply with our Safety Net at Bundaberg T020 bulk supply point restoration must be completed with an hour OR unserved load must be kept under 20MVA for the current 2 hour restoration time. We have determined that there will not be a non-network option that is a potential credible option, or that forms a significant part of a potential credible option. As per the “Screening for non-network options report”, we determined that the most appropriate technical and economic network solution to the Safety Net requirements is the establishment of 66kV and 132kV bus section circuit breakers and associated equipment at T020 Bundaberg. | 23 Apr 2018 | 25 May 2018 |
| Charleville (PDF, 1.4 MB) | Non-Network Options Report | The Static VAR Compensator (SVC) at Charleville zone substation is approaching the end of its design life and it is recommended for replacement on the basis of its age and reliability. The SVC performs the function of maintaining stable voltages at both high and low load times. The SVC also provides some Negative Phase Sequence (NPS) correction to address voltage balance issues associated with SWER networks.
The SVC is critical to the provision of ongoing voltage/VAR support, and to meet Ergon Energy’s corporate strategic objectives. Without reactive compensation, 66kV supply at Charleville and the far south western Queensland suffers from poor voltage regulation.
This report is an invitation to registered participants and interested parties to make submissions on credible options to address this identified need. | 12 Jan 2018 | 16 Apr 2018 |
| Charleville (PDF, 361.0 KB) | Non-Network Options Report | We need to revise the release dates for the forthcoming publications under the RIT-D process for Charleville 66kV Voltage Management. An updated timetable for the remaining steps of this RIT-D process is presented in this notice. | 13 Jun 2018 | |
| Charleville (PDF, 1.0 MB) | Draft Project Assessment Report | Ergon Energy published a Non-Network Options Report relating to the above described network constraints on 17 January 2018. Three submissions were received by the closing date of 16 April 2018.
This is a Draft Project Assessment Report (DPAR), where Ergon Energy provides both technical and economic information about possible solutions. Three potentially feasible options have been investigated in this DPAR document. | 26 Jul 2018 | 07 Sep 2018 |
| Charleville (PDF, 983.6 KB) | Final Project Assessment Report | This Final Project Assessment Report represents the final stage of the RIT-D process to address the identified need at Charleville. The NER requires the Final Project Assessment Report to include the preferred option under the RIT-D. This should be the option which is expected to maximise the present value of the net economic benefits to all those who produce, consume and transport electricity in the NEM. This Report presents the technical and economic analysis of the options received, and identifies the preferred solution. Ergon Energy’s preferred solution is Option C: Network Support Arrangement for the provision of reactive power via an external provider. | 22 May 2019 | 20 Jun 2019 |
| Emerald (PDF, 197.1 KB) | | The Expressions of Interest for Emerald Reactive Support closed on 21 March 2017. We have received four expressions of interest which potentially meet the reactive support needs for Emerald Zone Substation. Following due diligence, we will seek formal approvals through normal governance and provide further direction for the for proponents. | 21 Apr 2017 | |
| Garbutt (PDF, 850.6 KB) | Screening for Non-Network Options Report | Garbutt 132/66/11kV (T046) substation (GARB) is a Powerlink Queensland (PLQ) / Ergon Energy (EE) shared site with outdoor 132kV and 66kV assets and indoor 11kV assets, which supplies 48,500 customers and 86MVA of load (directly and indirectly). There is minimal forecast load growth at the substation however many assets are approaching or at the end of service life, with some equipment and the majority of structures 40-60 years old.
The only credible option is the network solution for Garbutt 66kV Switchgear replacement with 66kV gas insulated switchgear at the existing Garbutt Substation. The estimated preferred project cost is $28,381,619 with an estimated average annual maintenance cost of $52,029. The project delivery is commencing design in 2019/2020 and construction completed by 2021/2022.
Ergon Energy is publishing this notice under cl. 5.17.4(d) of the NER as it has determined that no non-network option is, or forms a significant part of any potential credible option. | 18 Jun 2018 | 31 Jul 2018 |
| South West Toowoomba (PDF, 2.2 MB) | Non-Network Options Report | The South Western edge of Toowoomba has experienced strong population and load growth in the communities of Westbrook, Drayton, Wyreema, Cambooya and Vale View. This growth is expected to continue. The existing Westbrook and Eiser St feeders predominantly supply these areas and are constrained in terms of voltage, capacity and performance of existing aged network. This report is an invitation to registered participants and interested parties to make submissions on credible options to address these constraints and identified need. | 04 May 2018 | 04 Aug 2018 |
| South West Toowoomba (PDF, 2.2 MB) | Draft Project Assessment Report | The South Western edge of Toowoomba has experienced strong population and load growth in the communities of Westbrook, Drayton, Wyreema, Cambooya and Vale View. This growth is expected to continue. The existing Westbrook and Eiser St feeders predominantly supply these areas and are constrained in terms of voltage, capacity and performance of existing aged network. 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 in the distribution network that supplies the SW area of Toowoomba. | 19 Oct 2018 | 30 Nov 2018 |
| South West Toowoomba (PDF, 3.1 MB) | Final Project Assessment Report | The South Western edge of Toowoomba has experienced strong population and load growth in the communities of Westbrook, Drayton, Wyreema, Cambooya and Vale View. This growth is expected to continue. The existing Westbrook and Eiser St feeders predominantly supply these areas and are constrained in terms of voltage, capacity and performance of existing aged network. This report represents the final stage of the consultation process in relation to the application of the Regulatory Investment Test for Distribution (RIT-D). As the non-network assessment has determined there are no credible non-network solutions, Ergon Energy plans to proceed with the proposed network solution. | 09 Jan 2019 | 14 Feb 2019 |
| West Toowoomba (PDF, 394.5 KB) | Screening for Non-Network Options Report | This notice has been prepared under clause 5.17.4(d) of the National Electricity Rules (NER) and summarises Ergon Energy's determination that no non-network option is, or forms a significant part of, any potential credible option for this RIT-D. | 17 Oct 2018 | |
| West Toowoomba (PDF, 982.3 KB) | Final Project Assessment Report | We have prepared this report in accordance with the requirements of clause 5.17.4(p) of the National Electricity Rules. A determination was made by us that there is not a non-network option that is a potential credible option to address the identified need at West Toowoomba substation. This report includes information relating to:
. A description of and the assumption used to identify the need
. A description of each option assessed by us
. Identification of our proposed preferred option, including:
- technical characteristics
- the estimated construction timetable and commissioning date
- indicative capital and operating cost | 23 Oct 2018 | 22 Nov 2018 |
| Garbutt (PDF, 1.3 MB) | Draft Project Assessment Report | Garbutt 132/66/11kV (T046) substation (GARB) is a Powerlink Queensland (PLQ) / Ergon Energy (EE) shared site with outdoor 132kV and 66kV assets and indoor 11kV assets, which supplies 48,500 customers and 86MVA of load (directly and indirectly). There is minimal forecast load growth at the substation however many assets are approaching or at the end of service life, with some equipment and the majority of structures 40-60 years old.
The only credible option is the network solution for Garbutt 66kV Switchgear replacement with 66kV gas insulated switchgear at the existing Garbutt Substation. The estimated preferred project cost is $28,381,619 with an estimated average annual maintenance cost of $52,029. The project delivery is commencing design in 2019/2020 and construction completed by 2021/2022.
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 at Garbutt Substation. | 18 Jun 2019 | 31 Aug 2019 |
| Cannonvale-Shute Harbour (PDF, 1.4 MB) | Non-Network Options Report | Cannonvale 66/11kV substation (CANN) and the surrounding 66 kV sub-transmission network supplies approximately 7,198 customers including major customers such as the Proserpine Sugar Mill, Hamilton Island, South Molle Island and Daydream Island.
The 66 kV sub-transmission network in the Cannonvale and Jubilee Pocket area consists of radial 66 kV timber pole lines with a number of sections of underground cable. There is currently no remote switching capability.
In its current state, due to the radial nature of the network and the reliance upon manual switching, a credible fault on the sub-transmission network in the Cannonvale and Jubilee Pocket area would mean that load cannot be restored within the requirements of the Safety Net security criteria, with this situation worsening as load increases.
This report is an invitation to registered participants and interested parties to make submissions on credible options to address this identified need. | 24 Jun 2019 | 19 Sep 2019 |
| Cannonvale (PDF, 1.5 MB) | Non-Network Options Report | Cannonvale 66/11kV substation (CANN) and the surrounding 66 kV sub-transmission network supplies approximately 7,198 customers including major customers such as the Proserpine Sugar Mill, Hamilton Island, South Molle Island and Daydream Island.
The 66 kV sub-transmission network in the Cannonvale and Jubilee Pocket area consists of radial 66 kV timber pole lines with a number of sections of underground cable. There is currently no remote switching capability.
In its current state, due to the radial nature of the network and the reliance upon manual switching, a credible fault on the sub-transmission network in the Cannonvale and Jubilee Pocket area would mean that load cannot be restored within the requirements of the Safety Net security criteria, with this situation worsening as load increases.
This report is an invitation to registered participants and interested parties to make submissions on credible options to address this identified need. | 24 Jun 2019 | 19 Sep 2019 |
| Planella (PDF, 2.2 MB) | Non-Network Options Report | Planella 33/11kV substation (PLAN), located on the northern beaches of Mackay, is supplied via a single radial wood pole 33 kV sub-transmission line between North Mackay (NOMA) 33/11 kV substation and Planella substation.
Under most circumstances, the wood poles of the 33 kV sub-transmission line are accessible; however in the event of periods of heavy rainfall and/or king tides, sections of the line become virtually inaccessible.
In its current state, a fault on this line in an inaccessible location would mean that load cannot be restored within the requirements of the Safety Net security criteria, with this situation worsening as load increases.
This report is an invitation to registered participants and interested parties to make submissions on credible options to address this identified need. | 24 Jun 2019 | 19 Sep 2019 |
