Distribution and Transmission
Annual Planning Report
December 2013
Disclaimer
Ausgrid is registered as both a Distribution Network Service Provider and a Transmission Network Service
Provider. This Distribution and Transmission Annual Planning Report 2013 has been prepared and published
by Ausgrid under clause 5.13.2 and 5.12.2 of the National Electricity Rules to notify Registered Participants
and Interested Parties of the results of the distribution and transmission network annual planning review and
should only be used for those purposes.
This document does not purport to contain all of the information that a prospective investor or participant or
potential participant in the National Electricity Market, or any other person or interested parties may require. In
preparing this document it is not possible nor is it intended for Ausgrid to have regard to the investment
objectives, financial situation and particular needs of each person who reads or uses this document.
In all cases, anyone proposing to rely on or use the information in this document should independently verify
and check the accuracy, completeness, reliability and suitability of that information for their own purposes.
Accordingly, Ausgrid makes no representations or warranty as to the accuracy, reliability, completeness or
suitability for particular purposes of the information in this document. Persons reading or utilising this
document acknowledge that Ausgrid and their employees, agents and consultants shall have no liability
(including liability to any person by reason of negligence or negligent misstatement) for any statements,
opinions, information or matter (expressed or implied) arising out of, contained in or derived from, or for any
omissions from, the information in this document, except insofar as liability under any New South Wales and
Commonwealth statute cannot be excluded.
Contact
For all enquires regarding the Distribution and Transmission Annual Planning Report 2013 and for making
written submissions contact:
Ausgrid
Manager – Asset & Network Planning
GPO Box 4009
Sydney NSW 2001
Email: ngordon@ausgrid.com.au
Contents
1 EXECUTIVE SUMMARY ................................................................................................................. 1 2 INTRODUCTION ............................................................................................................................. 2 2.1 About Ausgrid ...................................................................................................................... 2 2.1.1 Our Purpose and Vision ................................................................................................. 2 2.1.2 Our Principal Activities.................................................................................................... 3 2.1.3 Our Operating Environment ............................................................................................ 3 2.1.4 Ausgrid customer, demand and energy supply statistics ................................................ 4 2.2 Ausgrid’s Network ................................................................................................................ 4 2.2.1 Number and Types of Network Assets ........................................................................... 5 2.3 Annual Planning Review ...................................................................................................... 7 2.4 Ausgrid’s planning approach ................................................................................................ 7 2.4.1 Investment objectives and decision criteria .................................................................... 7 2.4.2 Network planning process .............................................................................................. 8 2.4.3 Network Area Plans ........................................................................................................ 9 2.5 Significant changes from previous DAPR ............................................................................ 9 2.6 Analysis and explanation of forecast changes ..................................................................... 9 2.7 Analysis and explanation of changes in other information ................................................... 9 3 FORECASTS FOR THE FORWARD PLANNING PERIOD ........................................................... 10 3.1 Load Forecasting Methodology .......................................................................................... 10 3.1.1 Assumptions applied to load forecasts ......................................................................... 10 3.1.2 Trasmission - distribution connection point load forecasts ........................................... 12 3.1.3 Sub-transmission feeder load forecasts ....................................................................... 12 3.1.4 Primary distribution feeder load forecasts .................................................................... 12 3.1.5 Notes on STS and ZS load forecast tables................................................................... 13 3.2 Camperdown and Blackwattle Bay Load Area ................................................................... 15 3.2.1 Description of Camperdown and Blackwattle Bay load area ........................................ 15 3.2.2 Sub-transmission feeder load forecast ......................................................................... 16 3.2.3 STS and ZS load forecast ............................................................................................ 16 3.3 Canterbury Bankstown Load Area ..................................................................................... 18 3.3.1 Description of Canterbury Bankstown area .................................................................. 18 3.3.2 Sub-transmission feeder load forecast ......................................................................... 20 3.3.3 STS and ZS load forecast ............................................................................................ 21 3.4 Carlingford Load Area ........................................................................................................ 23 3.4.1 Description of Carlingford area ..................................................................................... 23 3.4.2 Sub-transmission feeder load forecast ......................................................................... 24 3.4.3 STS and ZS load forecast ............................................................................................ 24 3.5 Eastern Suburbs Load Area ............................................................................................... 26 3.5.1 Description of Eastern Suburbs load area .................................................................... 26 3.5.2 Sub-transmission feeder load forecast ......................................................................... 27 3.5.3 STS and ZS load forecast ............................................................................................ 30 3.6 Greater Cessnock Load Area ............................................................................................. 33 3.6.1 Description of Greater Cessnock area.......................................................................... 33 3.6.2 Sub-transmission feeder load forecast ......................................................................... 34 3.6.3 STS and ZS load forecast ............................................................................................ 35 3.7 Inner West Load Area ........................................................................................................ 36 3.7.1 Description of Inner West area ..................................................................................... 36 3.7.2 Sub-transmission feeder load forecast ......................................................................... 37 3.7.3 STS and ZS load forecast ............................................................................................ 38 3.8 Lower Central Coast Load Area ......................................................................................... 40 3.8.1 Description of Lower Central Coast area ...................................................................... 40 3.8.2 Sub-transmission feeder load forecast ......................................................................... 42 3.8.3 STS and ZS load forecast ............................................................................................ 43 3.9 Lower North Shore Load Area ........................................................................................... 45 3.9.1 Description of Lower North Shore area ........................................................................ 45 3.9.2 Sub-transmission feeder load forecast ......................................................................... 46 3.9.3 STS and ZS load forecast ............................................................................................ 47 3.10 Maitland Load Area ............................................................................................................ 49 3.10.1 Description of Maitland area ......................................................................................... 49 3.10.2 Sub-transmission feeder load forecast ......................................................................... 50 3.10.3 STS and ZS load forecast ............................................................................................ 51 3.11 Manly Warringah Load Area .............................................................................................. 52 3.11.1 Manly Warringah area .................................................................................................. 52 3.11.2 Sub-transmission feeder load forecast ......................................................................... 54 3.11.3 STS and ZS load forecast ............................................................................................ 55 3.12 Newcastle Inner City Load Area ......................................................................................... 57 3.12.1 Newcastle Inner City area ............................................................................................ 57 Distribution and Transmission Annual Planning Report December 2013
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3.12.2 3.12.3 3.13 3.13.1 3.13.2 3.13.3 3.14 3.14.1 3.14.2 3.14.3 3.15 3.15.1 3.15.2 3.15.3 3.16 3.16.1 3.16.2 3.16.3 3.17 3.17.1 3.17.2 3.17.3 3.18 3.18.1 3.18.2 3.18.3 3.19 3.19.1 3.19.2 3.19.3 3.20 3.20.1 3.20.2 3.20.3 3.21 3.21.1 3.21.2 3.21.3 3.22 3.22.1 3.22.2 3.22.3 3.23 3.23.1 3.23.2 3.23.3 3.24 3.24.1 3.24.2 3.24.3 3.25 3.25.1 3.25.2 3.25.3 3.26 3.26.1 3.26.2 3.26.3 3.27 3.27.1 3.27.2 3.27.3 3.28 3.28.1 3.28.2 3.28.3 3.29 3.29.1 3.29.2 3.29.3 Sub-transmission feeder load forecast ......................................................................... 58 STS and ZS load forecast ............................................................................................ 59 Newcastle Ports Load Area................................................................................................ 60 Description of Newcastle Ports Load area.................................................................... 60 Sub-transmission feeder load forecast ......................................................................... 61 STS and ZS load forecast ............................................................................................ 61 Newcastle Western Corridor Load Area ............................................................................. 63 Description of Newcastle Western Corridor area .......................................................... 63 Sub-transmission feeder load forecast ......................................................................... 64 STS and ZS load forecast ............................................................................................ 64 North East Lake Macquarie Load Area .............................................................................. 66 Description of North East Lake Macquarie area ........................................................... 66 Sub-transmission feeder load forecast ......................................................................... 67 STS and ZS load forecast ............................................................................................ 68 North West Sydney Load Area ........................................................................................... 69 Description of North West Sydney area........................................................................ 69 Sub-transmission feeder load forecast ......................................................................... 70 STS and ZS load forecast ............................................................................................ 70 Pittwater and Terrey Hills Load Area.................................................................................. 71 Description of Pittwater and Terrey Hills area .............................................................. 71 Sub-transmission feeder load forecast ......................................................................... 73 STS and ZS load forecast ............................................................................................ 74 Port Stephens Load Area ................................................................................................... 75 Description of Port Stephens Load area ....................................................................... 75 Sub-transmission feeder load forecast ......................................................................... 76 STS and ZS load forecast ............................................................................................ 77 Singleton Load Load Area.................................................................................................. 78 Description of Singleton Load area .............................................................................. 78 Sub-transmission feeder load forecast ......................................................................... 79 STS and ZS load forecast ............................................................................................ 81 St George Load Area ......................................................................................................... 82 Description of St George load area .............................................................................. 82 Sub-transmission feeder load forecast ......................................................................... 83 STS and ZS load forecast ............................................................................................ 84 Sutherland Load Area ........................................................................................................ 85 Description of Sutherland load area ............................................................................. 85 Sub-transmission feeder load forecast ......................................................................... 86 STS and ZS load forecast ............................................................................................ 87 Sydney CBD Load Area ..................................................................................................... 89 Description of Sydney CBD load area .......................................................................... 89 Sub-transmission feeder load forecast ......................................................................... 90 STS and ZS load forecast ............................................................................................ 90 Upper Central Coast Load Area ......................................................................................... 91 Description of Upper Central Coast load area .............................................................. 91 Sub-transmission feeder load forecast ......................................................................... 92 STS and ZS load forecast ............................................................................................ 92 Upper Hunter Load Area .................................................................................................... 94 Description of Upper Hunter load area ......................................................................... 94 Sub-transmission feeder load forecast ......................................................................... 95 STS and ZS load forecast ............................................................................................ 96 Upper North Shore Load Area ........................................................................................... 98 Description of Upper North Shore load area................................................................. 98 Sub-transmission feeder load forecast ......................................................................... 99 STS and ZS load forecast ............................................................................................ 99 West Lake Macquarie Load Area ..................................................................................... 101 Description of West lake Macquarie load area ........................................................... 101 Sub-transmission feeder load forecast ....................................................................... 102 STS and ZS load forecast .......................................................................................... 102 Transmission Load Area - Central Coast ......................................................................... 104 Description of Central Coast Transmission load area ................................................ 104 Sub-transmission feeder load forecast ....................................................................... 106 STS and ZS load forecast .......................................................................................... 107 Transmission Load Area – Lower Hunter ......................................................................... 108 Description of Lower Hunter 132kV Transmission load area ...................................... 108 Sub-transmission feeder load forecast ....................................................................... 110 STS and ZS load forecast .......................................................................................... 112 Sydney Inner Metropolitan Transmission Load Area ....................................................... 113 Description of Sydney Inner Metropolitan Transmission load area ............................. 113 Sub-transmission feeder load forecast ....................................................................... 116 STS and ZS load forecast .......................................................................................... 121 Distribution 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Transmission - Distribution Connection Point load forecast ............................................. 121 3.30 3.31 Other factors having a material impact on the network .................................................... 122 3.31.1 Fault levels ................................................................................................................. 122 3.31.2 Voltage levels ............................................................................................................. 122 3.31.3 Other power system security requirements ................................................................ 122 3.31.4 Quality of Supply ........................................................................................................ 122 3.31.5 Ageing and potentially unreliable assets .................................................................... 122 4 PLANNING PROPOSALS FOR FUTURE NEEDS ...................................................................... 124 4.1 Proposed future transmission-distribution connection points ........................................... 124 4.2 Proposed future sub-transmission lines ........................................................................... 124 4.3 Proposed future Sub-transmission STS and Zone substations ........................................ 124 4.4 Future Sub-transmission and Zone substations loading levels ........................................ 125 4.4.1 Sydney and Central Coast Load Areas ...................................................................... 125 4.4.2 Hunter Load Areas ..................................................................................................... 125 5 IDENTIFIED SYSTEM LIMITATIONS .......................................................................................... 126 5.1 Notes on identified system limitations .............................................................................. 126 5.2 Sub-transmission Feeder Limitations ............................................................................... 127 5.3 Sub-transmission STS and Zone Substation Limitations ................................................. 136 5.4 Primary Distribution Feeder Limitations ........................................................................... 146 6 NETWORK INVESTMENTS ........................................................................................................ 147 6.1 Regulatory Tests completed during the year .................................................................... 147 6.1.1 Final Report- Jannali Zone Substation 11kV development ......................................... 147 6.1.2 Final Report- Raymond Terrace 11kV Feeders Upgrade ........................................... 148 6.1.3 Final Report- Rathmines Zone Substation 11kV Feeders .......................................... 149 6.1.4 Final Report- Nelson Bay (Anna Bay) New 11kV Development ................................. 150 6.1.5 Final Report- Nelson Bay New 11kV Development .................................................... 151 6.1.6 Final Report- Edgeworth New 11kV Development ..................................................... 152 6.1.7 Final Report- Kurri Kurri New Heddon Greta 11kV Development ............................... 153 6.1.8 Final Report- Kurri Kurri Zone Substation 11kV Feeders ........................................... 154 6.1.9 Final Report- Maitland Central New 11kV Development ............................................ 155 6.1.10 Final Report- Mosman Zone Substation Panel 18 20 22 29 and 42 Feeders ............. 156 6.1.11 Final Report- Greenacre Park 11kV Feeders ............................................................. 156 6.1.12 Final Report- Mosman Zone Substation 11kV Panel 24 41 and 43 feeders ............... 157 6.1.13 Final Report- Mosman Zone Substation 11kV Panel 9,10,17,23,30,32, 34 feeders ... 158 6.1.14 Final Report- Cardiff New 11kV Development ............................................................ 158 6.1.15 Final Report- Sefton Zone Substation 11kV Panel 16, 34, 35 feeders ....................... 159 6.1.16 Final Report- Thornton Zone Substation 11kV Development ..................................... 160 6.1.17 Final Report- Pelican 11kV Zone 11kV Development ................................................ 160 6.1.18 Final Report- South Eastern Flemington ZS 11kV Development ................................ 161 6.2 Regulatory Tests in progress during the year .................................................................. 162 6.2.1 Development of Alexandria 132/33kV STS ................................................................ 162 6.2.2 System limitations in circuits 9SA and 9SB/1 ............................................................. 162 6.2.3 Top Ryde Additional 132/11kV Transformer and 11kV Switchgear ............................ 163 6.3 Regulatory Investment Tests (RIT-D) for the forward planning period ............................. 164 6.4 Commited Investments .................................................................................................... 165 6.4.1 Refurbishment and replacement investments ............................................................ 165 6.4.2 Urgent and unforseen investments ............................................................................. 175 7 JOINT PLANNING ....................................................................................................................... 176 7.1 Joint Planning with TransGrid TNSP ................................................................................ 176 7.1.1 Process and Methodology .......................................................................................... 176 7.1.2 Joint TransGrid - Ausgrid planning completed in 2013 ............................................... 177 7.1.3 Planned Joint Transgrid-Ausgrid Network Investments .............................................. 177 7.1.4 Additional information ................................................................................................. 178 7.2 Joint planning with other DNSPs ...................................................................................... 178 7.2.1 Process & Methodology.............................................................................................. 178 7.2.2 Joint Ausgrid and other DNSP planning completed in preceding year ....................... 178 7.2.3 Planned DNSP Joint Network Investments ................................................................ 178 7.2.4 Additional information ................................................................................................. 178 8 NETWORK PERFORMANCE ...................................................................................................... 179 8.1 Reliability measures and standards ................................................................................. 179 8.1.1 Supply Reliability Standards ....................................................................................... 180 8.1.2 Supply reliability in the preceding year ....................................................................... 180 8.1.3 Service Target Performance Incentive Scheme (STPIS)............................................ 181 8.1.4 Forecast of Network Reliability Performance .............................................................. 181 8.1.5 Compliance with Network Reliability Standards ......................................................... 182 8.2 Quality of supply standards .............................................................................................. 183 Distribution and Transmission Annual Planning Report December 2013
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Voltage range for supplied electricity .......................................................................... 183 8.2.1 8.2.2 Harmonics and total harmonic distortion .................................................................... 184 8.2.3 Voltage fluctuations (flicker) ....................................................................................... 184 8.2.4 Voltage unbalance ...................................................................................................... 184 8.3 Quality of Supply Performance for preceding year ........................................................... 184 8.3.1 Supply voltage performance ....................................................................................... 185 8.3.2 Harmonic Content of Supply Voltage Waveform ........................................................ 185 8.3.3 Voltage Fluctuations (Flicker) performance ................................................................ 185 8.3.4 Voltage Unbalance performance ................................................................................ 185 8.3.5 Action planned to meet quality of supply standards ................................................... 185 8.3.6 Compliance with quality of supply standards .............................................................. 186 9 ASSET MANAGEMENT............................................................................................................... 187 9.1 Ausgrid’s asset management approach ........................................................................... 187 9.2 Asset Management Strategic Plan ................................................................................... 187 9.3 Risk Management strategies ............................................................................................ 188 9.4 Sub-transmission underground cables replacement strategy .......................................... 189 9.5 11kV switchgear asset management strategy .................................................................. 189 9.5.1 11kV compound switchgear replacement strategy ..................................................... 190 9.5.2 Air insulated switchboard replacement strategy ......................................................... 190 9.5.3 Outdoor 11kV switchgear replacement strategy ......................................................... 191 9.6 Distribution network losses .............................................................................................. 192 9.7 Obtaining further information on asset management ....................................................... 192 10 DEMAND MANAGEMENT ........................................................................................................... 193 10.1 Demand management...................................................................................................... 193 10.2 Demand management investigations in 2012-13 ............................................................. 194 10.3 Demand management projects implemented in 2012-13 ................................................. 195 10.4 Demand management innovation .................................................................................... 195 10.5 Forecast demand management projects .......................................................................... 196 11 INVESTMENTS IN METERING AND INFORMATION TECHNOLOGY....................................... 197 11.1 Metering ........................................................................................................................... 197 11.2 Information and communication technology ..................................................................... 198 11.2.1 Ausgrid’s ICT plan ...................................................................................................... 198 11.2.2 Description of key network related ICT systems ......................................................... 199 11.2.3 Smart Grid, Smart City ............................................................................................... 201 12 TRANSMISSION ANNUAL PLANNING REPORT 2013 UPDATE ............................................... 204 12.1 Transmission Annual Planning Report 2013 update ........................................................ 204 12.2 Transmission annual planning review .............................................................................. 204 12.2.1 Ausgrid’s responsibility as a registered TNSP ............................................................ 205 12.3 Developments since the publication of TAPR 2013 (June 2013) ..................................... 206 12.3.1 Dual function projects cancelled or deferred .............................................................. 206 12.3.2 Changes in dual function asset status ........................................................................ 206 12.4 Committed and Completed Dual Function Augmentations............................................... 208 12.4.1 Completed Augmentations ......................................................................................... 208 12.4.2 Committed Dual Function Augmentations .................................................................. 208 12.5 Planned Augmentations that have been subject to the Regulatory Test .......................... 210 12.6 Proposed dual function network developments ................................................................ 210 12.6.1 Constraints emerging within 5 years – proposed dual function assets ....................... 211 12.6.2 Constraints emerging within 5 years – consultation anticipated within 12 months ..... 212 12.6.3 Constraints emerging within 5 years –consultation anticipated beyond 12 months .... 212 12.6.4 Longer Term Constraints and Indicative Developments ............................................. 212 12.7 Dual Function Connection Points ..................................................................................... 213 12.7.1 Augmentation of existing dual function connection points .......................................... 213 12.7.2 Proposed new dual function connection points .......................................................... 214 12.8 Dual function replacement projects .................................................................................. 214 12.8.1 Identified dual function replacement projects ............................................................. 215 12.9 Urgent and unforeseen dual function projects.................................................................. 219 12.10 National Transmission Statement .................................................................................... 219 12.10.1 NSW Responsibility .................................................................................................... 220 12.11 Requests for Proposal...................................................................................................... 220 12.12 Demand Forecasts ........................................................................................................... 220 12.12.1 Ausgrid Network Global Peak Demand Forecasts ..................................................... 221 12.12.2 Dual Function Substation Demand Forecasts ............................................................ 222 13 APPENDIX 1 - GLOSSARY ......................................................................................................... 226 14 APPENDIX 2 - DESIGN, RELIABILITY & PERFORMANCE LICENCE CONDITION CRITERIA 227 Distribution and Transmission Annual Planning Report December 2013
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1
Executive Summary
On 11 October 2012 the Australian Energy Market Commission (AEMC) made a new National Electricity Rule
(NER) to establish a national Distribution Network Planning and Expansion Framework which is applicable to all
Distribution Network Service Providers (DNSPs) operating in the national electricity market. Commencing on 1
January 2013, this Rule requires all registered DNSPs to conduct an annual planning review and report on the
outcomes in a Distribution Annual Planning Report (DAPR).
This document presents the results of Ausgrid’s annual planning review covering all assets and activities carried out
by Ausgrid that could materially affect the performance of our network. The objective is to identify and report on
possible future network limitations, including network capacity constraints and aged or poor performing assets, and
the potential credible solutions to these limitations.
The DAPR portion of this document, Chapters 1 to 11, has been prepared to meet the requirements of the National
Electricity Rules Schedule S5.8 Distribution Annual Reporting Requirements and its objective is to:

Provide transparency to Ausgrid’s decision making processes to assist non-network providers, other Network
Service providers and connection applicants to make efficient investment decisions

Provide information on Ausgrid’s distribution assets planning process, including forecasting, identification of
network limitations, and the development of potential credible options to address these limitations covering a
minimum five year forward planning period

Report on the results of Ausgrid’s annual planning review, including STS and zone substation and subtransmission feeder forecast loading, identified network limitations including capacity, asset condition and
other limitations on the sub-transmission and distribution assets, and the potential credible solutions to
address these limitations

Provide third parties the opportunity to offer alternative proposals to the identified network needs, including
non-network solutions such as demand management or embedded generation

Provide timely indication of the planned commencement dates for the assessment of proposed projects that
will be subject the Regulatory Investment Test for Distribution, and

Provide information on Ausgrid’s demand management activities and actions taken to promote non-network
initiatives each year, including plans for demand management and embedded generation over the forward
planning period.
The DAPR covers a minimum five year forward planning period.
Ausgrid is also a registered Transmission Network Service Provider and is required to produce a Transmission
Annual Planning Report (TAPR) covering its 132kV dual function assets. To align the publication of the DAPR and
TAPR in future years, the two reports have been combined into one Distribution and Transmission Annual Planning
Report, as permitted under the NER. The TAPR 2013 update is presented as Chapter 12 of this document.
Distribution and Transmission Annual Planning Report December 2013
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2
Introduction
This Distribution and Transmission Annual Planning Report has been prepared to comply with National Electricity
Rules (NER) clause 5.13.2 Distribution Annual Planning Report (DAPR), and clause 5.12.2 Transmission Annual
Planning Report (TAPR).
With a five year forward planning horizon, this is the first DAPR to be published by Ausgrid. It reflects the outcomes
of the annual planning review of Ausgrid’s electricity network. The purpose of this document is to inform Registered
Participants, stakeholder groups and interested parties of the identified future network needs and the committed
and proposed solutions to these needs, and the potential opportunities for non-network solutions, particularly for
large investments where the Regulatory Investment Test for Distribution (RIT-D) applies.
Ausgrid’s DAPR has been prepared to meet the requirements of the National Electricity Rules Schedule S5.8
Distribution Annual Reporting Requirements to:

Provide transparency to Ausgrid’s decision making processes to assist non-network providers, other Network
Service providers and connection applicants to make efficient investment decisions

Promote efficient investment decisions in the electricity market

Include information on the planning process including forecasting, identification of network limitations, and the
development of potential credible options to address these limitations

Set out the results of Ausgrid’s annual planning review, including joint planning, covering a minimum five year
forward planning period for distribution assets

To give third parties the opportunity to offer alternative proposals to the identified network needs, including
non-network solutions such as demand management or embedded generation

Inform registered participants and interested parties on the outcomes of the annual planning review, including
network capacity and load forecasts for sub-transmission lines, zone substations and transmission-distribution
connection points, and any 11kV primary distribution feeders which are constrained or are forecast to be
constrained within the next two years

Provide information on Ausgrid’s demand management activities and actions taken to promote non-network
initiatives each year, including plans for demand management and embedded generation over the forward
planning period.
Ausgrid also owns, develops, operates and maintains dual function assets in NSW. Although these dual function
assets form part of our distribution network they are operated in parallel with TransGrid’s network, and essentially
perform a transmission function by supporting the NSW transmission network. Ausgrid is therefore also registered
as a TNSP and is required to publish a Transmission Annual Planning Report (TAPR) covering dual function
assets. The NER permit Ausgrid to publish its TAPR as part of the DAPR. An update to the Ausgrid TAPR 2013
published in June 2013 is presented as Chapter 12 - TAPR 2013 Update. This will align the publication of the
DAPR and TAPR in future years. The two reports have been combined into one Distribution and Transmission
Annual Planning Report.
2.1
About Ausgrid
Ausgrid is a NSW State Owned Corporation established under the Energy Services Corporations Act 1995 and the
State Owned Corporations Act 1989. We operate in the National Electricity Market (NEM) as both a distribution
network service provider (DNSP), and a transmission network service provider (TNSP).
Our electricity distribution network covers 22,275 square kilometres from Waterfall in Sydney’s south to Auburn in
western Sydney and north to the upper Hunter Valley. The network powers about half of the electricity customers in
NSW including residential and large and small business customers, as well as major industry including mining,
shipping, tourism, manufacturing and agriculture.
Ausgrid is committed to keeping electricity prices affordable for customers while delivering a safe, reliable and
sustainable network for the community.
2.1.1
Our Purpose and Vision
Ausgrid’s purpose is to be of service to its communities by efficiently distributing electricity to its customers in a way
that is safe, reliable and sustainable. Its values define the standard of ethical behaviour expected by the
community. These following values form the basis for everything done at Ausgrid:

safety excellence

respect for people
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2.1.2

customer and community focus

continuous improvement, and

act with integrity.
Our Principal Activities
Ausgrid is a NSW State Owned Corporation established under the Energy Services Corporations Act 1995
(administered by the Minister for Resources and Energy) and the State Owned Corporations Act 1989. Ausgrid’s
main activities are the safe management of its electricity network.
2.1.3
Our Operating Environment
Ausgrid is regulated by statutory and legislative requirements, including Work Heath and Safety (WH&S),
environmental, competition, industrial, consumer protection and information laws, the National Electricity and Gas
Law Rules, the NSW Electricity Supply Act 1995, and a NSW Distribution Network Service Provider licence.
Ausgrid manages compliance with these laws and regulations through its internal codes and policies and a
common control framework. This control framework comprises plans, policies, procedures, delegations, instruction
and training, audit and risk management.
The objectives of the corporation under the State Owned Corporations Act 1989 and the Energy Services
Corporations Act 1995 include requirements to:

operate efficiently and maximise the net worth of the State’s investment

operate an efficient, safe and reliable network, and

be socially responsible, having an active regard for the interests of the community and the environment.
Ausgrid’s operations are guided by a number of important policies and codes, including a Code of Conduct, Safety
Policy, Environmental Code of Conduct and Policy and Statement of Business Ethics. The organisation publishes a
Statement of Corporate Intent, outlining its strategies, risks and operational and commercial objectives.
As a result of the NSW Government reforms to state-owned electricity networks since 1 July 2012, the three NSW
Government owned electricity distribution networks Ausgrid, Endeavour Energy and Essential Energy continue to
operate as separate legal entities but are managed by a joint Board of Directors and common Chief Executive
Officer (CEO).
A key objective of the NSW Government’s reform program for its electricity distribution businesses is to deliver
more than $400 million in cost and efficiency savings over four years to assist electricity consumers, particularly
those receiving Low Income Household and Family Energy rebates. These savings at Ausgrid are being delivered
through more streamlined corporate and support services, reducing duplication, more efficient capital spending and
strategic procurement. The industry reforms also aim to deliver a more efficient, lower cost electricity distribution
service to customers – one that is financially sustainable, minimises waste and maintains the reliability of the
network in a way that is safe for its employees and the public.
Ausgrid is subject to the National Electricity Law (NEL) and National Electricity Rules (NERs) which regulate the
National Electricity Market. Ausgrid operates in the National Electricity Market (NEM) as both a distribution and
transmission network service provider (DNSP and TNSP). The National Electricity Objective (NEO), as stated in the
National Electricity Law is to:
“promote efficient investment in, and efficient operation and use of, electricity services for the long term interests of
consumers of electricity with respect to:
(a)
price, quality, safety, reliability and security of supply of electricity; and
(b)
the reliability, safety and security of the national electricity system.”
This objective requires Registered NEM participants to balance the costs and risks associated with electricity
supply.
Distribution and Transmission Annual Planning Report December 2013
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2.1.4
Ausgrid customer, demand and energy supply statistics
Number at end of
2011/12
Number at end
of 2012/13
1,627,948
1,642,353
Distribution Customer Numbers – Sydney East Region
321,360
326,028
Distribution Customer Numbers – Sydney South Region
479,182
485,836
Distribution Customer Numbers – Sydney North Region
386,135
388,924
Distribution Customer Numbers – Newcastle Region
200,493
199,759
Distribution Customer Numbers – Central Coast Region
158,668
158,045
Distribution Customer Numbers – Lower Hunter Region
52,695
53,679
Distribution Customer Numbers – Upper Hunter Region
29,415
30,082
Maximum Demand (Aggregated System MW)
5,149
5,659
Energy Received by Dist Network to Year End (GWh)
30,463
27,401
Energy Distributed to Year End (Residential) (GWh)
8,892
8,527
Energy Distributed to Year End (Non-Residential Including unmetered supplies) (GWh)
20,453
17,789
Energy Distributed to Year End (GWh)
29,345
26,316
System Loss Factor (%)
3.67%
3.96%
Distribution Customer Numbers (Total)
Table 1 – Ausgrid distribution network customers, maximum demand and energy
NOTE:
2.2
System Loss Factor (%) is the difference between electricity received by the distribution network and
electricity received by customers (including un-metered supplies) divided by electricity received by the
distribution network (allowing for embedded generation), expressed as a percentage.
Ausgrid’s Network
In 2012/13, Ausgrid’s network supplied more than 26,316GWh of electricity to more than 1.64 million network
customers. Our distribution area (Figure 1) covers an area of 22,275 square kilometres and includes some of the
most densely populated and fastest growing areas of NSW. We supply customers as far north as the Upper Hunter
Valley and as far south as Waterfall, and Auburn in Sydney’s west.
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Figure 1: Ausgrid’s Network Area
2.2.1
Number and Types of Network Assets
Ausgrid’s sub-transmission and distribution network includes:

a dual function sub-transmission system of 132kV assets (formerly referred to as transmission system)

a sub-transmission system of 33kV, 66kV and 132kV assets

a high voltage distribution system of 5kV and 11kV assets, and

a low voltage distribution system of 240V and 415V assets.
Ausgrid operates an extensive network of 132kV assets which are directly connected to TransGrid’s NSW main
transmission network. Where these 132kV assets are operated in parallel and provide transmission services to
support TransGrid’s network they are defined as dual function assets under the NER. Ausgrid is therefore also
registered as a Transmission Network Service Provider. Dual function assets are regulated by the Australian
Energy Regulator (AER) as if they were part of the distribution system for the purposes of revenue and are subject
to the economic evaluation, and public notification and consultation requirements of the Regulatory Investment Test
for Distribution (RIT-D).
Distribution and Transmission Annual Planning Report December 2013
5
Table 2 – Ausgrid network statistics
Distribution Network Assets
2011/12
2012/13
1,024
789
42
42
3,624
3,534
Substations - Zone (ZS)
188
192
Substations - Distribution
30,860
31,070
High Voltage Overhead (km)
10,159
10,117
High Voltage Underground (km)
7,634
7,822
Low Voltage Overhead (km)
13,642
13,060
Low Voltage Underground (km)
5,494
5,638
56
55
Dual Function (Transmission support) System – 132kV (km)
Substations - Sub-transmission (STS)
Sub-transmission System - 33kV, 66kV and 132kV (km)
Feeder Numbers CBD
Feeder Numbers Urban
1,751
1,733
Feeder Numbers Short Rural
293
287
Feeder Numbers Long Rural
4
4
Pole (number)
513,025
514, 190
Streetlights (number)
252, 955
253,881
Figure 2: Typical components of an electricity network
Distribution and Transmission Annual Planning Report December 2013
6
2.3
Annual Planning Review
The NER require that the annual planning review includes the planning for all assets and activities carried out by
Ausgrid that would materially affect the performance of its network. This includes planning activities associated with
replacement and refurbishment of assets and negotiated services. The objective of the annual planning review is to
identify possible future issues that could negatively affect the performance of the distribution network to enable
DNSPs to plan for and adequately address such issues in a sufficient timeframe.
This Distribution Annual Planning Report provides information to Registered Participants and interested parties on
the nature and location of emerging constraints on Ausgrid’s sub-transmission and 11kV distribution network
assets, commonly referred to as the distribution network. The timely identification and publication of emerging
network constraints allows the market to identify potential non-network options and Ausgrid to develop and
implement appropriate and timely solutions.
2.4
Ausgrid’s planning approach
The network planning and development process for both distribution and transmission networks is carried out in
accordance with the National Electricity Rules (NER) Chapter 5 Part B Network Planning and Expansion which
commenced in January, 2013. Planning for distribution and sub-transmission assets is carried out in accordance
with NER 5.13.1 - Distribution annual planning review, and in accordance with NER 5.12.1-Transmission annual
planning review for dual function assets.
2.4.1
Investment objectives and decision criteria
Ausgrid’s investments objectives respond to one or more of three key policy directives:

Comply with its obligations under Chapter 5 of the National Electricity Rules (NER); the Design, Reliability and
1
Performance Licence Conditions ; and other applicable regulatory instruments

Manage business risks with particular regard to ensuring the safety of its employees, customers and the
broader community; maintaining the reliability of supply to its customers; and protecting the environment; and

Improve the efficiency of the business or produce a net benefit to the community.
To provide a sound and consistent approach, decisions to invest are made based on (as appropriate):

Clearly defined requirements in terms of legislative obligations and identified risks

Compliance with Ausgrid’s policies and standards

Sound risk assessment (safety, performance, environmental, financial, community impact)

Consideration of whole-of-life costs and benefits taking into account the time-value of money

Consideration of the range of feasible solutions without bias for technology, and

A level of analysis which is commensurate with the costs and risks.
In compliance with the requirements of the National Electricity Objective and various elements of the NER,
investments in the network are made on the basis of best economic value to all producers and consumers of
electricity in the National Electricity Market (NEM). Network investments options are selected where they deliver the
highest Net Present Value (NPV), taking into account the costs, risks and benefits where material. Where
investments are required to meet regulatory obligations, the NPV may be negative.
Ausgrid’s investment processes are designed to deliver consistent, efficient and transparently prudent decisions.
The processes promote:

Efficient and prudent investments consistent with its stated investment objectives

Timely identification of the business’s capital and resource requirements

Investment decisions that are informed by a full understanding of the costs, benefits and regulatory
requirements and are authorised in accordance with the business’s internal delegations policy

Compliance with statutory and regulatory obligations to the Board, stakeholders, shareholders, broader
community, regulators and appointed auditors

Co-ordination with related organisations, including other network service providers and utilities, and

Investment opportunities being prioritised to best meet the objectives of the corporation and reviewed at Board
level.
1
Refer to Appendix 2- Design, Reliability & Performance Licence Condition Criteria
Distribution and Transmission Annual Planning Report December 2013
7
2.4.2
Network planning process
Ausgrid follows a structured planning process that can be summarised by the following diagram. The planning
phase involves identifying the investment needs and risks; developing one or more options to address these needs;
assessing those options to select the preferred option and initiating the preferred option.
Figure 3: Ausgrid Planning Process
The timeframe and complexity of this process varies according to network type, risk profile, and the project scale
and intent Accordingly, Ausgrid organises its planning activities by distinct investment categories. This approach
allows Ausgrid to adopt a level of analysis and justification that is commensurate with the costs, risks and
obligations associated with each investment category discussed below:
Major projects
These are generally sub-transmission major investments to meet the needs of the network, in particular demand
growth, voltage, power quality, fault duty, stability and asset renewal requirements. These investments are made
through an Area Planning process to meet the requirements of large geographic areas and consider obligations
holistically over a 20 year investment window to capture synergies between major projects. Detailed analysis
considering a number of alternatives is typical. These plans comprise of a relatively small number of high cost
investments.
Asset Replacement and Network Risk
These are generally investments to manage risk associated with the age and condition of assets, or that would
otherwise affect the safe and reliable operation of the network. Investment is either to meet specific obligations and
standards; or justified based on an assessment of the risk (e.g. determined from condition assessments and
historical performance) compared to the cost required to mitigate that risk. Investments usually involve programmes
of work that comprise of a large volume of lower cost projects to address the risk posed by a group of similar
assets.
Distribution (generally 11kV)
Investments to meet the needs of the distribution network, in particular demand growth, voltage, power quality and
fault duty requirements. These investments are to meet the requirements of inter-connected portions of the
distribution network considering a five year investment window. Analysis will depend on the scale and complexity of
the project.
Customer Connections
These investments are for the reinforcement of the up-stream portion of the shared network that is not funded by a
specific customer. Investments are initiated by applications for a customer connection. Forward investment is
forecast based on historical trends at a system level.
Reliability
These investments address gaps in reliability performance that will not be met by the other investment categories.
Proactive investments are planned to respond to forecasts of reliability performance considering investments
planned under other investment categories; and reactive investments are determined through an assessment of
reliability outcomes based on actual performance.
Distribution and Transmission Annual Planning Report December 2013
8
2.4.3
Network Area Plans
To ensure Ausgrid’s investment is prudent and efficient, planning of major investments in the network:

Is based on meeting the requirements of geographic areas, defined on the basis that they represent discrete
electrical areas and with relative independence from network interconnections

considers Ausgrid’s obligations under the National Electricity Rules and other applicable regulatory instruments
in a holistic manner

considers identified needs over a twenty year planning horizon to allow for the development of a long term
strategy that maximises synergies between drivers and minimises long term cost.
Ausgrid’s plans are documented in ‘Area Plans’, covering the identified network needs, potential credible options
and the preferred solution for each geographic area. For the purposes of planning investments to meet the needs of
the sub-transmission network, Ausgrid has divided its network into 25 geographic ‘Areas’ and generates an ‘Area
Plan’ for each geographic ‘Area’. The requirements of the Ausgrid 132kV network that links TransGrid’s bulk supply
points to Ausgrid’s sub-transmission network are considered based on the broader Sydney Inner Metropolitan,
Central Coast and Lower Hunter regions to create three ‘Transmission Area Plans’. Each of these regions
encompasses multiple ‘Areas’.
Projects that comprise the preferred strategy for each Area Plan are entered in the Major Project List (Project List)
with each project initiated based on this list and on expected project lead times, and in accordance with Ausgrid’s
Investment Initiation Standard. The Project List records the identified system limitation and need date, the required
completion date and the estimated cost for each project.
The Area Plans are reviewed on approximately a three year basis. In order to optimise project implementations, the
identified need date of projects within the Major Project List is reviewed annually as new information and forecasts
become available. Any changes to the projects within the Project List are recorded, including the cause of the
change. This Project List also forms the basis of the economic assessment, consultation and reporting requirement
under the Regulatory Investment Test for Distribution (RIT-D).
2.5
Significant changes from previous DAPR
This document is the first DAPR required to be published under NER Chapter 5 Part B Network planning and
expansion which commenced on 1 January 2013. There are therefore no significant changes from previous DAPR
to report.
2.6
Analysis and explanation of forecast changes
Future DAPRs will discuss significant changes to STS and ZS forecasts, sub-transmission feeder forecasts.
2.7
Analysis and explanation of changes in other information
Future DAPRs will discuss:

significant changes to proposed solutions (network or non-network) to address system limitations, project
timing, deferral, and cancellation

significant changes to proposed replacement projects >$2m - timing, deferral, cancellation

significant changes to proposed RIT-Ds - timing changes, deferral, and cancellation.
Distribution and Transmission Annual Planning Report December 2013
9
3
Forecasts for the forward planning period
3.1
Load Forecasting Methodology
This section describes the maximum demand forecasting methodology (the forecast) used by Ausgrid for zone
substations and sub-transmission substations. Ausgrid’s distribution network load forecasts are developed in
conjunction with the dual function asset load forecasts each year.
The forecasts of peak demand are prepared at the sub-transmission substation level and at the zone substation
level. These spatial forecasts form a key input to the planning of the demand driven capital expenditure program.
They take into account local trends and the utilisation of specific assets to service particular regions during peak
times.
The forecast is prepared seasonally for summer and winter.
A brief description of the forecasting methodology follows:
Gather necessary data:
3.1.1
3.1.1.1

Raw demand data is taken from zone substations and sub-transmission substations in 15min intervals

Weather data is taken from Bureau of Meteorology weather stations across the network

Network configuration data is taken from planning and customer connections

The demand data is screened to remove abnormal loads (generally resulting from network switching and
abnormal configurations). This prevents abnormally switched loads from distorting trends

The remaining valid historical loads are then weather corrected based on the variable of “average apparent
temperature”, and subjected to Monte Carlo simulation analysis. This enables calculation of probability of
exceedance (POE) levels. Jurisdictional requirements for NSW stipulate that the forecast for planning purposes
must be 50% POE

The weather corrected loads are adjusted to reverse out the effect of historical load transfers and spot loads to
reveal the underlying trend. Growth rates and the starting point for the forecast are calculated using a line of
best fit

This trend is adjusted, if necessary, to take account of any anticipated local factors, such as Local Government
area plans, that are expected to change the base growth rate in that area

Then, future committed spot loads and load transfers are superimposed over the base growth trend line for in
the first three years

Beyond this point, it is no longer assumed that the future will be driven by the statistical analysis of the past,
and regional econometric growth rates are used to adjust the growth rate at each substation for the medium to
long term. The regional econometric growth rates are determined by modelling the residential and nonresidential customer segment separately. The residential segment is based on an end-use model using
projected residential customer numbers, projected changes in average annual electricity consumption per
customer, expected impacts of solar PV penetration, expected impacts of the NSW Energy Savings Scheme
and air conditioning penetration and saturation. The non-residential segment is estimated using an
econometric model based on NSW gross state product and electricity price. The residential and non-residential
estimates are then combined.
Assumptions applied to load forecasts
Customer negotiated capacity
Where a customer has negotiated a higher standard of service than the default in the Licence Conditions and the
agreed financial terms have been met, the substation load forecast is adjusted accordingly so that this capacity is
reserved for that customer.
If a customer has negotiated a lower standard of service (e.g. to reduce their costs), this is generally not
incorporated into the forecast. Generally these requests are considered during network planning, or inherent in the
connection of the customer.
3.1.1.2
Embedded generation
The historical load data includes the impact of downstream embedded generation that was generating at the time of
peak, consequently, the forecast includes the impact of small scale generation (such as rooftop solar installations.
Where a generator has a material impact on peak load that is not accurately reflected in the historical data and
information is available about generator output and reliability, the forecast is adjusted to reflect the expected impact
of the generator, taking into account:
Distribution and Transmission Annual Planning Report December 2013
10

the historical reliability of the generator and expectations about its future reliability, including weather
dependency where relevant

when the generator was installed and whether it is a temporary or permanent installation

contractual obligations for Ausgrid to provide backup or standby supply to a site, and

network support agreements with the generator.
Larger generators that are relied on for network support are generally included as a negative spot load. In
determining whether a generator is ‘large’, Ausgrid uses the same approach as is used for spot loads and transfers.
3.1.1.3
Capacitors for power factor correction
Reactive compensation for locations with known capacitor installations is modelled according to the following
guidelines:
3.1.1.4

Growth rates are applied to the uncompensated MVAr component of load prior to switching in capacitors. In
other words, growth rates are not applied to capacitors

The amount of reactive compensation for forecast years is applied according to the step size and maximum
available MVAr capacity such that the resultant power factor is as close to unity as possible, but does not result
in a leading power factor.
Weather correction and load normalisation
Historical loads are weather corrected and load normalised, to enable statistical trend line calculation of growth
rates and the determination of probabilistic forecast loads. The weather correction and load normalisation factor is
the percentage difference between the weather corrected and actual load in the most recent historical year. This
correction factor can be negative, positive or zero.
Weather correction and load normalisation is applied according to the following rules:
maximum demands are weather corrected and normalised with a probability of exceedance of 50% (POE50)
3.1.1.5

each substation uses Bureau of Meteorology (BOM) data from the geographically closest BOM weather station

apparent temperature is used, which includes the effects of humidity, wind speed and ambient temperature,
and

weather correction and load normalisation is applied using a Monte-Carlo simulation method to determine the
POE50 maximum demand. The simulation incorporates non-working days to model the effect of substations
that can peak on a non-workday.
Exceptions for weather correction and load normalisation
Weather correction and load normalisation is not applied to zone substations or sub-transmission substations
where the load does not exhibit weather dependency for that season, or where the load exhibits weather
dependency that does not follow the general trend expected for that season based on an examination of the
seasonal load versus temperature relationship. Weather correction and load normalisation is not applied to
dedicated customer loads (connected at the sub-transmission level).
3.1.1.6
Rate of growth
The rate of growth, which may be negative, is calculated according to the following process:
3.1.1.7

the historical spot loads and transfers are adjusted out of the historical weather corrected loads to reveal the
underlying trend

the weather corrected and adjusted trends are reviewed by an expert panel to consider factors that could
influence the growth rates, such as Local Government Plans

a range of econometric factors are incorporated from the 4th year onwards via an adjustment to the growth
rates, and

a growth rate of zero is applied to dedicated customer loads (connected at the sub-transmission level).
Spot loads and transfers
Spot loads and transfers are included after the application of growth rates. A spot load or transfer can result in
either an increase or decrease in the forecast load (e.g. load can be transferred to or from a zone substation).
Only spot loads and transfers for committed projects are included in the forecast. All load transfers are included in
the forecast. Spot loads are included according to the following guidelines:
Distribution and Transmission Annual Planning Report December 2013
11
Substation Capacity
Forecast Includes aggregate of spot
loads per year if greater than
Non-firm substations (<10MVA peak load)
10A @ 11kV (approx 0.2 MVA)
Substations with firm capacity between 10 to 25MVA
25A @ 11kV (approx 0.5 MVA)
Substation with firm capacity >25MVA
50A @ 11kV (approx 1 MVA)
In addition to the above table, distribution planners may apply some discretion to include spot loads that are
considered abnormal for a given area. For example, a small industrial spot load in an area dominated by residential
load would be considered abnormal for that area, even if the spot is below the numeric threshold. Similarly, a
cluster of small spot loads resulting from a local council zoning change to an area would be considered as a single
spot load increase for each year.
A scaling factor of 80% is applied to spot loads at zone substations to reflect the difference between the capacity
applied for as part of a customer connection application, and the eventual load from that connection. The
exceptions to this rule are major customer connections and Sydney CBD, where this scaling factor is already
applied.
3.1.2
Trasmission - distribution connection point load forecasts
Ausgrid produces a ten year forward planning period forecast of loads (MW and MVAr) for each dual function subtransmission substation and zone substation that provides material support to TransGrid’s transmission network.
The transmission-distribution connection point forecasts are presented in the TAPR 2013 update in 12.8.3 - Dual
Function Substation Demand Forecasts, and are based on the forecast information contained in the “132kV
TransGrid Report” which is provided to TransGrid by the end of May each year.
3.1.3
Sub-transmission feeder load forecasts
Ausgrid undertakes an annual review of sub-transmission feeder capacity constraints (“the feeder load forecast”)
using load-flow analysis to simulate credible network contingencies and identify limitations. The criteria for
determining these limitations and any acceptable levels of risk which can be taken are defined in Schedule 1 of the
NSW Distribution Licence conditions. With the pending change to the licence conditions from 1st July 2014, Ausgrid
has begun assessing network limitations using a more risk-based approach.
Initial analysis is conducted using network load-flow models for a forward looking 20 year period, based on:

A 50% POE Base Spatial Demand Forecast, including committed spot loads

Committed network developments and load transfers

Line and cable cyclic normal and long-term emergency ratings.
The results of this analysis form an input into the Area Planning process and the Annual Capital Review process. A
second series of studies – the ‘Development Feeder Forecast’ – is completed following this initial review, using a
set of models which includes proposed projects (such as those investigated to resolve identified capacity
constraints or other issues such as reliability or network condition) and anticipated load transfers and spot loads.
Any identified feeder limitations are again assessed to ensure that any anticipated future changes do not adversely
affect the performance of the network, and the results of this analysis is fed back into the Area Planning and Annual
Review processes.
3.1.4
Primary distribution feeder load forecasts
Ausgrid’s primary distribution feeder forecast is derived from the historical seasonal peak loads of distribution
feeders. Peak load values are identified for a season with standard temperature variation and normal switching on
the distribution network. The process for identifying and forecasting distribution peak loads may be triggered by:

A licence compliance check performed for every primary distribution feeder in the CBD on an annual cycle and
for other locations on a 2.5 year cycle

An identified need for an 11kV load transfer

A High Voltage customer connection, or

other distribution feeder identified needs.
The connecting zone substation historic peak load data is reviewed to identify the summer and winter peak day and
night loads. SCADA 15 minute interval load data is used to identify the peak loads for the primary distribution
feeders. Any inconsistencies between the zone substation and the primary distribution feeder SCADA data, as well
as any abnormal load switching are identified. If there is no evidence of abnormal switching the primary distribution
feeder peak load value can be assessed as normal and no further analysis of the historic load is required. If there is
Distribution and Transmission Annual Planning Report December 2013
12
any evidence of abnormal switching further investigations are carried out to get a more accurate understanding of
what may have influenced the peak load value to determine the actual load value that will be used as the peak load
value for that primary distribution feeder. The weather correction applied to the connecting zone substation load is
also applied to the primary distribution feeder if appropriate.
The associated zone substation forecast load rate of growth (ROG) value for a forward planning period covering the
next 6 years is applied to the primary distribution feeder peak load value, considering the following factors:

Maximum Demand Indicators (MDI)

Customer types i.e. residential, industrial, or commercial

Load sizes and types

Constant loads e.g. pumping stations

Local knowledge of the network

Spot loads and load transfers to other locations.
This primary distribution feeder peak load value is then applied in a network modelling tool based review of the
primary distribution feeder loading and compliance, or as triggered by other events as shown in Figure 4 below.
Figure 4: Primary distribution feeder load forecast process
3.1.5
Notes on STS and ZS load forecast tables
Limitation refers to whether the substation is limited to N-1 or N by its configuration. Small or temporary substations
may operate in a non-secure manner, these are marked as limited to N and must have load less than 10MVA.
The substation Total Capacity is the maximum load able to be carried by the substation with all elements in service.
Substations limited to N must ensure their Total Capacity exceeds the forecast load by at least 15%.
The Firm Capacity of a substation is the capacity with one major piece of apparatus out of service for subtransmission substations (STS) and suburban zone substations, and two pieces of apparatus out of service for
Sydney CBD zone substations. This is often referred to as its N-1 rating for STS and suburban zone substations,
and N-2 rating for Sydney CBD zone substations. Sub-transmission substations and CBD zone substations are
considered to be constrained when the load exceeds the Firm Capacity. Suburban zone substations are considered
to be constrained when the Hours > Firm Capacity exceeds 1% of the year annually (88 hrs) or the Load / Firm
capacity exceeds 120%, or where N capacity does not meet at least 115% of forecast demand except where
substation rating is limited by underground feeders or where exceeding Firm Capacity will result in the thermal
rating of apparatus being exceeded in its normal configuration. In the case of these N-1 limited substations the load
may not exceed Firm Capacity.
Any future forecast changes to substation Firm Capacity and Total Capacity are based on assumptions as to the
effects of future committed projects. The voltage levels of our sub-transmission substations are nominally 132kV on
the primary and either 66kV or more usually 33kV on the secondary. The voltage levels of our zone substations are
Distribution and Transmission Annual Planning Report December 2013
13
nominally either at 132kV, 66kV or 33kV on the primary side of the transformers and 11kV (or 5kV in some rare
cases) on the secondary side.
Forecast rating changes have only been included where the associated project has been given approval, and is a
committed project at the date of preparation of the forecast. Power factor recordings correspond to the power factor
at time of peak load.
The Solar PV capacity by zone substation is based on the most recent available information recorded in Ausgrid’s
data systems at the end of September 2013. The solar generation capacity is based on information gathered and
recorded from the application for connection forms completed at the time of applying for a solar installation.
Embedded generation “Other” includes all known diesel, landfill biogas, coal seam methane, natural gas including
tri-generation and co-generation, hydro and mini hydro, coal washery, and waste heat recovery generating units
know to Ausgrid. Not all of these units export to the grid. Many of these units are not capable of operating in parallel
with the Ausgrid network to export to the grid and are intended for standby operation in island mode.
To calculate the “95% of peak load exceeded hours/year” Ausgrid analysed the demand profile of each zone
substation and STS within the network using one of 5 standard Load Cycle demand profiles. A load duration curve
(LDC) was then produced for each standard load cycle. The percentage of time within 95% of peak load for each
zone substation was determined from the LDC of each load cycle type and multiplied by the total number of hours
within the analysed season.) The “hours within 95% of peak” value was then allocated based on the assigned
standard load cycle type for each zone substation (ZS) and sub-transmission substation (STS).
3.1.5.1
Load transfer capacities of Zone Substations
Load transfer capacity is the load that can be permanently transferred from one substation that has become
constrained under current licence capacity, to a nearby substation which still has spare licence capacity, through
permanent switching utilising the capacity of the existing network (as determined by any thermal rating, voltage
drop, or fault level limitations).
The DAPR reports forecast load transfer capacity for those years in the five year planning period when a ZS load
forecast exceeds the licence capacity based on the peak MVA and time. Once the load transfer capacity available
by switching the network is forecast to be exceeded, Ausgrid would need to seek a solution (network or nonnetwork) to either augment the available capacity or manage the limitation with demand management.
Edgeworth 33/11kV ZS > 2.1
2017/18
-
2.1
-
Tarro 33/11kV ZS
2016/17
-
2.4
-
Argenton
132/11kV
ZS
Thornton
33/11kV
ZS
-
Maitland
33/11kV
ZS
Telarah 33/11kV ZS
1.0
>0.7
2018/19
-
0.6
Distribution and Transmission Annual Planning Report December 2013
Summer
Comments
Winter
Does
available
transfer
defer
constraint
to >2018?
Winter
Transfer
Capacity
Available
(MVA)
Summer
Winter
Transfer To
Substation
Summer
Winter
Transfer
required to
defer
constraint to
>2018 (MVA)
Summer
Summer
Winter
Year of
Constraint
Winter
Substation
Load
Transfer
Capacity
(MVA)
Summer
Load Transfer Capacity of Zone Substations
-
3.6
-
YES
-
-
1
-
NO
-
-
0.7
-
YES
-
Minimum 3.6MVA transfer
capacity exists away from
Edgeworth.
Maximum 1MVA transfer
capacity exists away from
Tarro.
Maitland ZS will replace
Maitland Central ZS in S
13/14. Minimum 0.7MVA
transfer capacity exists
away from Telarah.
14
3.2
3.2.1
Camperdown and Blackwattle Bay Load Area
Description of Camperdown and Blackwattle Bay load area
The Camperdown and Blackwattle Bay network area is a predominantly urban area on the fringe of the Sydney
CBD. It includes high-density residential developments and commercial areas such as Darling Harbour, Broadway,
Pyrmont and Camperdown. A small geographical area, it is supplied by Darling Harbour 132/11kV Zone Substation
(ZS), and the Camperdown and Blackwattle Bay 33/5kV zone substations. These are the two remaining Zone
Substations in Ausgrid’s network that supply electricity at 5kV.
Camperdown ZS, Blackwattle Bay ZS and Darling Harbour ZS supply the suburbs of Pyrmont, Ultimo, Glebe,
Camperdown, Forest Lodge and Annandale. Camperdown ZS also supplies the University of Sydney.
Pyrmont STS is also included in the Camperdown and Blackwattle Bay network area. Supply at 33kV is provided
from Pyrmont STS to two major customers: Railcorp and Global Switch (a data centre).
The network in the Camperdown and Blackwattle Bay area has the following characteristics:

Darling Harbour ZS and Pyrmont STS are located in the same building and are both supplied at 132kV from
Haymarket Bulk Supply Point (BSP)

Blackwattle Bay ZS is supplied via four short 33kV cables from Pyrmont STS

Camperdown ZS is supplied via three 33kV cables direct from Bunnerong North STS and one 33kV cable from
Canterbury STS

Pyrmont STS currently supplies Blackwattle Bay ZS and two major customers (Railcorp & Global Switch). It
provides a limited alternative supply to City East ZS. Work is currently underway to retire the existing City North
ZS. This will free up capacity and 33kV connections at Pyrmont STS.
The distribution system in the Camperdown and Blackwattle Bay area is comprised of a significant number of 5kV
cables, which are among the oldest in Ausgrid’s system. Ausgrid’s policy is to progressively replace these cables
with 11kV assets. This will increase operational flexibility by allowing load transfers between adjacent zone
substations if required.
Figure 5: Camperdown Load Area
Distribution and Transmission Annual Planning Report December 2013
15
Table 3 – Identified system limitations in Camperdown load area
Location
3.2.2
Identified
Limitation
Refer to
DAPR section
1.
Blackwattle Bay ZS
Asset condition
5.3.1
2.
Feeders 527 & 559 - Pyrmont STS to Blackwattle Bay ZS
Asset condition
5.2.1
3.
Feeder 490 & 491 - Pyrmont STS to Global Switch
Capacity
5.2.1
4.
Pyrmont STS
Capacity
5.3.1
Sub-transmission feeder load forecast
Camperdown-Blackwattle Bay Area - Feeder Load Forecast
Feeder name
Feeder 490
(Pyrmont STS to Global
Switch)
33 Rating
Feeder 491
(Pyrmont STS to Global
Switch)
33 Rating
Load
Load
Feeder 527
(Pyrmont STS to
Blackwattle Bay ZS T1)
33 Rating
Feeder 559 (Pyrmont
STS to Blackwattle Bay
ZS T2)
33 Rating
Feeder 560 (Pyrmont
STS to Blackwattle Bay
ZS T3)
33 Rating
Feeder 561 (Pyrmont
STS to Blackwattle Bay
ZS T4)
33 Rating
Feeder 580 (Pyrmont
STS to Camperdown ZS
T1)
Feeder 581 (Pyrmont
STS to Camperdown ZS
T2)
Feeder 582 (Pyrmont
STS to Camperdown ZS
T3)
3.2.3
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(KV)
2017
2018
32.2
32.2
32.2
32.2
23.4
28.0
32.6
32.6
32.6
32.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
27.4
32.2
32.2
32.2
32.2
32.2
23.4
28.0
32.6
32.6
32.6
32.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
7.8
7.5
7.3
7.2
7.2
7.2
7.3
7.1
6.9
6.9
7.0
7.1
17.0
17.0
17.0
17.0
17.0
17.0
18.4
18.4
18.4
18.4
18.4
18.4
7.3
7.1
6.8
6.8
6.8
6.8
6.1
5.9
5.7
5.8
5.8
5.9
18.6
18.6
18.6
18.6
18.6
18.6
20.2
20.2
20.2
20.2
20.2
20.2
Load
7.8
7.5
7.3
7.2
7.2
7.2
7.3
7.1
6.9
6.9
7.0
7.1
18.8
18.8
18.8
18.8
18.8
18.8
20.5
20.5
20.5
20.5
20.5
20.5
Load
6.2
6.0
5.8
5.8
5.8
5.7
6.3
6.1
5.9
6.0
6.0
6.1
15.3
15.3
15.3
15.3
15.3
15.3
17.0
17.0
17.0
17.0
17.0
17.0
9.8
9.5
9.1
8.9
8.7
8.5
0.3
9.1
8.8
8.8
8.9
9.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
10.2
9.8
9.4
9.2
9.1
8.8
0.3
9.4
9.1
9.1
9.1
9.3
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
10.2
9.8
9.4
9.2
9.1
8.8
0.3
9.4
9.1
9.1
9.1
9.3
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
32.0
Load
33 Rating
Load
33 Rating
Winter (MVA)
2015
2016
32.2
Load
Load
2014
27.4
Load
33 Rating
2013
STS and ZS load forecast
Camperdown and Blackwattle Bay Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Pyrmont 132/33kV STS
Blackwattle Bay 33/5kV ZS
Camperdown 33/11kV ZS
Camperdown 33/5kV ZS
Darling Harbour 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total
Capacity
(MVA)
299.1
61.3
78.0
75.6
141.2
299.1
65.1
78.0
77.5
141.2
131.7
41.7
52.0
56.2
70.3
134.6
44.8
52.0
59.3
70.3
131.7
41.7
52.0
56.2
78.7
134.6
44.8
52.0
59.3
84.4
13.8
11.2
11.2
11.2
11.2
22.2
5.0
5.0
5.0
19.1
0.06
0.16
0.16
7.31
Identified
Limitation
in next 5
years
Yes
No
No
No
No
SUMMER - Camperdown and Blackwattle Bay Area STS and ZS Load Forecast
Substation
Pyrmont 132/33kV STS
Blackwattle Bay 33/5kV ZS
Camperdown 33/11kV ZS
Camperdown 33/5kV ZS
Darling Harbour 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
89.6
104.5
102.2
98.1
76.1
113.2
128.5
135.7
144.7
154.1
163.1
0.98
1.00
1.00
0.96
1.00
0.97
0.96
0.96
0.95
0.94
0.94
28.6
27.5
26.7
25.1
22.0
22.3
21.6
20.9
20.8
20.8
20.7
0.98
1.00
0.88
0.88
0.88
0.88
0.88
0.88
0.88
0.88
0.88
19.7
19.0
18.3
17.9
17.5
17.0
0.86
0.86
0.86
0.86
0.86
0.86
39.8
40.1
39.6
30.4
23.5
0.99
0.99
0.87
0.89
0.86
62.4
62.2
58.5
57.1
57.1
64.9
66.4
66.2
67.8
70.0
71.9
0.91
0.91
0.93
0.94
0.95
0.94
0.94
0.94
0.94
0.94
0.94
Distribution and Transmission Annual Planning Report December 2013
16
WINTER - Camperdown and Blackwattle Bay Area STS and ZS Load Forecast
Substation
Pyrmont 132/33kV STS
Blackwattle Bay 33/5kV ZS
Camperdown 33/11kV ZS
Camperdown 33/5kV ZS
Darling Harbour 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
88.3
0.94
27.0
0.94
42.6
0.99
47.6
0.93
2009
86.9
0.87
24.4
0.87
37.9
1.00
45.8
0.93
Actual Load
2010
2011
90.3
86.2
1.00
0.96
23.8
25.8
0.92
0.92
38.6
33.8
0.94
0.95
46.6
40.4
0.95
0.95
Distribution and Transmission Annual Planning Report December 2013
2012
86.1
1.00
22.7
0.92
23.9
0.94
43.2
0.96
2013
93.3
0.99
21.4
0.92
22.9
0.94
46.2
0.96
2014
123.4
0.97
20.8
0.92
18.3
0.94
52.0
0.96
Forecast Load
2015
2016
134.2
138.3
0.96
0.96
20.3
20.4
0.92
0.92
17.7
17.7
0.94
0.94
51.8
53.3
0.96
0.96
2017
148.2
0.96
20.6
0.92
17.8
0.94
55.0
0.96
2018
158.5
0.95
20.9
0.92
18.1
0.94
57.2
0.96
17
3.3
3.3.1
Canterbury Bankstown Load Area
Description of Canterbury Bankstown area
The Canterbury Bankstown network area extends from Leightonfield in the north-west, Revesby in the south, and
east as far as Dulwich Hill. The area encompasses a broad spectrum of load types from low density residential
through to large commercial and industrial customers.
There area contains substantial industrial precincts at Chullora, Leightonfield, Milperra and Padstow. Bankstown
airport at Milperra is viewed as a key economic driver for the central western area of Sydney, providing
opportunities for reasonable expansion to serve a wider commercial purpose. Due to the highly built-up nature of
the area, residential buildings are often situated in close proximity to electrical substations. There is potential for
substantial development of the area, particularly in the vicinity of Bankstown airport
The network in the Canterbury Bankstown area:

is supplied from Ausgrid’s Inner Metropolitan transmission system, except for Revesby and Milperra zone
substations, which are supplied from TransGrid’s Sydney South Bulk Supply Point

includes 132/33kV sub-transmission substations at Bankstown and Canterbury which supply five 33/11kV zone
substations and provide 33kV supply to Railcorp and the M5 motorway

includes six 132/11kV substations at Greenacre Park, Bankstown, Potts Hill, Sefton, Revesby and Milperra

includes Leightonfield, a “stand-alone” 33kV zone substation, which is supplied from Endeavour Energy’s
network at Guildford sub-transmission substation

includes substantial lengths of 33kV gas-pressure cables, which are an obsolete technology, and

is traversed by transmission feeders 91A/2, 91B/2, 910, and 911.
Figure 6: Canterbury Bankstown Load Area
Distribution and Transmission Annual Planning Report December 2013
18
Table 4 – Identified system limitations in Canterbury Bankstown load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Bass Hill ZS
Asset condition
5.3.2
2.
Dulwich Hill ZS
Asset condition
5.3.2
3.
Greenacre Park ZS
Asset condition
5.3.2
4.
Leightonfield ZS
Asset condition
5.3.2
5.
Potts Hill ZS
Capacity
5.3.2
6.
Feeders 643, 644 & 645 - Canterbury STS to Dulwich Hill
ZS
Asset condition
5.2.2
7.
Feeders 639, 640 & 641 - Canterbury STS to Enfield ZS
Asset condition
5.2.2
8.
Feeder 291/1 - Greenacre Park to Potts Hill ZS
Asset condition
5.2.2
Distribution and Transmission Annual Planning Report December 2013
19
3.3.2
Sub-transmission feeder load forecast
Canterbury-Bankstown Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder 282/1
(Sydney South BSP to
Revesby ZS)
132 Rating
Feeder 282/2
(Revesby ZS to Milperra
ZS)
132 Rating
Feeder 283/1
(Sydney South BSP to
Revesby ZS)
132 Rating
Feeder 283/2
(Revesby ZS to Milperra
ZS)
132 Rating
Load
Load
Load
Load
Feeder 631
(Canterbury STS to
Campsie ZS T4)
33 Rating
Feeder 632
(Canterbury STS to M5
Tunnel)
33 Rating
Feeder 633
(Canterbury STS to M5
Tunnel)
33 Rating
Feeder 634
(Canterbury STS to
Campsie ZS T4)
33 Rating
Feeder 636
(Canterbury STS to
Dulwich Hill ZS T1)
33 Rating
Load
Load
Load
Load
Load
Feeder 639
(Canterbury STS to
Enfield ZS T1)
33 Rating
Feeder 640
(Canterbury STS to
Enfield ZS T2)
33 Rating
Load
Load
Feeder 641
(Canterbury STS to
Enfield ZS T3)
33 Rating
Feeder 643
(Canterbury STS to
Dulwich Hill ZS T4)
33 Rating
Load
Load
Feeder 644
(Canterbury STS to
Dulwich Hill ZS T2)
33 Rating
Feeder 645
(Canterbury STS to
Dulwich Hill ZS T3)
33 Rating
Load
Load
Feeder 648
(Canterbury STS to
Campsie ZS T1)
33 Rating
Feeder 649
(Canterbury STS to
Campsie ZS T2)
33 Rating
Load
Load
Feeder 650
(Canterbury STS to
Campsie ZS T3)
33 Rating
Feeder 655
(Bankstown STS to
Bass Hill ZS)
33 Rating
Load
Load
Feeder 661
(Bankstown STS to
Bass Hill ZS)
33 Rating
Feeder 665
(Bankstown STS to
Punchbowl ZS T1)
33 Rating
Feeder 666
(Bankstown STS to
Punchbowl ZS T2)
33 Rating
Feeder 667
(Bankstown STS to
Punchbowl ZS T3)
33 Rating
Feeder 668
(Bankstown STS to
Punchbowl ZS T4)
33 Rating
Feeder 669
(Bankstown STS to
Punchbowl ZS T5)
33 Rating
Load
Load
Load
Load
Load
Load
2013
2014
Winter (MVA)
2015
2016
2017
2018
70.2
71.7
68.7
69.3
69.9
68.8
60.4
58.6
57.2
57.3
57.6
58.3
184.7
184.7
184.7
184.7
184.7
184.7
196.4
196.4
196.4
196.4
196.4
196.4
25.5
53.6
50.8
50.9
51.0
49.4
41.5
40.4
39.6
39.6
39.8
40.2
143.1
143.1
143.1
143.1
143.1
143.1
152.0
152.0
152.0
152.0
152.0
152.0
68.9
33.8
68.9
69.7
70.2
69.0
60.5
58.8
57.3
57.4
57.7
58.4
193.0
193.0
193.0
193.0
193.0
193.0
202.1
202.1
202.1
202.1
202.1
202.1
25.5
25.1
50.8
51.2
51.6
49.4
41.5
40.3
39.5
39.5
39.8
40.2
155.5
155.5
155.5
155.5
155.5
155.5
164.6
164.6
164.6
164.6
164.6
164.6
6.2
6.3
6.4
6.7
7.0
7.3
6.5
6.6
6.5
6.6
6.7
6.9
16.5
16.5
16.5
16.5
16.5
16.5
18.5
18.5
18.5
18.5
18.5
18.5
7.3
7.3
7.3
7.3
7.3
7.3
9.7
9.7
9.7
9.7
9.7
9.7
31.1
31.1
31.1
31.1
31.1
31.1
33.4
33.4
33.4
33.4
33.4
33.4
7.3
7.3
7.3
7.3
7.3
7.3
9.7
9.7
9.7
9.7
9.7
9.7
31.1
31.1
31.1
31.1
31.1
31.1
33.4
33.4
33.4
33.4
33.4
33.4
6.2
6.3
6.4
6.7
7.0
7.3
6.5
6.6
6.5
6.6
6.7
6.9
16.5
16.5
16.5
16.5
16.5
16.5
18.5
18.5
18.5
18.5
18.5
18.5
13.7
13.6
13.5
13.8
14.1
14.5
16.1
15.6
15.1
15.1
15.2
15.4
18.5
18.5
18.5
18.5
18.5
18.5
20.0
20.0
20.0
20.0
20.0
20.0
9.5
10.5
10.4
10.6
10.8
11.0
8.5
8.2
8.9
9.0
9.1
9.3
16.4
16.4
16.4
16.4
16.4
16.4
17.3
17.3
17.3
17.3
17.3
17.3
12.8
12.4
12.3
12.5
12.7
14.0
12.2
11.7
12.8
12.9
13.0
13.3
16.4
16.4
16.4
16.4
16.4
16.4
17.3
17.3
17.3
17.3
17.3
17.3
12.3
13.5
13.4
13.6
13.9
14.2
12.4
11.9
13.0
13.1
13.2
13.5
16.4
16.4
16.4
16.4
16.4
16.4
17.3
17.3
17.3
17.3
17.3
17.3
12.9
12.8
12.7
12.9
13.3
13.6
13.3
12.9
12.5
12.5
12.6
12.8
18.9
18.9
18.9
18.9
18.9
18.9
20.4
20.4
20.4
20.4
20.4
20.4
13.3
14.0
14.0
13.4
13.8
14.3
15.9
15.4
15.4
14.9
15.5
15.2
18.9
18.9
18.9
18.9
18.9
18.9
20.4
20.4
20.4
20.4
20.4
20.4
13.7
13.6
13.5
13.8
14.1
14.5
15.1
14.7
14.2
14.3
14.3
14.5
18.9
18.9
18.9
18.9
18.9
18.9
20.4
20.4
20.4
20.4
20.4
20.4
27.4
28.0
28.1
29.6
31.1
32.4
28.8
29.5
28.9
29.5
29.8
31.0
34.3
34.3
34.3
34.3
34.3
34.3
36.5
36.5
36.5
36.5
36.5
36.5
23.8
24.1
24.5
25.5
26.8
28.1
25.0
25.4
24.9
25.3
25.9
26.6
34.3
34.3
34.3
34.3
34.3
34.3
36.5
36.5
36.5
36.5
36.5
36.5
28.1
28.6
29.0
30.2
31.8
33.3
29.7
30.1
29.5
30.1
30.8
31.7
34.3
34.3
34.3
34.3
34.3
34.3
37.2
37.2
37.2
37.2
37.2
37.2
14.7
14.6
14.5
15.0
15.4
15.9
11.6
11.2
10.9
10.9
11.0
11.1
41.2
41.2
41.2
41.2
41.2
41.2
41.2
41.2
41.2
41.2
41.2
41.2
14.8
14.9
14.5
15.0
15.3
15.9
11.6
11.3
10.9
10.9
11.0
11.2
36.1
36.1
36.1
36.1
36.1
36.1
43.4
43.4
43.4
43.4
43.4
43.4
13.8
13.7
13.9
13.7
13.0
13.2
9.5
9.5
9.2
9.2
9.3
9.4
21.3
21.3
21.3
21.3
21.3
21.3
22.5
22.5
22.5
22.5
22.5
22.5
13.2
13.1
12.9
13.2
13.5
13.8
6.7
6.7
6.5
6.5
6.6
6.6
21.3
21.3
21.3
21.3
21.3
21.3
22.5
22.5
22.5
22.5
22.5
22.5
13.1
13.0
12.9
13.2
13.5
13.8
7.3
7.3
7.1
7.1
7.2
7.3
21.3
21.3
21.3
21.3
21.3
21.3
22.5
22.5
22.5
22.5
22.5
22.5
13.6
13.5
13.4
13.6
14.0
14.3
9.3
9.3
9.0
9.1
9.1
9.2
21.3
21.3
21.3
21.3
21.3
21.3
22.5
22.5
22.5
22.5
22.5
22.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
21.3
21.3
21.3
21.3
21.3
21.3
22.5
22.5
22.5
22.5
22.5
22.5
Distribution and Transmission Annual Planning Report December 2013
20
3.3.3
STS and ZS load forecast
Canterbury Bankstown Area - STS and ZS details
155.8
194.5
65.0
29.2
87.0
61.9
44.8
92.0
30.5
64.6
54.9
77.5
47.8
99.7
137.4
176.8
72.6
35.0
97.4
61.9
44.8
96.4
34.1
68.0
61.4
75.7
53.9
113.5
155.8
194.5
69.0
35.0
87.0
61.9
44.8
110.3
36.6
77.5
65.8
77.5
47.9
119.6
Other
Winter
137.4
176.8
65.0
29.2
87.0
61.9
44.8
86.2
30.5
61.2
54.9
75.7
44.9
94.6
Solar PV
Summer
223.4
274.4
100.0
45.2
140.6
84.8
67.7
152.6
51.9
123.2
107.0
108.6
76.2
152.5
Embedded
Generation
(MVA)
0.74
0.95
2.21
1.49
0.85
0.38
0.58
1.31
2.44
2.07
3.54
6.00
2.40
-
Winter
Winter
206.1
274.4
90.0
45.2
140.6
84.8
67.7
152.4
51.9
123.2
107.0
108.0
76.2
152.4
95% Peak Load
Exceeded
(hrs/yr)
Summer
Summer
Licence
Capacity (MVA)
Winter
Substation
Bankstown 132/33kV STS
Canterbury 132/33kV STS
Bankstown 132/11kV ZS
Bass Hill 33/11kV ZS
Campsie 33/11kV ZS
Dulwich Hill 33/11kV ZS
Enfield 33/11kV ZS
Greenacre Park 132/11kV ZS
Leightonfield 33/11kV ZS
Milperra 132/11kV ZS
Potts Hill 132/11kV ZS
Punchbowl 33/11kV ZS
Revesby 132/11kV ZS
Sefton 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
2.9
2.9
11.2
2.9
11.2
11.2
2.9
11.2
11.2
13.8
11.2
2.9
2.9
2.9
5.0
5.0
5.0
5.0
5.0
3.5
3.5
19.1
19.1
22.2
19.1
5.0
3.5
5.0
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
No
No
No
SUMMER - Canterbury Bankstown Area STS and ZS Load Forecast
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Substation
Bankstown 132/33kV STS
Canterbury 132/33kV STS
Bankstown 132/11kV ZS
Bass Hill 33/11kV ZS
Campsie 33/11kV ZS
Dulwich Hill 33/11kV ZS
Enfield 33/11kV ZS
Greenacre Park 132/11kV ZS
Leightonfield 33/11kV ZS
Milperra 132/11kV ZS
Padstow 33/11kV ZS
Potts Hill 132/11kV ZS
Punchbowl 33/11kV ZS
Revesby 132/11kV ZS
Sefton 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
112.5
1.00
142.6
1.00
27.0
1.00
53.5
1.00
40.0
1.00
33.9
1.00
94.3
0.95
24.3
0.95
46.9
0.87
37.6
1.00
55.0
1.00
43.1
0.90
62.5
0.85
121.8
1.00
147.6
0.99
26.8
1.00
60.4
0.99
43.2
0.99
37.3
0.99
85.3
0.95
24.0
0.95
51.7
0.87
36.4
1.00
56.6
1.00
43.8
0.90
70.2
0.85
94.5
0.96
146.0
1.00
26.3
0.77
29.8
0.90
61.1
0.92
45.8
0.94
41.5
0.91
91.1
0.93
25.7
0.94
55.9
0.89
59.8
0.89
48.7
0.92
74.8
0.90
75.0
0.98
126.7
1.00
24.3
0.77
21.5
0.90
56.2
0.92
36.5
0.94
20.2
0.92
71.4
0.96
20.2
0.94
50.1
0.88
47.7
0.89
36.8
0.94
60.1
0.90
Distribution and Transmission Annual Planning Report December 2013
84.5
0.99
128.2
1.00
22.8
0.77
25.5
0.88
63.6
0.90
38.2
0.95
21.6
0.89
78.9
0.97
22.0
0.94
47.4
0.89
55.3
0.90
43.4
0.94
69.4
0.91
72.4
1.00
127.4
1.00
40.4
0.83
28.1
0.88
62.4
0.90
41.0
0.95
22.0
0.89
59.0
1.00
23.7
0.94
51.1
0.89
50.1
0.92
38.8
0.90
43.6
0.94
45.9
0.91
72.0
1.00
129.9
1.00
40.6
0.83
27.9
0.88
63.3
0.90
40.7
0.95
24.1
0.89
57.1
1.00
22.9
0.94
50.3
0.89
49.1
0.92
38.6
0.90
43.3
0.94
45.4
0.91
71.5
1.00
130.1
1.00
40.5
0.83
27.7
0.88
64.1
0.90
40.5
0.95
23.9
0.89
55.6
1.00
22.7
0.94
48.5
0.89
48.1
0.92
38.2
0.90
43.0
0.94
44.8
0.91
72.7
1.00
133.3
1.00
41.4
0.83
28.3
0.88
66.6
0.90
41.2
0.95
24.3
0.89
55.6
1.00
22.5
0.94
47.9
0.89
48.4
0.92
38.9
0.90
43.9
0.94
45.4
0.91
74.6
1.00
137.6
1.00
42.7
0.83
29.0
0.88
69.7
0.90
42.3
0.95
24.8
0.89
56.1
1.00
22.4
0.94
47.7
0.89
49.1
0.92
39.9
0.90
45.1
0.94
46.3
0.91
76.1
1.00
141.5
1.00
43.9
0.83
29.7
0.88
72.8
0.90
43.3
0.95
25.3
0.89
56.3
1.00
22.3
0.94
47.3
0.89
49.5
0.92
40.7
0.90
46.1
0.94
47.0
0.91
21
WINTER - Canterbury Bankstown Area STS and ZS Load Forecast
Substation
Bankstown 132/33kV STS
Canterbury 132/33kV STS
Bankstown 132/11kV ZS
Bass Hill 33/11kV ZS
Campsie 33/11kV ZS
Dulwich Hill 33/11kV ZS
Enfield 33/11kV ZS
Greenacre Park 132/11kV ZS
Leightonfield 33/11kV ZS
Milperra 132/11kV ZS
Padstow 33/11kV ZS
Potts Hill 132/11kV ZS
Punchbowl 33/11kV ZS
Revesby 132/11kV ZS
Sefton 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
124.6
1.00
175.5
1.00
26.9
1.00
62.1
1.00
53.7
1.00
38.4
1.00
75.7
0.97
21.8
0.95
44.6
0.88
32.7
1.00
60.9
1.00
46.2
0.95
60.2
0.95
Actual Load
2009
2010
2011
112.5
105.0
85.2
0.98
0.99
1.00
160.4
165.6
150.0
1.00
1.00
0.98
23.1
0.78
23.1
24.9
24.3
0.98
0.94
0.94
55.4
57.4
64.4
1.00
0.86
0.83
46.5
48.6
45.6
1.00
0.97
0.98
37.1
40.1
21.7
1.00
0.94
0.94
66.7
67.9
59.2
0.96
0.97
0.97
19.8
21.4
19.2
0.95
0.96
0.84
40.0
48.1
46.2
0.92
0.93
0.90
31.1
23.1
0.98
0.93
53.6
54.8
53.1
0.98
0.96
0.96
41.6
42.4
40.8
0.95
0.95
0.96
60.6
58.5
61.8
0.95
0.95
0.95
Distribution and Transmission Annual Planning Report December 2013
2012
76.9
1.00
127.6
0.99
22.2
0.79
22.5
0.90
59.5
0.85
42.6
0.97
20.3
0.95
57.6
0.99
19.4
0.97
46.6
0.91
48.0
0.96
38.5
0.90
59.2
0.95
2013
64.6
1.00
134.0
0.99
39.4
0.88
21.9
0.90
62.6
0.85
43.6
0.97
20.5
0.95
56.3
1.00
20.4
0.97
44.8
0.91
32.2
0.96
39.4
0.90
59.6
0.95
2014
63.8
1.00
127.8
0.99
39.1
0.88
21.3
0.90
63.3
0.85
42.3
0.97
19.8
0.95
43.3
1.00
19.8
0.97
44.4
0.91
42.1
0.96
32.4
0.96
38.3
0.90
33.0
0.95
Forecast Load
2015
2016
62.1
62.2
1.00
1.00
127.2
128.4
0.99
0.99
38.6
39.4
0.88
0.88
20.6
20.7
0.90
0.90
62.2
63.3
0.85
0.85
41.0
41.1
0.97
0.97
21.5
21.7
0.95
0.95
42.1
42.4
1.00
1.00
19.2
19.2
0.97
0.97
42.9
42.9
0.91
0.91
40.9
41.1
0.96
0.96
31.4
31.5
0.96
0.96
37.1
37.2
0.90
0.90
32.0
32.1
0.95
0.95
2017
62.6
1.00
130.0
0.99
40.4
0.88
20.8
0.90
64.6
0.85
41.3
0.97
21.9
0.95
42.8
1.00
19.3
0.97
43.1
0.91
41.5
0.96
31.7
0.96
37.5
0.90
32.3
0.95
2018
63.3
1.00
132.4
0.99
41.6
0.88
21.1
0.90
66.3
0.85
41.8
0.97
22.3
0.95
43.5
1.00
19.5
0.97
43.5
0.91
42.1
0.96
32.1
0.96
37.9
0.90
32.7
0.95
22
3.4
3.4.1
Carlingford Load Area
Description of Carlingford area
The Carlingford network area extends east from Endeavour Energy's Carlingford Sub-transmission substation to
Epping and Macquarie Park, and as far south as Hunters Hill and Meadowbank. The area is bounded by the supply
boundary with Endeavour Energy to the north-west, by the Lane Cove River Valley to the north, and the Parramatta
River and Sydney Harbour to the south and east.
The Macquarie Park area, running along the northern boundary of the Carlingford network area contains significant
commercial load arising from:

Macquarie shopping centre

Macquarie University

Macquarie Park commercial area

Carlingford Court shopping centre

Epping/Hunters Hill commercial centres, and

Top Ryde shopping centre.
Commercial developments are expected to continue in this area as a result of the recently opened Chatswood to
Epping rail line and the proposed North West rail line. Between the commercial areas there is significant residential
load with high density development in the Epping, Macquarie, Meadowbank and Ryde areas.
The distribution network in the Carlingford load area is supplied by two electrically separate sub-transmission
systems - a 66kV network supplied from Endeavour Energy’s Carlingford sub-transmission substation, and
Ausgrid’s 132kV network interconnected to TransGrid’s Sydney North Bulk Supply Point, Lane Cove Switching
Station and Mason Park Switching Station.
Figure 7: Carlingford Load Area
Distribution and Transmission Annual Planning Report December 2013
23
Table 5 – Identified system limitations in Carlingford load area
Location
3.4.2
Identified
Limitation
Refer to
DAPR section
Asset condition
5.3.3
1.
Hunters Hill ZS
2.
Macquarie Park ZS
Capacity
5.3.3
3.
Top Ryde ZS
Capacity
5.3.3
Sub-transmission feeder load forecast
Carlingford Area - Feeder Load Forecast
Feeder name
Feeder 809
(Carlingford BSP to
Ryde STSS)
Feeder 810
(Carlingford BSP to
Ryde STSS)
Feeder 812 (1)
(Ryde STSS to to 812
TEE)
Load
66 Rating
Load
66 Rating
Load
66 Rating
Feeder 812 (2)
(Hunters Hill ZS to to
812 TEE)
66 Rating
Feeder 813
(Carlingford BSP to
Epping ZS)
66 Rating
Feeder 819
(Carlingford BSP to
Hunters Hill ZS)
66 Rating
Feeder 820
(Carlingford BSP to
Epping ZS)
Feeder 82C
(Carlingford BSP to
Hunters Hill ZS)
3.4.3
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
Load
66 Rating
Load
66 Rating
2014
Winter (MVA)
2015
2016
2017
2018
-
-
-
-
-
-
21.6
-
-
-
-
-
-
-
-
-
-
-
82.3
-
-
-
-
-
-
-
-
-
-
-
24.5
-
-
-
-
-
-
-
-
-
-
-
82.3
-
-
-
-
-
-
-
-
-
-
-
45.7
-
-
-
-
-
-
-
-
-
-
-
153.2
-
-
-
-
-
-
-
-
-
-
-
45.1
-
-
-
-
-
-
-
-
-
-
-
114.5
-
-
-
-
-
65.2
66.1
65.7
67.4
69.5
71.3
48.8
51.2
50.1
50.5
51.0
50.9
79.0
79.0
79.0
79.0
79.0
79.0
83.4
83.4
83.4
83.4
83.4
83.4
55.2
54.9
54.7
55.9
57.5
59.0
45.3
43.9
42.6
43.1
43.5
44.0
88.9
88.9
88.9
88.9
88.9
88.9
82.9
91.4
91.4
91.4
91.4
91.4
65.1
66.0
65.6
67.4
69.5
71.4
48.8
51.2
50.1
50.5
50.9
50.9
Load
Load
2013
90.2
90.2
90.2
90.2
90.2
90.2
91.4
91.4
91.4
91.4
91.4
91.4
55.2
54.9
54.5
56.2
57.5
59.0
-
43.9
42.6
43.0
43.4
43.9
82.3
82.3
82.3
82.3
82.3
82.3
-
82.3
82.3
82.3
82.3
82.3
STS and ZS load forecast
Carlingford Area - STS and ZS details
Winter
Summer
Winter
Summer
Winter
Solar PV
113.5
113.5
171.5
152.8
113.3
113.5
113.6
171.5
157.7
113.3
74.9
69.8
114.3
103.8
61.3
74.9
72.3
114.3
108.7
61.3
83.3
69.8
127.1
124.6
73.5
89.9
72.3
137.2
130.4
73.5
13.8
2.9
13.8
2.9
2.9
5.0
5.0
19.1
5.0
5.0
1.68
1.20
0.19
2.20
1.28
Other
Summer
Epping 66/11kV ZS
Hunters Hill 66/11kV ZS
Macquarie Park 132/11kV ZS
Meadowbank 132/11kV ZS
Top Ryde 132/11kV ZS
Embedded
Licence Capacity 95% Peak Load
Exceeded (hrs/yr) Generation (MVA)
(MVA)
Winter
Substation
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
1.53
-
Identified
Limitation
in next 5
years
No
No
No
No
Yes
SUMMER - Carlingford Area STS and ZS Load Forecast
Substation
MVA
PF
MVA
Hunters Hill 66/11kV ZS
PF
MVA
Macquarie Park 132/11kV ZS PF
MVA
Meadowbank 132/11kV ZS
PF
MVA
North Ryde 66/11kV ZS
PF
MVA
Top Ryde 132/11kV ZS
PF
Epping 66/11kV ZS
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
64.6
66.9
66.8
54.1
61.1
65.9
66.7
66.3
67.9
69.8
71.5
0.95
0.95
0.96
0.96
0.96
0.99
0.99
0.99
0.99
0.99
0.99
60.1
60.9
66.8
48.4
48.4
53.3
53.1
52.7
53.9
55.3
56.6
0.95
0.95
0.88
0.88
0.87
0.87
0.87
0.87
0.87
0.87
0.87
68.1
67.9
80.8
65.7
68.3
105.1
113.2
117.3
121.3
126.5
131.4
0.95
0.95
0.96
0.95
0.96
0.96
0.96
0.96
0.96
0.96
0.96
75.2
76.9
80.7
57.8
66.3
74.6
78.4
79.0
81.7
85.2
88.5
0.89
0.89
0.93
0.94
0.95
0.95
0.95
0.95
0.95
0.95
0.95
32.4
32.4
31.9
0.95
0.95
0.97
40.1
55.3
56.2
58.7
60.3
62.1
64.4
66.5
0.90
0.96
0.96
0.96
0.96
0.96
0.96
0.96
Distribution and Transmission Annual Planning Report December 2013
24
WINTER - Carlingford Area STS and ZS Load Forecast
Substation
MVA
PF
Epping 66/11kV ZS
MVA
PF
Hunters Hill 66/11kV ZS
MVA
Macquarie Park 132/11kV ZS PF
MVA
PF
Meadowbank 132/11kV ZS
MVA
North Ryde 66/11kV ZS
PF
MVA
Top Ryde 132/11kV ZS
PF
2008
58.7
0.95
66.0
0.95
42.8
0.96
74.0
0.94
35.1
0.95
-
2009
54.4
0.95
56.3
0.95
51.3
0.97
64.8
0.94
28.4
0.95
-
Actual Load
2010
2011
56.9
52.0
0.98
0.98
59.0
58.1
0.96
0.97
55.3
56.1
0.97
0.95
64.5
63.0
0.94
0.94
29.3
27.7
0.98
0.98
-
Distribution and Transmission Annual Planning Report December 2013
2012
48.5
0.99
46.6
0.97
55.3
0.95
58.0
0.94
43.3
0.98
2013
49.3
1.00
46.0
0.97
77.3
0.95
56.9
0.94
43.2
0.98
2014
52.0
1.00
44.8
0.97
82.7
0.95
56.2
0.94
44.7
0.98
Forecast Load
2015
2016
50.5
50.9
1.00
1.00
43.5
43.9
0.97
0.97
87.4
87.9
0.95
0.95
57.4
57.6
0.94
0.94
45.7
46.0
0.98
0.98
2017
51.3
1.00
44.3
0.97
88.6
0.95
58.0
0.94
46.4
0.98
2018
51.8
1.00
44.8
0.97
89.9
0.95
58.8
0.94
47.2
0.98
25
3.5
3.5.1
Eastern Suburbs Load Area
Description of Eastern Suburbs load area
The Eastern Suburbs load area includes Sydney’s eastern seaboard from South Head to La Perouse, and extends
inland to Surry Hills in the north-west, and west as far as Marrickville. It includes a wide variety of load types,
comprising heavy industrial around Botany in the south, light industrial and commercial in the west and north, and
predominantly domestic with pockets of commercial everywhere else.
Significant industrial development has been proposed for the port facilities at Botany, the airport, and the Alexandria
area. Residential and light industrial areas in the west of the area have been undergoing urban renewal in recent
times. The coastal suburbs in the east of the area are relatively established and are not expected to change
drastically in the foreseeable future.
The network in the Eastern Suburbs area:

is supplied from the Inner Metropolitan transmission network, including Bunnerong sub-transmission substation
and TransGrid’s Beaconsfield West and Haymarket Bulk Supply Points (BSPs)

includes 132/11kV and 33/11kV zones substations, as well as 132kV and 33kV gas, oil and HSL feeders;

supplies high voltage customers including Railcorp (Surry Hills), Sydney Airport, AMCOR (called “Aust Paper”
on the above map), and a chemical plant directly at 33kV

will supply Equinix data centre in Bourke Road, Alexandria, via an ex-Alexandria zone 33kV cable from
Bunnerong North STS

includes assets which are in poor condition, particularly 33kV cables and many substation 11kV busbars, and

much of the existing 33kV standby feeder network involves extremely long feeders, complex connections and
is operationally difficult.
In addition to existing loads in the area, Sydney Airport Corporation Limited (SACL) has indicated plans to increase
their demand in the medium-term future. Several other large load applications in the Alexandria area have been
submitted to Ausgrid, and, though they have not progressed to date, information from town planning cites
Alexandria as an area for major future development.
Many assets are approaching the end of their service life, particularly 33kV cables and substation 11kV busbars.
Much of the existing 33kV standby feeder network involves extremely long feeders, complex connections and is
operationally difficult.
Figure 8: Eastern Suburbs Load Area
Distribution and Transmission Annual Planning Report December 2013
26
Table 6 – Identified system limitations in the Eastern Suburbs load area
Location
3.5.2
Identified
Limitation
Refer to
DAPR section
1.
Botany ZS
Asset condition
5.3.4
2.
Darlinghurst ZS
Asset condition
5.3.4
3.
Matraville ZS
Asset condition
5.3.4
4.
Surry Hills ZS
Asset condition
5.3.4
5.
Sydney Airport ZS
Asset condition
5.3.4
6.
Clovelly ZS
Asset condition
5.3.4
7.
Feeder 396(1) - Surry Hills STS to Paddington ZS
Capacity
5.2.3
8.
Feeder 396(2) - Surry Hills STS to Waverley ZS
Capacity
5.2.3
9.
Feeder 387 - Surry Hills STS to Darlinghurst ZS
Asset condition
5.2.3
10.
Feeders 386, 388 & 389 - Surry Hills STS to Darlinghurst
ZS
Asset condition
5.2.3
11.
Feeders 377 & 378 - Surry Hills STS to Graving Dock ZS
Asset condition
5.2.3
12.
Feeders 313, 318, 324 & 340 - Bunnerong North STS to
Matraville ZS
Asset condition
5.2.3
13.
Feeders 380, 381 & 382 - Surry Hills STS to Paddington ZS
Asset condition
5.2.3
14.
Feeder 376 - Surry Hills STS to Surry Hills ZS
Asset condition
5.2.3
15.
Feeders 383, 384 & 385 - Surry Hills STS to Surry Hills ZS
Asset condition
5.2.3
16.
Feeders 331, 352 & 356 - Bunnerong STS to Sydney
Airport ZS
Asset condition
5.2.3
17.
Feeders 260/2 and 261/2 - Zetland to Clovelly ZS
Asset condition
5.2.3
18.
Feeders 328, 331, 337 & 341 - Bunnerong STS to Mascot
ZS
Asset condition
5.2.3
Sub-transmission feeder load forecast
Peak demand in the Eastern Suburbs area occurs in summer and is driven by demand from residential and
commercial customers. It is predominantly driven by temperature, and the associated peak in air-conditioning
and appliance usage during the hottest part of the day. Winter demand is relatively close to summer demand in
the Eastern Suburbs due to the prevalence of central heating systems in residences, and also because
proximity to the harbour and the ocean results in relatively moderate summer temperatures.
Peak demand in the Eastern Suburbs area has flattened out over the last five years, possibly attributable to a
combination of factors such as mild summers, economic down-turn coupled with increased electricity prices,
and increasing penetration of energy-efficient appliances.
Distribution and Transmission Annual Planning Report December 2013
27
Eastern Suburbs Area - Feeder Load Forecast
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder name
(kV)
Feeder 260/1
Load
59.5
57.4
55.3
55.1
55.4
55.3
(Beaconsfield West BSP
105.0
105.0
105.0
105.0
105.0
to Zetland ZS)
132 Rating 105.0
Feeder 260/2 (Zetland
ZS to Clovelly ZS)
Feeder 261/1
(Beaconsfield West BSP
to Zetland ZS)
Feeder 261/2
(Zetland ZS to Clovelly
ZS)
Feeder 262
(Double Bay ZS to
Clovelly ZS)
Feeder 264
(Beaconsfield West BSP
to Kingsford ZS)
Feeder 265
(Bunnerong STSS to
Maroubra ZS)
Feeder 270
(Kingsford ZS to
Maroubra ZS)
Feeder 313
(Bunnerong North STS
to Matraville ZS T3)
Feeder 315(1)
(Bunnerong North STS
to Matraville ZS T1)
Feeder 317(1)
(Bunnerong North STS
to 475 TEE)
Feeder 318
(Bunnerong North STS
to Matraville ZS T4)
Feeder 324
(Bunnerong North STS
to Matraville ZS T2)
Feeder 327
(Bunnerong North STS
to Mascot ZS T4)
Feeder 328
(Bunnerong North STS
to Mascot ZS T3)
Feeder 331 (1)
(Bunnerong North STS
to Sydney Airport)
Feeder 331 (2)
(Bunnerong North STS
to Sydney Airport)
Feeder 332
(Bunnerong North STS
to Mascot ZS T2)
Feeder 337
(Bunnerong North STS
to Mascot ZS T5)
Feeder 338
(Sydney Airport to
International Terminal)
Feeder 339
(Bunnerong North STS
to Port Botany ZS ZS
Feeder 340
(Bunnerong North STS
to Matraville ZS T5)
Feeder 341
(Bunnerong North STS
to Mascot ZS T1)
Feeder 345
(Bunnerong North STS
to Sydney Airport)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
22.6
22.0
22.0
22.0
22.0
22.1
40.0
40.0
40.0
40.0
40.0
40.0
2018
28.1
27.7
27.3
27.7
28.3
28.8
31.9
30.3
29.4
29.5
29.6
30.0
135.0
135.0
135.0
135.0
135.0
135.0
130.0
130.0
130.0
130.0
130.0
130.0
73.2
71.4
69.5
69.8
70.7
71.2
78.1
71.0
68.6
68.9
69.4
70.3
75.0
75.0
75.0
75.0
75.0
75.0
80.0
80.0
80.0
80.0
80.0
80.0
34.7
34.2
33.7
34.2
35.0
35.6
44.5
42.2
40.8
41.0
41.2
41.8
75.0
75.0
75.0
75.0
75.0
75.0
55.0
55.0
55.0
55.0
55.0
55.0
66.1
65.2
63.4
65.0
66.5
68.0
80.6
76.3
73.6
73.8
74.4
75.4
179.5
179.5
179.5
179.5
179.5
179.5
182.9
182.9
182.9
182.9
182.9
182.9
83.0
83.0
82.8
85.1
88.3
91.2
95.0
96.6
96.3
99.6
103.6
108.3
251.0
251.0
251.0
251.0
251.0
251.0
265.7
265.7
265.7
265.7
265.7
265.7
83.1
82.9
82.9
85.2
88.4
91.2
94.4
96.6
96.6
100.0
103.9
108.7
140.6
140.6
140.6
140.6
140.6
140.6
149.8
149.8
149.8
149.8
149.8
149.8
48.0
47.7
47.4
48.4
49.8
51.1
51.7
52.7
52.7
54.5
56.6
59.2
250.4
250.4
250.4
250.4
250.4
250.4
265.2
265.2
265.2
265.2
265.2
265.2
4.8
4.9
4.9
5.0
5.2
5.3
6.7
4.2
4.2
4.3
4.4
4.5
17.4
17.4
17.4
17.4
17.4
17.4
18.0
18.0
18.0
18.0
18.0
18.0
9.7
10.0
9.9
10.2
10.5
10.8
14.8
9.1
9.2
9.4
9.6
9.9
18.2
18.2
18.2
18.2
18.2
18.2
20.2
20.2
20.2
20.2
20.2
20.2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
16.1
16.1
16.1
16.1
16.1
16.1
17.1
17.1
17.1
17.1
17.1
17.1
7.9
8.1
8.1
8.3
8.5
8.8
12.3
7.6
7.7
7.8
8.0
8.2
18.0
18.0
18.0
18.0
18.0
18.0
19.0
19.0
19.0
19.0
19.0
19.0
6.1
6.2
6.2
6.4
6.6
6.7
11.0
6.8
6.9
7.0
7.2
7.4
19.7
19.7
19.7
19.7
19.7
19.7
21.2
21.2
21.2
21.2
21.2
21.2
9.3
9.0
8.7
8.6
8.6
8.5
7.1
6.8
6.6
6.6
6.7
6.7
17.6
17.6
17.6
17.6
17.6
17.7
19.2
19.2
19.2
19.2
19.2
19.2
9.3
9.0
8.6
8.6
8.6
8.5
7.1
6.8
6.6
6.6
6.6
6.7
17.5
17.5
17.5
17.5
17.5
17.5
19.0
19.0
19.0
19.0
19.0
19.0
6.2
6.2
6.2
6.2
6.2
6.2
5.4
5.4
5.4
5.4
5.4
5.4
15.0
15.0
15.0
15.0
15.0
15.0
16.9
16.9
16.9
16.9
16.9
16.9
6.2
6.2
6.2
6.2
6.2
6.2
5.4
5.4
5.4
5.4
5.4
5.4
15.0
15.0
15.0
15.0
15.0
15.0
16.9
16.9
16.9
16.9
16.9
16.9
9.3
9.0
8.6
8.6
8.6
8.5
7.1
6.8
6.6
6.6
6.6
6.7
16.2
16.2
16.2
16.2
16.2
16.2
17.5
17.5
17.5
17.5
17.5
17.5
8.4
8.1
7.8
7.7
7.7
7.7
6.4
6.2
5.9
6.0
6.0
6.0
16.6
16.6
16.6
16.6
16.6
16.6
18.4
18.4
18.4
18.4
18.4
18.4
5.3
5.3
5.3
5.3
5.3
5.3
2.8
2.8
2.8
2.8
2.8
2.8
29.7
29.7
29.7
29.7
29.7
29.7
31.5
31.5
31.5
31.5
31.5
31.5
9.9
12.1
13.2
13.2
13.2
13.2
0.7
7.5
10.2
10.2
10.2
10.2
27.1
27.1
27.1
27.1
27.1
27.1
28.6
28.6
28.6
28.6
28.6
28.6
4.5
4.7
4.7
4.8
4.9
5.0
9.7
6.0
6.1
6.2
6.3
6.5
15.1
15.1
15.1
15.1
15.1
15.1
17.7
17.7
17.7
17.7
17.7
17.7
10.2
9.8
9.5
9.4
9.4
9.3
7.7
7.5
7.2
7.3
7.3
7.4
17.1
17.1
17.1
17.1
17.1
17.1
18.7
18.7
18.7
18.7
18.7
18.7
12.0
12.0
12.0
12.0
12.0
12.0
9.1
9.1
9.1
9.1
9.1
9.1
16.4
16.4
16.4
16.4
16.4
16.4
17.8
17.8
17.8
17.8
17.8
17.8
Distribution and Transmission Annual Planning Report December 2013
28
Eastern Suburbs Area - Feeder Load Forecast
Summer (MVA)
Feeder name
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder 346
Load
9.2
9.1
9.0
9.2
9.4
9.6
(Bunnerong North STS
13.1
13.1
13.1
13.1
13.1
13.1
to Botany ZS T1)
33 Rating
Feeder 347
Load
9.9
12.2
13.2
13.2
13.2
13.2
(Bunnerong North STS
27.1
27.1
27.1
27.1
27.1
27.1
to Port Botany ZS T2)
33 Rating
Feeder 349
Load
9.2
9.1
9.0
9.2
9.4
9.6
(Bunnerong North STS
to Botany ZS T3)
33 Rating
15.1
15.1
15.1
15.1
15.1
15.1
Feeder 350
Load
8.7
8.6
8.5
8.7
8.9
9.1
(Bunnerong North STS
to Botany ZS T2)
33 Rating
16.2
16.2
16.2
16.2
16.2
16.2
Feeder 352
Load
6.2
6.2
6.2
6.2
6.2
6.2
(Bunnerong North STS
15.0
15.0
15.0
15.0
15.0
15.0
to Sydney Airport)
33 Rating
Feeder 353
Load
6.9
6.9
6.8
6.9
7.1
7.3
(Bunnerong North STS
17.4
17.3
17.3
17.4
17.3
17.3
to Botany ZS T4)
33 Rating
Feeder 354
Load
9.9
12.2
13.2
13.2
13.2
13.2
(Bunnerong North STS
to Port Botany ZS ZS
33 Rating
27.1
27.1
27.1
27.1
27.1
27.1
Feeder 356
Load
11.5
11.5
11.5
11.5
11.5
11.5
(Bunnerong North STS
to International Terminal) 33 Rating
16.7
16.7
16.7
16.7
16.7
16.7
Feeder 359
Load
11.5
11.5
11.5
11.5
11.5
11.5
(Bunnerong North STS
16.7
16.7
16.7
16.7
16.7
16.7
to International Terminal) 33 Rating
Feeder 360
Load
10.2
9.9
9.5
9.4
9.4
9.4
(Bunnerong North STS
17.7
17.7
17.7
17.7
17.7
17.7
to Mascot ZS T6)
33 Rating
Feeder 376
Load
17.2
17.1
17.0
17.3
17.8
18.3
(Surry Hills STS to Surry
Hills T2)
33 Rating
30.5
30.5
30.5
30.5
30.5
30.5
Feeder 377
Load
6.2
6.2
6.2
6.2
6.2
6.2
(Surry Hills STS to
Graving Dock ZS T1)
33 Rating
17.0
17.0
17.0
17.0
17.0
17.0
Feeder 378
Load
6.3
6.3
6.3
6.3
6.3
6.1
(Surry Hills STS to
16.5
16.5
16.5
16.5
16.5
16.5
Graving Dock ZS T2)
33 Rating
Feeder 380
Load
10.7
10.4
10.0
10.0
10.0
9.9
(Surry Hills STS to
29.7
29.7
29.7
29.7
29.7
29.7
Paddington ZS T4)
33 Rating
Feeder 381
Load
18.4
17.8
17.2
17.1
17.2
17.1
(Surry Hills STS to
Paddington ZS T3)
33 Rating
29.7
29.7
29.7
29.7
29.7
29.7
Feeder 382
Load
16.6
16.0
15.5
15.4
15.4
15.4
(Surry Hills STS to
Paddington ZS T2)
33 Rating
29.7
29.7
29.7
29.7
29.7
29.7
Feeder 383
Load
25.1
24.9
24.7
25.3
26.0
26.7
(Surry Hills STS to Surry
27.0
27.0
27.0
27.0
27.0
27.0
Hills T1)
33 Rating
Feeder 384
Load
19.8
19.7
19.6
20.0
20.6
21.1
(Surry Hills STS to Surry
30.5
30.5
30.5
30.5
30.5
30.5
Hills T4)
33 Rating
Feeder 385
Load
12.2
12.2
12.1
12.3
12.7
13.0
(Surry Hills STS to Surry
Hills T3)
33 Rating
29.7
29.7
29.7
29.7
29.7
29.7
Feeder 386 (Surry Hills
Load
16.0
15.6
15.2
15.3
15.4
15.5
STS to Darlinghurst ZS
T4)
33 Rating
27.1
27.1
27.1
27.1
27.1
27.1
Feeder 387
Load
16.8
16.4
16.0
16.0
16.2
16.3
(Surry Hills STS to
29.7
29.7
29.7
29.7
29.7
29.7
Darlinghurst ZS T2)
33 Rating
Feeder 388
Load
16.8
16.4
16.0
16.0
16.2
16.3
(Surry Hills STS to
29.7
29.7
29.7
29.7
29.7
29.7
Darlinghurst ZS T1)
33 Rating
Feeder 389
Load
14.3
14.0
13.7
13.7
13.8
13.9
(Surry Hills STS to
Darlinghurst ZS T3)
33 Rating
27.1
27.1
27.1
27.1
27.1
27.1
Feeder 390(1)
Load
4.0
(Surry Hills STS to
Waverley ZS T2)
33 Rating
14.9
-
Distribution and Transmission Annual Planning Report December 2013
Winter (MVA)
2015
2016
2013
2014
9.0
7.8
7.6
7.7
2017
7.9
2018
8.0
14.6
14.6
14.6
14.6
14.6
14.6
0.7
7.6
10.2
10.2
10.2
10.2
28.6
28.6
28.6
28.6
28.6
28.6
9.0
7.8
7.6
7.7
7.9
8.1
16.4
16.4
16.4
16.4
16.4
16.4
8.2
7.1
7.0
7.1
7.2
7.3
17.6
17.6
17.6
17.6
17.6
17.6
5.4
5.4
5.4
5.4
5.4
5.4
16.9
16.9
16.9
16.9
16.9
16.9
8.5
7.4
7.2
7.3
7.4
7.6
19.1
19.1
19.1
19.1
19.1
19.1
0.7
7.6
10.2
10.2
10.2
10.2
28.6
28.6
28.6
28.6
28.6
28.6
8.5
8.5
8.5
8.5
8.5
8.5
18.3
18.3
18.3
18.3
18.3
18.3
8.6
8.6
8.6
8.6
8.6
8.6
18.0
18.0
18.0
18.0
18.0
18.0
7.8
7.5
7.3
7.3
7.3
7.4
19.2
19.2
19.2
19.2
19.2
19.2
10.4
13.2
13.1
13.5
14.0
14.5
32.2
32.2
32.2
32.2
32.2
32.2
4.6
4.6
4.6
4.6
4.6
4.6
18.4
18.4
18.4
18.4
18.4
18.4
4.6
4.6
4.6
4.6
4.6
4.6
17.9
17.9
17.9
17.9
17.9
17.9
12.0
11.6
11.4
11.2
11.4
11.6
32.0
32.0
32.0
32.0
32.0
32.0
20.5
20.2
19.8
20.2
20.6
21.2
31.3
31.3
31.3
31.3
31.3
31.3
17.2
16.9
16.6
16.9
17.3
17.8
31.3
31.3
31.3
31.3
31.3
31.3
15.0
19.2
19.1
19.7
20.3
21.2
29.0
29.0
29.0
29.0
29.0
29.0
13.1
9.3
11.9
11.8
12.2
12.6
32.2
32.2
32.2
32.2
32.2
32.2
11.5
14.6
14.5
15.0
15.5
16.1
31.3
31.3
31.3
31.3
31.3
31.3
14.9
14.4
13.9
13.9
14.0
14.2
28.9
28.9
28.9
28.9
28.9
28.9
11.7
11.4
11.0
11.0
11.1
11.2
31.3
31.3
31.3
31.3
31.3
31.3
14.9
14.4
13.9
13.9
14.0
14.2
31.3
31.3
31.3
31.3
31.3
31.3
11.4
11.0
10.6
10.7
10.7
10.8
28.9
28.9
28.9
28.9
28.9
28.9
11.5
-
-
-
-
-
16.6
-
-
-
-
-
29
Eastern Suburbs Area - Feeder Load Forecast
Summer (MVA)
Winter (MVA)
Feeder name
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder 390(2)
Load
4.2
(Surry Hills STS to
Waverley ZS T2)
33 Rating
14.2
Feeder 391
Load
2.9
(Surry Hills STS to
Waverley ZS T3)
33 Rating
16.9
Feeder 392(1) (Surry
Load
3.0
Hills STS to Waverley
ZS T4)
33 Rating
14.3
Feeder 392(2)
Load
3.1
(Surry Hills STS to
Waverley ZS T4)
33 Rating
15.1
Feeder 393
Load
7.9
(Surry Hills STS to Rose
Bay ZS T4)
33 Rating
17.1
Feeder 394
Load
7.9
(Surry Hills STS to Rose
Bay ZS T3)
33 Rating
18.0
Feeder 395
Load
10.7
(Surry Hills STS to Rose
Bay ZS T2)
33 Rating
16.8
Feeder 396(1)
Load
13.6
0.4
0.4
0.4
0.4
0.4
(Surry Hills STS to
Paddington ZS)
33 Rating
17.8
15.6
15.6
15.6
15.6
15.6
Feeder 396(2)
Load
13.4
(Surry Hills STS to
Waverley ZS)
33 Rating
16.6
Feeder 478
Load
13.5
(Waverley ZS to Rose
Bay ZS T1)
33 Rating
18.5
Feeder 9SB/2
Load
65.4
62.9
60.2
60.0
60.0
59.7
(Surry Hills STS to
Double Bay ZS)
33 Rating 132.0
132.0
132.0
132.0
132.0
132.0
3.5.3
2013
2014
2015
2016
2017
2018
11.6
-
-
-
-
-
16.1
-
-
-
-
-
7.8
-
-
-
-
-
18.5
-
-
-
-
-
8.5
-
-
-
-
-
16.2
-
-
-
-
-
8.6
-
-
-
-
-
17.1
-
-
-
-
-
10.4
-
-
-
-
-
18.2
-
-
-
-
-
13.1
-
-
-
-
-
19.7
-
-
-
-
-
15.4
-
-
-
-
-
18.0
-
-
-
-
-
21.1
0.4
0.4
0.4
0.4
0.4
19.4
15.6
15.6
15.6
15.6
15.6
20.5
-
-
-
-
-
17.1
-
-
-
-
-
20.3
-
-
-
-
-
20.5
-
-
-
-
-
64.3
64.6
62.6
62.7
63.0
63.8
140.0
140.0
140.0
140.0
140.0
140.0
STS and ZS load forecast
Eastern Suburbs Area - STS and ZS details
Summer
Winter
Summer
Winter
378.8
466.4
266.0
346.7
274.4
346.7
266.0
346.7
274.4
346.7
11.2
13.8
19.1
19.1
-
-
-
-
-
-
-
-
81.6
127.0
152.4
121.9
157.2
22.2
18.7
171.5
124.6
150.6
76.2
103.5
101.3
114.3
112.3
100.0
68.5
152.4
126.4
96.0
76.0
152.4
82.3
127.0
152.7
121.9
157.2
22.2
20.8
171.5
124.6
150.6
76.2
105.0
105.7
114.3
112.3
100.0
71.2
152.7
127.0
96.0
79.3
152.6
53.1
62.8
87.6
85.2
81.3
0.0
0.0
114.3
62.2
102.8
74.8
76.5
68.1
66.5
59.2
78.0
48.5
87.5
77.8
71.0
51.7
83.6
53.1
65.0
93.0
90.1
87.8
0.0
0.0
114.3
65.0
102.8
74.8
78.8
72.7
69.8
59.2
78.0
50.4
87.5
77.8
75.4
55.4
90.3
53.1
70.3
92.4
85.2
89.2
10.0
10.0
127.1
64.4
103.6
66.3
76.5
68.1
66.5
59.2
85.9
48.5
97.9
77.8
71.7
51.7
93.0
53.1
78.0
111.6
90.1
99.3
10.0
10.0
137.2
78.0
121.2
66.3
78.8
72.7
69.8
59.2
87.0
50.4
104.9
77.8
83.5
55.4
108.4
11.2
11.2
11.2
11.2
11.2
13.8
13.8
13.8
11.2
11.2
13.8
13.8
11.2
11.2
11.2
2.9
2.9
11.2
13.8
2.9
2.9
13.8
19.1
19.1
3.5
19.1
5.0
19.1
19.1
22.2
3.5
5.0
5.0
19.1
5.0
5.0
5.0
3.5
3.5
19.1
19.1
3.5
3.5
19.1
Distribution and Transmission Annual Planning Report December 2013
0.63
0.07
1.16
0.19
0.42
0.12
0.96
0.81
1.45
0.37
1.02
0.11
0.61
1.03
0.23
0.31
0.39
Other
Winter
378.8
466.4
Solar PV
Summer
Bunnerong North 132/33kV STS
Surry Hills 132/33kV STS
Alexandria 33/5kV ZS
Botany 33/11kV ZS
Campbell St 132/11kV ZS
Clovelly 132/11kV ZS
Darlinghurst 33/11kV ZS
Double Bay 132/11kV ZS
Graving Dock No 1 33/11kV ZS
Graving Dock No 2 33/11kV ZS
Green Square 132/11kV ZS
Kingsford 132/11kV ZS
Maroubra 132/11kV ZS
Marrickville 132/11kV ZS
Mascot 33/11kV ZS
Matraville 33/11kV ZS
Paddington 33/11kV ZS
Port Botany 33/11kV ZS
Rose Bay 132/11kV ZS
Rose Bay 33/11kV ZS
St Peters 132/11kV ZS
Surry Hills 33/11kV ZS
Waverley 132/11kV ZS
Waverley 33/11kV ZS
Zetland 132/11kV ZS
Licence Capacity 95% Peak Load
Embedded
(MVA)
Exceeded (hrs/yr) Generation (MVA)
Winter
Substation
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
1.47
0.32
4.60
4.40
1.40
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
30
SUMMER - Eastern Suburbs Area STS and ZS Load Forecast
Substation
Bunnerong North 132/33kV STS
Surry Hills 132/33kV STS
Alexandria 33/5kV ZS
Botany 33/11kV ZS
Campbell St 132/11kV ZS
Clovelly 132/11kV ZS
Darlinghurst 33/11kV ZS
Double Bay 132/11kV ZS
Graving Dock No 1 33/11kV ZS
Graving Dock No 2 33/11kV ZS
Green Square 132/11kV ZS
Kingsford 132/11kV ZS
Maroubra 132/11kV ZS
Marrickville 132/11kV ZS
Mascot 33/11kV ZS
Matraville 33/11kV ZS
Paddington 33/11kV ZS
Port Botany 33/11kV ZS
Randwick 33/11kV ZS
Rose Bay 132/11kV ZS
Rose Bay 33/11kV ZS
St Peters 132/11kV ZS
Surry Hills 33/11kV ZS
Waverley 132/11kV ZS
Waverley 33/11kV ZS
Zetland 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
261.4
257.5
246.9
227.3
227.4
222.3
238.5
245.6
246.5
248.4
249.9
0.99
0.99
0.99
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
218.1
231.4
235.7
217.0
211.3
211.0
186.1
172.8
173.6
175.3
176.5
0.92
1.00
0.98
0.97
1.00
1.00
1.00
0.99
0.99
0.99
0.99
6.0
0.99
38.4
34.4
34.0
32.3
29.4
27.3
27.1
26.9
27.3
28.0
28.6
0.99
0.99
0.89
0.88
0.91
0.91
0.91
0.91
0.91
0.91
0.91
31.5
31.7
32.8
29.2
43.6
44.5
44.8
45.0
46.5
48.3
50.1
0.91
0.91
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
64.1
66.3
67.0
63.2
59.1
60.3
59.6
58.7
59.5
60.7
61.8
0.94
0.94
0.95
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
51.2
54.1
54.5
48.6
48.7
48.6
47.6
46.5
46.6
47.1
47.4
0.92
1.00
0.94
0.95
0.97
0.97
0.97
0.97
0.97
0.97
0.97
63.7
66.8
70.1
57.8
60.0
60.8
58.8
56.8
56.4
56.4
56.2
0.93
0.93
0.93
0.94
0.95
0.95
0.95
0.95
0.95
0.95
0.95
7.6
6.8
7.0
6.1
8.1
8.1
8.1
8.1
8.1
8.1
8.1
0.92
1.00
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
6.0
7.2
6.2
6.1
7.4
7.4
7.4
7.4
7.4
7.4
7.4
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
23.7
31.3
34.6
28.8
34.5
46.6
52.2
48.6
50.9
53.7
56.5
0.92
0.92
0.79
0.90
0.79
0.79
0.79
0.79
0.79
0.79
0.79
11.5
38.7
37.2
37.5
41.1
41.3
41.5
42.8
44.5
46.1
0.93
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
56.4
55.2
56.3
49.5
44.6
47.8
47.6
47.3
48.2
49.5
50.7
0.91
0.91
0.92
0.93
0.94
0.94
0.94
0.94
0.94
0.94
0.94
56.3
56.7
55.5
50.5
49.3
50.1
48.6
47.1
46.8
47.0
47.0
0.87
0.87
0.88
0.90
0.91
0.91
0.91
0.91
0.91
0.91
0.91
52.5
55.2
56.1
50.8
50.6
50.4
48.8
47.1
46.7
46.6
46.4
0.99
0.99
0.89
0.89
0.90
0.90
0.90
0.90
0.90
0.90
0.90
40.1
43.4
43.5
40.8
42.4
26.6
27.3
27.2
27.9
28.7
29.5
0.99
0.99
0.92
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
31.4
32.7
32.8
30.0
29.6
28.5
27.7
26.8
26.6
26.7
26.6
0.92
1.00
0.94
0.91
0.95
0.95
0.95
0.95
0.95
0.95
0.95
3.2
2.8
27.9
34.0
36.9
36.9
36.9
36.9
0.90
0.84
0.90
0.90
0.90
0.90
0.90
0.90
33.2
27.6
0.99
0.99
17.1
34.1
34.9
36.0
36.9
0.92
0.92
0.92
0.92
0.92
34.9
35.0
38.9
31.0
34.0
34.2
17.1
0.92
1.00
0.92
0.92
0.92
0.92
0.92
65.7
65.9
66.7
66.2
66.1
72.4
75.0
74.5
75.9
78.0
79.7
0.90
0.90
0.93
0.94
0.93
0.93
0.93
0.93
0.93
0.93
0.93
54.8
57.4
60.7
57.7
43.6
56.3
56.0
55.6
56.8
58.3
59.7
0.92
1.00
0.92
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
11.1
22.1
21.7
22.0
22.4
22.7
0.94
0.94
0.94
0.94
0.94
0.94
24.7
23.4
24.2
21.5
22.7
11.1
0.92
1.00
0.94
0.94
0.94
0.94
80.9
81.2
80.4
69.1
70.7
60.6
58.7
56.8
56.5
56.7
56.7
0.95
0.95
0.96
0.97
0.98
0.99
0.99
0.99
0.99
0.99
0.99
Distribution and Transmission Annual Planning Report December 2013
31
WINTER - Eastern Suburbs Area STS and ZS Load Forecast
Substation
Bunnerong North 132/33kV STS
Surry Hills 132/33kV STS
Alexandria 33/5kV ZS
Botany 33/11kV ZS
Campbell St 132/11kV ZS
Clovelly 132/11kV ZS
Darlinghurst 33/11kV ZS
Double Bay 132/11kV ZS
Graving Dock No 1 33/11kV ZS
Graving Dock No 2 33/11kV ZS
Green Square 132/11kV ZS
Kingsford 132/11kV ZS
Maroubra 132/11kV ZS
Marrickville 132/11kV ZS
Mascot 33/11kV ZS
Matraville 33/11kV ZS
Paddington 33/11kV ZS
Port Botany 33/11kV ZS
Randwick 33/11kV ZS
Rose Bay 132/11kV ZS
Rose Bay 33/11kV ZS
St Peters 132/11kV ZS
Surry Hills 33/11kV ZS
Waverley 132/11kV ZS
Waverley 33/11kV ZS
Zetland 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
275.8
0.99
230.1
0.95
5.6
0.99
36.0
0.99
26.5
0.93
97.8
0.97
47.1
0.95
76.1
0.85
5.0
0.95
8.1
0.90
17.2
0.97
58.0
0.94
63.4
0.94
42.1
0.99
51.3
0.99
31.8
0.95
49.6
0.99
54.1
0.95
57.2
0.94
48.3
0.95
34.9
0.95
71.5
0.98
Actual Load
2009
2010
2011
252.7
217.2
212.3
1.00
1.00
1.00
220.1
209.1
212.3
1.00
1.00
1.00
3.2
1.00
33.1
29.2
29.9
1.00
0.93
0.94
25.2
24.7
24.1
0.94
0.95
0.95
87.0
87.8
87.5
0.97
0.98
0.99
43.5
44.7
45.7
1.00
0.96
0.95
68.7
68.6
68.0
0.97
0.97
0.97
7.7
4.4
8.5
1.00
0.90
0.90
3.3
6.1
7.0
0.90
0.90
0.90
18.0
26.7
28.1
0.95
0.95
0.95
35.6
48.0
0.90
0.90
58.8
56.9
54.9
0.95
0.95
0.95
55.5
56.9
53.3
0.94
0.97
0.97
38.9
43.8
42.6
1.00
0.93
0.91
44.5
45.8
48.1
1.00
0.95
0.95
31.0
30.7
32.3
1.00
0.96
0.97
2.8
0.90
44.6
12.9
1.00
0.96
46.2
44.5
46.2
1.00
0.97
0.97
52.9
53.4
53.0
0.96
0.95
0.98
45.5
47.4
48.5
1.00
0.93
0.92
30.4
33.3
29.3
1.00
0.98
0.98
63.6
65.6
63.3
0.98
0.98
0.98
Distribution and Transmission Annual Planning Report December 2013
2012
180.2
1.00
206.3
1.00
26.7
0.95
33.1
0.95
79.8
0.99
39.0
0.98
63.3
0.98
7.3
0.90
8.7
0.90
28.4
0.95
46.9
0.90
49.5
0.93
51.8
0.98
39.8
0.89
43.2
0.95
31.4
0.97
2.5
0.84
42.7
0.97
53.9
0.96
35.9
0.95
28.4
0.97
56.5
0.99
2013
199.4
1.00
200.1
1.00
26.6
0.95
35.1
0.95
80.7
0.99
38.6
0.98
62.3
0.98
7.8
0.90
8.1
0.90
31.9
0.95
51.2
0.90
51.4
0.93
51.8
0.98
40.1
0.89
43.8
0.95
31.6
0.97
2.5
0.84
43.3
0.97
56.3
0.96
36.4
0.95
29.3
0.97
54.4
0.99
2014
184.0
1.00
193.4
1.00
23.2
0.95
35.1
0.95
76.9
0.99
37.4
0.98
62.6
0.98
7.8
0.90
8.1
0.90
40.1
0.95
51.7
0.90
52.4
0.93
50.3
0.98
38.9
0.89
27.4
0.95
31.2
0.97
26.6
0.92
42.0
0.97
60.0
0.96
46.0
0.95
14.6
0.97
47.1
1.00
Forecast Load
2015
2016
202.2
210.7
1.00
1.00
160.7
143.0
0.99
0.99
22.7
23.0
0.95
0.95
35.0
36.2
0.95
0.95
74.5
74.7
0.99
0.99
36.2
36.2
0.98
0.98
60.6
60.8
0.98
0.98
7.8
7.8
0.90
0.90
8.1
8.1
0.90
0.90
39.6
41.0
0.95
0.95
51.5
53.0
0.90
0.90
52.3
54.1
0.93
0.93
48.7
48.9
0.98
0.98
37.6
37.7
0.89
0.89
27.7
28.2
0.95
0.95
30.7
31.2
0.97
0.97
35.6
35.6
0.92
0.92
20.3
40.8
0.97
0.97
20.4
0.97
62.7
64.5
0.96
0.96
45.7
47.1
0.95
0.95
28.8
28.9
0.97
0.97
45.6
45.8
1.00
1.00
2017
212.0
1.00
145.1
0.99
23.3
0.95
37.5
0.95
75.2
0.99
36.4
0.98
61.1
0.98
7.8
0.90
8.1
0.90
42.4
0.95
54.7
0.90
56.0
0.93
49.3
0.98
37.8
0.89
28.8
0.95
31.9
0.97
35.6
0.92
41.0
0.97
66.5
0.96
48.6
0.95
29.1
0.97
46.1
1.00
2018
214.0
1.00
148.1
0.99
23.9
0.95
39.0
0.95
76.1
0.99
36.8
0.98
61.9
0.98
7.8
0.90
8.1
0.90
44.2
0.95
56.9
0.90
58.4
0.93
49.9
0.98
38.2
0.89
29.6
0.95
32.7
0.97
35.6
0.92
41.6
0.97
69.0
0.96
50.4
0.95
29.5
0.97
46.8
1.00
32
3.6
3.6.1
Greater Cessnock Load Area
Description of Greater Cessnock area
The Greater Cessnock network area extends in the north to Rothbury and Allandale and south to Laguna and
Quorrobolong. The area also extends from Kurri in the east, to Mt View and Pokolbin State Forest in the west. The
area is geographically bounded by the Sugarloaf Mountain range in the east as well as the Watagan Mountains and
Wollemi National Park to the south.
Predominantly rural, the main urban development lies between and around Kurri township and the City of
Cessnock. Development activity is focussed around the Pokolbin and Rothbury vineyard district, with ongoing
winemaking and tourism development, as well as residential developments such as the Vineyards Resort at
Rothbury becoming more prevalent. A new large integrated residential development has been proposed to the
north of the area near Rothbury. An extensive industrial park is also being developed to the south-west of Kurri
known as the Hunter Economic Zone (HEZ), which has the potential to contain large industrial facilities.
The network in the Greater Cessnock area:

predominantly comprises a 33kV network supply from the Kurri sub-transmission substation (STS), which is
itself supplied via 132kV feeders from TransGrid Newcastle BSP at Killingworth

includes two 132/11kV zone substations, one located at Rothbury and the other at Kurri

includes four 33/11kV zone substations

includes one 33kV connected mining customer near Ellalong

consists of approximately 100km of predominantly overhead 33kV feeder network

is partially traversed by a number of 132kV overhead feeders between Killingworth and Kurri STS, and

is traversed by 132kV and 66kV feeders between Kurri sub-transmission substation and Singleton STS.
Figure 9: Greater Cessnock load area
Distribution and Transmission Annual Planning Report December 2013
33
Table 7 – Identified system limitations in the Greater Cessnock load area
Location
1.
3.6.2
Cessnock 33/11kV zone substation
Identified
Limitation
Refer to
DAPR section
Asset Condition
5.3.12
Sub-transmission feeder load forecast
Greater Cessnock Area - Feeder Load Forecast
Feeder name
Feeder 30092 (1)
(Cessnock ZS to Paxton
ZS)
Feeder 30092(3)
(Cessncok ZS to Paxton
ZS)
Feeder 30092(4)
(Cessnock ZS to Paxton
ZS)
Feeder 30092(6)
(Cessnock ZS to Paxton
ZS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder 30092(7)
(tee to Austar Kitchener)
Feeder 30095(1)
(Cessnock ZS to Austar
Ellalong)
Feeder 30095(3)
(Cessncok ZS to Austar
Ellalong)
Feeder 30095(4)
(Cessnock ZS to Austar
Ellalong)
Feeder KU1(1)
(Kurri STS to tee
Tomalpin and Cessnock)
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder KU1(2)
(tee to Tomalpin ZS)
33 Rating
Load
Feeder KU1(3)
(tee to Cessnock ZS)
Feeder KU6(1)
(Kurri STS to tee
Cessnock and Nulkaba)
Feeder KU6(3)
(Kurri STS to tee
Cessnock and Nulkaba)
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder KU6(4)
(tee to Nulkaba ZS)
33 Rating
Load
Feeder KU6(5)
(tee to Cessnock ZS)
33 Rating
Load
Feeder KU9(1)
(Kurri STS to Nulkaba)
33 Rating
Load
Feeder KU9(2)
(Kurri STS to Nulkaba)
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
7.7
7.7
7.7
7.7
7.8
7.9
3.7
7.5
7.5
7.6
7.7
7.8
20.7
20.7
20.7
20.7
20.7
20.7
23.0
23.0
23.0
23.0
23.0
23.0
7.7
7.7
7.7
7.7
7.8
7.9
3.7
7.5
7.5
7.6
7.7
7.7
21.0
21.0
21.0
21.0
21.0
21.0
15.1
28.0
28.0
28.0
28.0
28.0
5.5
5.4
5.4
5.4
5.5
5.6
4.1
4.1
4.1
4.2
4.2
4.3
13.6
13.6
13.6
13.6
13.6
13.6
15.1
15.1
15.1
15.1
15.1
15.1
5.5
5.5
5.5
5.5
5.6
5.6
-
4.1
4.1
4.2
4.3
4.4
21.0
21.0
21.0
21.0
21.0
21.0
-
28.0
28.0
28.0
28.0
28.0
5.0
5.0
5.0
5.0
5.0
5.0
-
5.0
5.0
5.0
5.0
5.0
31.0
31.0
31.0
31.0
31.0
31.0
-
41.0
41.0
41.0
41.0
41.0
9.8
9.8
9.8
9.8
9.8
9.8
10.3
10.3
10.3
10.3
10.3
10.3
20.7
20.7
20.7
20.7
20.7
20.7
23.0
23.0
23.0
23.0
23.0
23.0
9.8
9.8
9.8
9.8
9.8
9.8
10.3
10.3
10.3
10.3
10.3
10.3
20.7
20.7
20.7
20.7
20.7
20.7
23.0
23.0
23.0
23.0
23.0
23.0
9.8
9.8
9.8
9.8
9.8
9.8
10.3
10.3
10.3
10.3
10.3
10.3
20.7
20.7
20.7
20.7
20.7
20.7
23.0
23.0
23.0
23.0
23.0
23.0
33.9
33.2
34.4
33.9
33.7
33.5
27.8
31.9
31.4
31.5
31.6
31.7
41.7
41.7
41.7
41.7
41.7
41.7
46.5
46.5
46.5
46.5
46.5
46.5
0.3
0.3
0.3
0.3
0.3
0.3
0.8
0.8
0.8
0.8
0.8
0.8
46.8
46.8
46.8
46.8
46.8
46.8
63.7
63.7
63.7
63.7
63.7
63.7
32.6
31.9
32.7
32.3
32.1
31.9
26.2
29.9
29.4
29.5
29.6
29.8
41.6
41.6
41.6
41.6
41.6
41.6
56.1
56.1
56.1
56.1
56.1
56.1
35.9
35.3
36.6
36.5
36.6
36.6
27.4
30.4
29.8
30.1
30.4
30.8
41.7
41.7
41.7
41.7
41.7
41.7
46.6
46.6
46.6
46.6
46.6
46.6
35.9
35.3
36.6
36.5
36.6
36.6
27.4
30.4
29.8
30.1
30.4
30.8
41.7
41.7
41.7
41.7
41.7
41.7
46.6
46.6
46.6
46.6
46.6
46.6
19.9
19.7
20.7
20.8
21.1
21.5
13.8
13.7
13.4
13.9
14.2
14.5
46.8
46.8
46.8
46.8
46.8
46.8
63.7
63.7
63.7
63.7
63.7
63.7
31.7
31.0
31.4
31.2
31.0
30.8
25.4
29.0
28.5
28.6
28.7
28.8
41.5
41.5
41.5
41.5
41.5
41.5
56.0
56.0
56.0
56.0
56.0
56.0
20.4
20.3
21.6
21.8
22.1
22.5
14.4
14.3
14.1
14.4
14.8
15.3
40.3
40.3
40.3
40.3
40.3
40.3
45.0
45.0
45.0
45.0
45.0
45.0
20.4
20.3
21.6
21.8
22.1
22.5
14.4
14.3
14.1
14.4
14.8
15.3
40.3
40.3
40.3
40.3
40.3
40.3
45.0
45.0
45.0
45.0
45.0
45.0
Distribution and Transmission Annual Planning Report December 2013
34
3.6.3
STS and ZS load forecast
Greater Cessnock Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Kurri 132/33kV STS
Cessnock 33/11kV ZS
Kurri 132/11kV ZS
Nulkaba 33/11kV ZS
Paxton 33/11kV ZS
Rothbury 132/11kV ZS
Tomalpin 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
183.0
31.0
100.0
76.2
11.6
76.2
20.8
212.0
31.0
100.0
76.2
11.6
76.2
22.2
155.0
22.9
60.0
38.1
0.0
38.1
0.0
164.0
22.9
60.0
38.1
0.0
38.1
0.0
155.0
27.0
72.0
45.7
10.0
42.6
10.0
164.0
27.0
72.0
45.7
10.0
45.7
10.0
2.9
2.9
2.9
2.9
11.2
11.2
13.8
5.0
5.0
5.0
5.0
5.0
5.0
22.2
1.31
1.53
0.97
0.57
0.42
-
29.00
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
SUMMER - Greater Cessnock Area STS and ZS Load Forecast
Substation
Kurri 132/33kV STS
Cessnock 33/11kV ZS
Kurri 132/11kV ZS
Kurri 33/11kV ZS
Nulkaba 33/11kV ZS
Paxton 33/11kV ZS
Rothbury 132/11kV ZS
Tomalpin 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
142.1
149.5
130.2
114.4
124.6
137.3
137.3
137.3
138.8
141.1
143.7
0.98
1.00
0.98
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
29.4
28.5
24.5
17.5
22.6
21.4
20.7
20.0
19.6
19.4
19.1
0.98
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
32.5
23.4
28.3
27.4
27.7
27.9
28.5
29.3
30.2
0.92
0.96
0.96
1.00
1.00
1.00
1.00
1.00
1.00
29.2
29.6
0.98
1.00
19.0
19.6
21.1
14.5
19.7
21.1
21.1
21.0
21.1
21.4
21.8
0.98
1.00
0.95
0.99
0.99
1.00
1.00
1.00
1.00
1.00
1.00
5.8
5.4
5.4
3.9
5.5
5.3
5.3
5.3
5.3
5.4
5.4
0.98
1.00
0.94
0.94
0.95
0.95
0.95
0.95
0.95
0.95
0.95
10.9
13.2
13.3
8.4
10.4
15.3
15.3
15.3
15.4
15.7
16.0
0.96
0.93
0.96
0.98
0.97
0.96
0.96
0.96
0.96
0.96
0.96
1.4
1.7
1.8
1.4
1.8
1.8
1.8
1.8
1.8
1.8
1.8
0.98
1.00
0.95
0.99
0.99
0.99
0.99
0.99
0.99
0.99
0.99
WINTER - Greater Cessnock Area STS and ZS Load Forecast
Substation
Kurri 132/33kV STS
Cessnock 33/11kV ZS
Kurri 132/11kV ZS
Kurri 33/11kV ZS
Nulkaba 33/11kV ZS
Paxton 33/11kV ZS
Rothbury 132/11kV ZS
Tomalpin 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
129.6
0.99
18.8
0.99
23.0
0.99
13.6
0.99
4.5
0.99
6.0
1.00
0.1
0.99
Actual Load
2009
2010
2011
108.4
105.1
115.6
1.00
1.00
0.99
17.3
16.8
16.0
1.00
1.00
0.97
20.4
0.96
21.4
22.0
1.00
0.95
12.9
12.9
12.2
1.00
0.96
0.96
4.3
4.1
4.0
1.00
0.97
0.98
5.9
6.5
6.2
0.93
0.93
1.00
1.2
1.5
1.7
1.00
0.94
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
92.0
0.97
16.3
0.98
21.0
0.96
12.3
0.97
3.9
0.98
6.1
1.00
1.6
0.94
2013
102.2
0.97
14.6
1.00
18.8
0.99
13.8
0.97
4.1
0.98
8.4
1.00
1.6
0.94
2014
101.6
0.97
14.2
1.00
18.8
0.99
13.7
0.98
4.1
0.98
9.3
1.00
1.6
0.94
Forecast Load
2015
2016
100.8
102.4
0.97
0.97
13.7
13.7
1.00
1.00
18.7
19.3
0.99
0.99
13.5
13.9
0.98
0.97
4.0
4.1
0.98
0.98
9.3
9.5
1.00
1.00
1.6
1.6
0.94
0.94
2017
104.0
0.97
13.7
1.00
19.9
0.99
14.2
0.97
4.2
0.98
9.8
1.00
1.6
0.94
2018
106.0
0.97
13.7
1.00
20.6
0.99
14.6
0.97
4.3
0.98
10.1
1.00
1.6
0.94
35
3.7
3.7.1
Inner West Load Area
Description of Inner West area
The Inner West load area extends from Homebush Bay in the north, south-west to Rozelle and Leichhardt and west
as far as Auburn. The area is divided by parts of the harbour and the Lane Cove River. Parramatta Road runs
through the southern part of the area. The network in the Inner West area:

is supplied from TransGrid’s transmission system at Sydney North, and via Chullora sub-transmission
switching station from Beaconsfield West and Sydney South

includes 132/33kV sub-transmission substations at Homebush, Strathfield and Rozelle

includes four 132/11kV zone substations, supplied via Mason Park sub-transmission switching station

includes four 33/11kV zone substations supplied via Homebush sub-transmission substation, and Leichhardt
zone substation, which is supplied via Strathfield and Rozelle sub-transmission substations, and

includes Five Dock zone substation, Ausgrid’s oldest zone substation.
Figure 10: Inner West Load Area
Table 8 – Identified system limitations in Inner West load area
Location
Identified Limitation
Refer to DAPR
section
1.
Feeder 607 - Homebush STS to Concord ZS
Capacity
5.2.4
2.
Feeder 614 - Homebush STS to Auburn ZS
Asset Condition
5.2.4
3.
Feeder 615 - Homebush STS to Auburn ZS
Asset Condition
5.2.4
4.
Feeders 602 & 604 - Homebush STS to Lidcombe ZS
Asset Condition
5.2.4
5.
Feeder 605 - Homebush STS to Lidcombe ZS
Asset Condition
5.2.4
6.
Lidcombe ZS
Asset Condition
5.3.5
Distribution and Transmission Annual Planning Report December 2013
36
3.7.2
Sub-transmission feeder load forecast
Inner West Area - Feeder Load Forecast
Summer (MVA)
Feeder name
Feeder 200
(Mason Park STSS to
Flemington ZS)
Feeder 201
(Mason Park STSS to
Flemington ZS)
Feeder 601
(Homebush STS to
Auburn ZS)
Feeder 602
(Homebush STS to
Lidcombe ZS)
Feeder 604
(Homebush STS to
Lidcombe ZS)
Feeder 605
(Homebush STS to
Lidcombe ZS)
Feeder 606
(Homebush STS to
Concord ZS)
Feeder 607
(Homebush STS to
Concord ZS)
Feeder 608
(Homebush STS to
Concord ZS)
Feeder 609
(Homebush STS to
Concord ZS)
Feeder 610
(Homebush STS to Five
Dock ZS)
Feeder 612
(Homebush STS to Five
Dock ZS)
Feeder 613
(Homebush STS to Five
Dock ZS)
Feeder 615
(Homebush STS to
Auburn ZS)
Feeder 614
(Homebush STS to
Auburn ZS)
Feeder 617
(Homebush STS to Five
Dock ZS)
Feeder 763
(Rozelle STS to 763tee)
Feeder 763 (A)
(763 tee to Leichhardt
ZS)
Feeder 763 (B)
(763 tee to Leichhardt
ZS)
Feeder 771
(771tee to Leichhardt
ZS)
Feeder 771 (A)
(Strathfield STS to
771tee)
Feeder 771 (B)
(Strathfield STS to
771tee)
Feeder 773 (A)
(Strathfield STS to
Leichhardt ZS)
Feeder 773 (B)
(Strathfield STS to
Leichhardt ZS)
Feeder 90A
(Mason Park STSS to
Homebush STS)
Feeder 90L
(Mason Park STSS to
Homebush STS)
Feeder 923/1
(Mason Park STSS to
923tee)
Feeder 923/2
(923tee to Burwood ZS)
(kV)
Winter (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Load
132 Rating
Load
132 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
2013
2014
2015
2016
2017
112.5
109.8
106.9
107.4
109.2
109.9
75.4
81.8
78.3
78.8
79.0
2018
79.7
142.4
142.4
142.4
142.4
142.4
142.4
151.1
151.1
151.1
151.1
151.1
151.1
112.6
109.8
107.0
107.4
109.3
110.0
75.5
81.8
78.4
78.8
79.1
80.1
152.9
152.9
152.9
152.9
152.9
152.9
162.3
162.3
162.3
162.3
162.3
162.3
14.0
13.6
13.1
12.9
12.9
12.9
13.2
13.2
13.1
13.5
14.0
14.6
18.5
18.5
18.5
18.5
18.5
18.5
20.1
20.1
20.1
20.1
20.1
20.1
11.0
10.7
10.2
10.1
10.1
10.1
7.4
7.2
6.9
7.0
7.0
7.0
16.8
16.8
16.8
16.8
16.8
16.8
18.2
18.2
18.2
18.2
18.2
18.2
11.3
11.0
10.4
10.3
10.3
10.2
7.6
7.3
7.1
7.1
7.1
7.2
16.8
16.8
16.8
16.8
16.8
16.8
18.2
18.2
18.2
18.2
18.2
18.2
12.5
11.8
11.6
11.4
11.5
11.4
9.1
8.8
8.5
8.5
8.6
8.6
16.8
16.8
16.8
16.8
16.8
16.8
18.2
18.2
18.2
18.2
18.2
18.2
13.5
14.0
13.9
14.2
14.7
15.1
8.4
8.5
8.6
8.6
8.7
8.8
15.9
15.9
15.9
15.9
15.9
15.9
17.7
17.7
17.7
17.7
17.7
17.7
17.4
18.2
18.1
18.5
19.1
19.6
12.0
12.1
12.2
12.3
12.3
12.5
18.6
18.6
18.6
18.6
18.6
18.6
21.4
21.4
21.4
21.4
21.4
21.4
17.5
18.3
18.0
18.5
19.0
19.6
11.6
11.8
11.9
11.9
12.0
12.1
24.1
24.1
24.1
24.1
24.1
24.1
26.8
26.8
26.8
26.8
26.8
26.8
17.6
18.2
18.1
18.5
19.1
19.6
11.0
11.1
11.2
11.2
11.3
11.5
22.8
22.8
22.8
22.8
22.8
22.8
25.3
25.3
25.3
25.3
25.3
25.3
12.6
12.8
6.3
-
-
-
10.3
10.0
4.8
-
-
-
18.5
18.5
18.5
-
-
-
20.0
20.0
20.0
-
-
-
13.5
13.7
6.8
-
-
-
16.7
16.2
7.7
-
-
-
18.4
18.4
18.4
-
-
-
20.0
20.0
20.0
-
-
-
11.3
11.6
5.7
-
-
-
8.4
8.2
3.9
-
-
-
18.1
18.1
18.1
-
-
-
20.0
20.0
20.0
-
-
-
17.6
17.1
16.3
16.2
16.2
16.1
14.5
14.5
14.4
14.9
15.4
16.0
32.2
32.2
32.2
32.2
32.2
32.2
34.9
34.9
34.9
34.9
34.9
34.9
17.3
16.7
16.1
16.0
16.0
15.9
14.3
14.3
14.3
14.7
15.2
15.9
18.6
18.6
18.6
18.6
18.6
18.6
19.0
19.0
19.0
19.0
19.0
19.0
13.3
13.5
6.6
-
-
-
10.9
10.6
5.0
-
-
-
18.1
18.1
18.1
-
-
-
20.0
20.0
20.0
-
-
-
11.9
11.8
5.6
-
-
-
13.2
12.8
6.1
-
-
-
15.6
15.6
15.6
-
-
-
18.2
18.2
18.2
-
-
-
5.9
5.9
2.8
-
-
-
6.6
6.4
3.0
-
-
-
14.2
14.2
14.2
-
-
-
16.7
16.7
16.7
-
-
-
5.9
5.9
2.8
-
-
-
6.6
6.4
3.0
-
-
-
14.2
14.2
14.2
-
-
-
16.7
16.7
16.7
-
-
-
23.6
23.1
11.1
-
-
-
26.4
25.7
12.1
-
-
-
27.4
27.4
27.4
-
-
-
31.1
31.1
31.1
-
-
-
11.8
11.6
5.5
-
-
-
13.2
12.9
6.0
-
-
-
13.6
13.6
13.6
-
-
-
15.4
15.4
15.4
-
-
-
11.8
11.6
5.5
-
-
-
13.2
12.9
6.0
-
-
-
13.6
13.6
13.6
-
-
-
15.4
15.4
15.4
-
-
-
12.1
11.0
5.1
-
-
-
11.6
11.2
5.3
-
-
-
13.6
13.6
13.6
-
-
-
15.4
15.4
15.4
-
-
-
12.1
11.0
5.1
-
-
-
11.6
11.2
5.3
-
-
-
13.6
13.6
13.6
-
-
-
15.4
15.4
15.4
-
-
-
131.6
132.5
108.9
91.1
92.6
93.8
102.8
101.5
84.3
71.1
72.0
73.1
139.0
139.0
139.0
139.0
139.0
139.0
145.4
145.4
145.4
145.4
145.4
145.4
131.5
132.4
108.9
91.1
92.6
93.7
102.8
101.4
84.3
71.1
72.0
73.1
139.0
139.0
139.0
139.0
139.0
139.0
145.4
145.4
145.4
145.4
145.4
145.4
148.1
152.3
192.4
184.8
186.2
186.0
122.6
122.2
106.2
95.8
98.7
101.4
219.5
219.5
219.5
219.5
219.5
219.5
219.5
219.5
219.5
219.5
219.5
219.5
83.2
83.7
84.0
86.8
90.8
94.4
63.5
64.2
63.8
65.9
68.4
71.4
158.9
158.9
158.9
158.9
158.9
158.9
168.0
168.0
168.0
168.0
168.0
168.0
Distribution and Transmission Annual Planning Report December 2013
37
Inner West Area - Feeder Load Forecast
Summer (MVA)
Feeder name
Feeder 924/1
(Mason Park STSS to
924tee)
Feeder 924/2
(924tee to Burwood ZS)
Feeder 90G
(Mason Park STSS to
Olympic Park ZS)
Feeder 90U
(Mason Park STSS to
Olympic Park ZS)
Load
132 Rating
Load
132 Rating
2016
2017
2018
145.3
150.1
193.1
183.6
184.5
184.7
125.0
124.8
107.7
97.0
99.6
103.2
228.4
228.4
228.4
228.4
228.4
228.4
257.4
257.4
257.4
257.4
257.4
257.4
83.8
84.1
84.6
87.2
91.4
94.7
63.8
64.5
64.1
66.3
68.7
71.9
168.0
168.0
168.0
168.0
168.0
168.0
177.2
177.2
177.2
177.2
177.2
177.2
-
-
1.2
1.2
1.2
1.2
-
-
1.2
1.2
1.2
1.2
-
-
212.0
212.0
212.0
212.0
-
-
218.0
218.0
218.0
218.0
-
-
1.2
1.2
1.2
1.2
-
-
1.2
1.2
1.2
1.2
-
-
212.0
212.0
212.0
212.0
-
-
218.0
218.0
218.0
218.0
Load
132 Rating
Load
132 Rating
2013
2014
2015
STS and ZS load forecast
Winter
Summer
Winter
Summer
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Homebush 132/33kV STS
Rozelle 132/33kV STS
Strathfield 132/33kV STS
Auburn 33/11kV ZS
Burwood 132/11kV ZS
Concord 33/11kV ZS
Croydon 132/11kV ZS
Drummoyne 132/11kV ZS
Five Dock 33/11kV ZS
Flemington 132/11kV ZS
Homebush Bay 132/11kV ZS
Leichhardt 132/11kV ZS
Leichhardt 33/11kV ZS
Lidcombe 33/11kV ZS
Olympic Park 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
266.2
40.0
129.5
75.9
152.4
81.4
124.6
102.1
64.6
152.4
106.7
109.3
114.3
54.1
124.6
266.2
45.0
137.2
75.9
152.5
81.4
124.6
112.3
65.6
152.4
115.1
120.3
114.3
55.2
124.6
140.3
0.0
68.6
41.0
83.6
54.4
62.2
56.2
41.3
98.7
53.2
59.5
65.8
33.4
62.2
142.9
0.0
68.6
41.0
90.3
54.4
65.0
61.8
44.2
106.6
57.4
62.5
69.1
33.4
65.0
140.3
0.0
68.6
41.0
100.3
60.9
74.7
67.4
41.3
109.7
59.1
65.5
65.8
33.4
74.7
142.9
0.0
68.6
41.0
108.4
65.3
78.0
63.3
44.2
127.9
68.9
70.4
69.1
33.4
78.0
11.2
11.2
11.2
13.8
2.9
11.2
2.9
2.9
2.9
13.8
13.8
11.2
11.2
13.8
13.8
5.0
5.0
5.0
22.2
5.0
5.0
3.5
3.5
3.5
19.1
19.1
5.0
5.0
5.0
19.1
Embedded
Generation
(MVA)
Other
Inner West Area - STS and ZS details
Solar
PV
3.7.3
Winter (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
-
2.00
-
0.29
1.64
0.76
-
1.16
0.85
0.97
1.20
-
0.95
0.56
-
Identified
Limitatio
n in next
5 years
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
SUMMER - Inner West Area STS and ZS Load Forecast
Substation
Homebush 132/33kV STS
Rozelle 132/33kV STS
Strathfield 132/33kV STS
Auburn 33/11kV ZS
Burwood 132/11kV ZS
Concord 33/11kV ZS
Croydon 132/11kV ZS
Drummoyne 132/11kV ZS
Five Dock 33/11kV ZS
Flemington 132/11kV ZS
Homebush Bay 132/11kV ZS
Leichhardt 132/11kV ZS
Leichhardt 33/11kV ZS
Lidcombe 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
101.6
121.9
132.2
108.1
114.3
120.6
121.1
102.1
85.8
87.1
88.1
1.00
1.00
0.98
0.98
0.99
0.99
0.99
0.99
1.00
1.00
1.00
14.0
11.4
12.2
10.4
11.2
11.9
11.8
7.3
0.86
0.86
0.90
0.73
0.90
0.91
0.91
0.92
57.8
56.1
44.5
47.0
51.6
50.9
50.6
41.1
31.7
31.7
31.7
0.98
0.98
0.92
0.95
0.98
0.98
0.98
0.98
0.98
0.98
0.98
22.8
29.7
27.6
29.2
27.8
29.9
28.9
27.9
27.7
27.6
27.5
0.84
0.84
0.84
0.83
0.90
0.90
0.90
0.90
0.90
0.90
0.90
78.3
81.4
84.2
70.4
78.0
74.0
74.3
74.5
76.7
79.5
82.1
0.92
0.92
0.90
0.91
0.91
0.96
0.96
0.96
0.96
0.96
0.96
45.5
44.5
45.6
38.0
43.0
46.4
48.1
47.9
48.9
50.4
51.7
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
18.2
37.2
38.9
40.6
0.92
0.92
0.92
0.92
51.2
55.6
58.1
48.8
50.7
54.3
55.1
55.9
58.1
60.9
63.6
0.94
0.94
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
29.3
33.6
38.2
30.0
32.7
35.7
36.1
18.3
0.95
0.95
0.94
0.95
0.92
0.92
0.92
0.92
86.1
85.8
89.2
78.6
84.1
93.1
91.3
89.4
89.8
90.9
91.6
0.88
0.88
0.92
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
50.2
45.7
47.7
42.9
45.9
52.9
52.0
45.6
45.8
46.3
46.6
0.94
0.94
0.95
0.95
0.96
0.96
0.96
0.96
0.96
0.96
0.96
16.3
32.7
33.4
33.9
0.93
0.93
0.93
0.93
32.3
28.8
28.4
28.8
33.9
33.5
33.0
16.3
0.98
0.98
0.93
0.93
0.93
0.93
0.93
0.93
28.5
27.7
29.5
26.1
21.7
22.6
21.8
21.1
20.9
20.8
20.7
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
Distribution and Transmission Annual Planning Report December 2013
38
WINTER - Inner West Area STS and ZS Load Forecast
Substation
Homebush 132/33kV STS
Rozelle 132/33kV STS
Strathfield 132/33kV STS
Auburn 33/11kV ZS
Burwood 132/11kV ZS
Concord 33/11kV ZS
Croydon 132/11kV ZS
Drummoyne 132/11kV ZS
Five Dock 33/11kV ZS
Flemington 132/11kV ZS
Homebush Bay 132/11kV ZS
Leichhardt 132/11kV ZS
Leichhardt 33/11kV ZS
Lidcombe 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
109.7
1.00
17.8
0.86
55.9
0.98
17.5
1.00
72.2
0.93
39.0
1.00
71.2
0.97
40.1
1.00
69.4
0.92
43.4
0.96
37.9
0.98
23.5
1.00
2009
104.3
1.00
18.3
0.86
50.3
0.99
23.6
1.00
66.4
0.94
33.9
1.00
60.9
0.96
34.7
1.00
59.7
0.92
37.4
0.99
33.3
0.99
20.8
1.00
Actual Load
2010
2011
105.1
102.7
1.00
1.00
18.5
19.1
0.87
0.90
48.2
40.6
0.98
0.93
28.1
21.5
0.83
0.84
61.5
66.4
0.94
0.90
33.0
32.5
0.93
0.93
63.0
61.3
0.95
0.95
39.9
37.9
0.96
0.96
69.9
62.2
0.91
0.92
39.0
40.3
0.99
0.97
30.8
30.8
0.93
0.93
24.8
23.0
0.94
0.92
Distribution and Transmission Annual Planning Report December 2013
2012
94.7
0.99
19.8
0.74
47.8
0.99
25.5
0.92
61.9
0.95
30.1
0.93
56.5
0.95
31.6
0.97
64.8
0.92
34.5
0.98
37.1
0.93
20.1
0.94
2013
93.6
0.99
17.9
0.68
47.0
0.99
26.4
0.92
59.9
0.99
30.5
0.93
58.7
0.95
34.2
0.97
66.5
0.92
36.7
0.98
37.3
0.93
16.1
0.94
2014
92.3
0.99
17.4
0.68
46.5
0.99
26.4
0.92
60.5
0.99
30.8
0.93
56.9
0.95
33.2
0.97
71.0
0.92
43.7
0.98
36.3
0.93
15.7
0.94
Forecast Load
2015
2016
76.2
62.5
1.00
1.00
10.9
0.65
36.1
26.1
0.99
0.99
26.3
27.1
0.92
0.92
60.1
61.9
0.99
0.99
31.1
31.2
0.93
0.93
16.1
32.3
0.97
0.97
55.2
55.4
0.95
0.95
16.1
0.97
68.7
68.7
0.92
0.92
36.6
37.1
0.98
0.98
17.7
35.5
0.93
0.93
17.7
0.93
15.1
15.1
0.94
0.94
2017
63.3
1.00
26.1
0.99
28.0
0.92
63.9
0.99
31.4
0.93
32.5
0.97
55.7
0.95
69.0
0.92
37.6
0.98
35.9
0.93
15.2
0.94
2018
64.5
1.00
26.1
0.99
29.2
0.92
66.4
0.99
31.8
0.93
32.9
0.97
56.4
0.95
69.7
0.92
38.4
0.98
36.5
0.93
15.4
0.94
39
3.8
3.8.1
Lower Central Coast Load Area
Description of Lower Central Coast area
The Lower Central Coast area includes all of the Gosford local government area and a portion of Wyong Shire. The
area extends south from Tuggerah Bulk Supply Point (BSP) to Broken Bay/Brisbane Water. There is bushland to
the west of the region, and water to the east and south. The coastal area of the Lower Central Coast is a popular
holiday destination and is a dormitory suburb for Sydney. The area is currently a mix of rural, residential,
commercial and industrial land use.
The Department of Planning’s Regional Strategy for the Central Coast predicts continued population growth in the
area over the next 25 years. Over 16,000 additional dwellings are expected in the Gosford City Council area in the
period to 2031, as a result of in-fill development. The current trend of redeveloping smaller, older dwellings into
large modern houses is also expected to continue.
As the population grows, industries in the region are likely to generate an increase in the number of jobs in
wholesaling, retailing, property and business services, tourism, health services, cultural and recreational services
and personal services. Although manufacturing jobs will increase in total numbers, the proportion of manufacturing
jobs will decline. Development in the area is currently constrained by water supply issues, which prevent
development of extensive areas of land west of the Sydney to Newcastle freeway. Greater population growth may
be possible if the water supply issues are resolved.
The network in the Lower Central Coast area:

is normally supplied from TransGrid’s transmission system at Tuggerah and Vales Point Bulk Supply Points to
the north via Ausgrid’s Central Coast 132kV transmission system. There is also a “normally closed” connection
with Sydney East Bulk Supply Point to the south

includes a mix of 132kV, 66kV and 33kV feeders and 132/11kV, 66/11kV and 33/11kV zone substations.
132kV supply to zone substations is a relatively recent supply development in the area. Historically, areas of
high load density were supplied at 66kV

is surrounded on three sides by water and bushland, which limits interconnection with other areas

supplies RailCorp at 66kV via the Ourimbah sub-transmission substation, and

provides two 33kV supplies at Mangrove Creek and Bangalow Creek for water pumping.
Figure 11: Lower Central Coast Load Area
Distribution and Transmission Annual Planning Report December 2013
40
Table 9 – Identified system limitations in Lower Central Coast load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Lisarow ZS
Asset Condition
(11kV switchgear)
5.3.6
2.
Lisarow ZS
Asset Condition
(33kV switchgear)
5.3.6
3.
Umina ZS
Asset Condition
5.3.6
4.
Feeders 794 - Ourimbah STS to Peats Ridge ZS
Capacity
5.2.5
5.
Feeders 720 - Gosford STS to Peats Ridge ZS
Capacity
5.2.5
Distribution and Transmission Annual Planning Report December 2013
41
3.8.2
Sub-transmission feeder load forecast
Lower Central Coast Area - Feeder Load Forecast
Summer (MVA)
Feeder name
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder 268
Load
12.1
12.1
12.2
12.5
12.9
13.3
(Ourimbah STS to
Wamberal ZS)
132 Rating 124.0
124.0
124.0
124.0
124.0
124.0
Feeder 720
Load
20.0
22.2
22.2
22.5
22.9
23.1
(Gosford STS to Peats
Ridge ZS)
33 Rating
22.9
22.9
22.9
22.9
22.9
22.9
Feeder 721
Load
23.3
23.5
23.8
24.6
25.3
26.0
(Gosford STS to Lisarow
ZS)
33 Rating
39.3
39.3
39.3
39.3
39.3
39.3
Feeder 757
Load
6.4
6.4
6.4
6.4
6.4
6.4
(Peats Ridge ZS to
22.9
22.9
22.9
22.9
22.9
22.9
Mangrove Creek ZS)
33 Rating
Feeder 794
Load
20.6
23.1
23.1
23.4
23.8
24.1
(Ourimbah STS to Peats
22.9
22.9
22.9
22.9
22.9
22.9
Ridge ZS)
33 Rating
Feeder 799
Load
23.2
23.4
23.7
24.5
25.2
25.9
(Ourimbah STS to
Lisarow ZS)
33 Rating
32.9
32.9
32.9
32.9
32.9
32.9
Load
Feeder 824/1
(Gosford STS to 824tee)
66 Rating
Feeder 824/2
(824tee to 824tee2)
66 Rating
Feeder 824/3
(Erina ZS to 824tee)
Feeder 824/4
(Wamberal ZS to
824tee2)
Feeder 824/5
(Avoca ZS to 824tee2)
Feeder 826
(Gosford STS to Erina
ZS)
Feeder 828
(Gosford to STS Woy
Woy ZS)
Feeder 830
(Gosford STS to Umina
ZS)
Feeder 840
(Woy Woy ZS to Umina
ZS)
Load
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
Feeder 841
(Avoca ZS to Erina ZS)
66 Rating
Feeder 883
Load
(Avoca ZS to Empire
Bay ZS)
66 Rating
Feeder 884
Load
(Woy Woy ZS to Empire
Bay ZS)
66 Rating
Feeder 88J
Load
(Ourimbah STS to Long
Jetty ZS)
66 Rating
Feeder 88M
Load
(Ourimbah STS to Long
Jetty ZS)
66 Rating
Feeder 954
Load
(Tuggerah BSP to
Berkeley Vale ZS)
132 Rating
Feeder 94L
Load
(Tuggerah BSP to
Brekeley Vale ZS)
132 Rating
2013
2014
Winter (MVA)
2015
2016
2017
15.8
15.7
15.6
16.2
16.7
17.3
130.0
130.0
130.0
130.0
130.0
130.0
2018
13.3
15.5
15.4
15.7
16.2
16.6
22.9
22.9
22.9
22.9
22.9
22.9
22.2
21.8
21.4
21.9
22.5
23.1
40.0
40.0
40.0
40.0
40.0
40.0
2.2
2.2
2.2
2.2
2.2
2.2
22.9
22.9
22.9
22.9
22.9
22.9
13.5
15.8
15.7
16.2
16.6
17.1
22.9
22.9
22.9
22.9
22.9
22.9
22.0
21.7
21.3
21.9
22.4
23.0
34.8
34.8
34.8
34.8
34.8
34.8
70.6
74.4
75.1
77.8
80.3
82.9
71.2
70.4
73.2
75.3
77.6
79.8
105.6
105.6
105.6
105.6
105.6
105.6
130.6
130.6
130.6
130.6
130.6
130.6
41.9
45.9
46.5
48.4
50.5
52.5
49.0
48.6
51.9
53.5
55.3
56.9
83.6
83.6
83.6
83.6
83.6
83.6
115.6
115.6
115.6
115.6
115.6
115.6
44.1
45.7
46.0
47.4
48.8
50.2
41.5
40.9
42.0
43.1
44.4
45.5
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
12.0
12.1
12.1
12.5
12.8
13.2
15.8
15.5
15.5
16.1
16.6
17.2
30.3
30.3
30.3
30.3
30.3
30.3
46.9
46.9
46.9
46.9
46.9
46.9
41.7
45.6
46.2
48.1
50.1
52.1
48.7
48.4
51.6
53.3
55.0
56.6
83.6
83.6
83.6
83.6
83.6
83.6
115.6
115.6
115.6
115.6
115.6
115.6
70.8
74.9
75.6
78.3
80.9
83.5
71.5
70.8
73.6
75.8
78.1
80.3
105.6
105.6
105.6
105.6
105.6
105.6
114.3
114.3
114.3
114.3
114.3
114.3
47.6
43.9
44.0
44.8
45.9
46.8
44.2
43.0
38.3
38.8
39.4
39.9
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
47.9
44.3
44.3
45.5
46.3
47.3
44.4
43.2
38.5
39.0
39.6
40.1
105.6
105.6
105.6
105.6
105.6
105.6
114.3
114.3
114.3
114.3
114.3
114.3
27.2
25.3
25.1
25.3
25.5
25.7
26.2
25.3
23.1
23.3
23.5
23.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
41.9
45.9
46.7
48.7
50.5
52.5
49.3
49.0
52.1
53.7
55.5
57.2
63.5
63.5
63.5
63.5
63.5
63.5
69.1
69.1
69.1
69.1
69.1
69.1
9.9
14.3
14.5
15.0
15.5
15.9
11.6
11.4
15.6
15.9
16.2
16.6
70.9
70.9
70.9
70.9
70.9
70.9
80.6
80.6
80.6
80.6
80.6
80.6
9.8
14.3
14.5
15.0
15.4
15.9
-
11.5
15.5
16.0
16.2
16.5
70.9
70.9
70.9
70.9
70.9
70.9
-
91.4
91.4
91.4
91.4
91.4
38.4
38.1
38.0
38.8
39.6
40.4
45.6
45.1
44.6
46.1
47.6
49.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
38.2
38.0
37.8
38.7
39.3
40.1
45.3
44.8
44.5
45.8
47.5
48.9
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
114.3
47.6
47.4
48.3
48.2
47.8
47.6
40.4
39.0
38.7
39.0
39.2
39.4
275.0
275.0
275.0
275.0
275.0
275.0
340.4
340.4
340.4
340.4
340.4
340.4
47.6
47.4
48.5
48.2
48.0
47.6
40.4
39.0
38.7
39.0
39.2
39.4
275.0
275.0
275.0
275.0
275.0
275.0
338.1
338.1
338.1
338.1
338.1
338.1
Distribution and Transmission Annual Planning Report December 2013
42
3.8.3
STS and ZS load forecast
Lower Central Coast Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Gosford 132/33kV STS
Gosford 132/66kV STS
Ourimbah 132/33kV STS
Ourimbah 132/66kV STS
Avoca 66/11kV ZS
Berkeley Vale 132/11kV ZS
Empire Bay 66/11kV ZS
Erina 66/11kV ZS
Lisarow 33/11kV ZS
Long Jetty 66/11kV ZS
Peats Ridge 33/11kV ZS
Somersby 132/11kV ZS
Umina 66/11kV ZS
Wamberal 132/11kV ZS
Wamberal 66/11kV ZS
West Gosford 132/11kV ZS
Woy Woy 66/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
71.0
350.0
21.7
216.1
100.3
117.6
76.0
81.1
61.0
114.3
29.2
104.5
96.7
72.5
130.0
62.0
78.0
350.0
22.3
216.1
101.6
117.6
76.0
83.4
61.1
114.3
29.2
112.3
98.9
75.0
130.0
68.0
0.0
240.0
21.7
108.0
55.7
59.9
38.0
49.3
30.5
71.7
15.2
51.9
58.8
34.4
65.0
30.8
0.0
240.0
22.3
108.0
57.0
63.3
38.0
49.3
30.5
76.2
15.2
56.1
61.0
36.9
65.0
32.7
0.0
240.0
21.7
108.0
62.2
67.0
44.2
54.8
30.5
77.2
18.3
53.7
70.6
35.1
72.3
36.9
0.0
240.0
22.3
108.0
68.4
75.9
45.6
59.1
30.5
91.5
17.0
65.8
70.2
43.6
78.0
39.2
2.9
2.9
2.9
2.9
2.9
11.2
2.9
13.8
2.9
2.9
2.9
13.8
2.9
2.9
13.8
2.9
3.5
5.0
5.0
3.5
3.5
5.0
3.5
5.0
3.5
3.5
5.0
5.0
3.5
3.5
5.0
3.5
2.48
1.39
0.43
1.01
1.36
2.10
0.40
0.88
1.63
1.14
1.78
1.31
1.06
0.13
1.06
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
SUMMER - Lower Central Coast Area STS and ZS Load Forecast
Substation
Gosford 132/33kV STS
Gosford 132/66kV STS
Ourimbah 132/33kV STS
Ourimbah 132/66kV STS
Avoca 66/11kV ZS
Berkeley Vale 132/11kV ZS
Berkeley Vale 33/11kV ZS
Empire Bay 66/11kV ZS
Erina 66/11kV ZS
Lisarow 33/11kV ZS
Long Jetty 33/11kV ZS
Long Jetty 66/11kV ZS
Peats Ridge 33/11kV ZS
Somersby 132/11kV ZS
Umina 66/11kV ZS
Wamberal 132/11kV ZS
Wamberal 66/11kV ZS
West Gosford 132/11kV ZS
Woy Woy 66/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
26.0
25.5
26.9
21.7
29.0
25.0
25.2
25.4
26.2
26.9
27.6
0.90
0.90
0.90
0.90
0.92
0.88
0.88
0.88
0.88
0.88
0.88
138.6
153.3
164.6
115.8
146.2
126.3
126.8
127.3
131.3
134.9
138.9
0.96
0.92
0.95
0.93
0.92
1.00
1.00
0.99
0.99
0.99
0.99
87.9
69.2
70.7
12.9
15.1
15.8
17.5
17.4
17.7
18.0
18.3
0.99
0.95
0.94
0.90
0.93
0.93
0.93
0.93
0.93
0.93
0.93
45.7
61.3
51.5
51.3
51.1
52.0
52.8
53.6
0.90
0.85
0.78
0.78
0.78
0.78
0.78
0.78
45.7
42.2
46.2
33.0
41.9
33.7
33.2
33.7
35.1
36.5
37.9
0.96
0.92
0.95
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
45.4
48.3
42.9
46.1
41.2
40.9
41.7
41.6
41.4
41.2
0.91
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
45.7
0.99
9.7
14.0
14.1
14.6
15.0
15.4
0.92
0.92
0.92
0.92
0.92
0.92
42.4
39.2
40.1
32.2
34.2
30.7
30.6
30.5
31.2
31.8
32.5
0.96
0.92
0.94
0.94
0.94
0.99
0.99
0.99
0.99
0.99
0.99
23.3
24.5
26.1
20.4
27.2
23.1
23.3
23.5
24.3
24.9
25.5
0.99
0.95
0.97
0.97
0.98
1.00
1.00
1.00
1.00
1.00
1.00
48.2
45.6
43.6
0.99
0.81
0.93
33.3
45.3
35.3
35.2
35.0
35.7
36.3
37.0
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
12.0
12.2
12.9
11.0
10.6
12.7
14.6
14.5
14.8
15.1
15.4
0.99
0.95
0.96
0.96
0.97
0.97
0.96
0.96
0.96
0.96
0.96
19.8
19.2
19.2
16.7
17.2
18.7
17.1
16.6
16.5
16.3
16.2
0.91
0.91
0.89
0.89
0.93
0.93
0.93
0.93
0.93
0.93
0.93
35.8
32.8
35.8
27.0
34.8
27.8
26.1
25.7
26.0
26.2
26.5
0.96
0.92
0.92
0.92
0.88
0.88
0.88
0.88
0.88
0.88
0.88
6.9
14.5
11.6
11.6
11.7
12.0
12.3
12.7
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
7.0
8.2
7.6
0.45
0.90
0.90
58.1
56.7
60.1
48.5
51.2
53.8
52.1
50.5
50.3
49.8
49.5
0.92
0.92
0.90
0.91
0.90
0.88
0.88
0.88
0.88
0.88
0.88
31.6
27.6
29.1
23.3
31.1
19.3
17.7
17.9
18.7
19.3
20.1
0.96
0.92
0.92
0.91
0.92
0.92
0.92
0.92
0.92
0.92
0.92
Distribution and Transmission Annual Planning Report December 2013
43
WINTER - Lower Central Coast Area STS and ZS Load Forecast
Substation
Gosford 132/33kV STS
Gosford 132/66kV STS
Ourimbah 132/33kV STS
Ourimbah 132/66kV STS
Avoca 66/11kV ZS
Berkeley Vale 132/11kV ZS
Berkeley Vale 33/11kV ZS
Empire Bay 66/11kV ZS
Erina 66/11kV ZS
Lisarow 33/11kV ZS
Long Jetty 33/11kV ZS
Long Jetty 66/11kV ZS
Peats Ridge 33/11kV ZS
Somersby 132/11kV ZS
Umina 66/11kV ZS
Wamberal 132/11kV ZS
Wamberal 66/11kV ZS
West Gosford 132/11kV ZS
Woy Woy 66/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
23.9
0.90
152.5
0.96
110.0
0.98
49.3
0.96
41.7
0.98
37.7
0.96
26.6
0.98
53.2
0.98
9.7
0.98
18.1
0.93
34.5
0.96
48.3
0.99
30.5
0.96
Actual Load
2009
2010
2011
24.5
24.1
20.5
0.90
0.90
0.90
135.5
144.6
134.4
0.99
0.99
0.98
69.0
69.5
11.6
0.99
0.98
0.90
56.2
0.99
43.9
43.6
41.2
0.99
0.98
0.98
34.8
34.3
34.2
0.95
0.90
0.90
35.4
31.5
28.8
0.99
0.97
0.97
24.8
25.9
23.3
0.99
0.98
0.98
47.5
44.2
0.99
0.98
42.6
0.90
10.5
11.1
10.4
0.99
0.90
0.90
17.4
17.7
16.9
0.94
0.93
0.91
30.2
31.2
27.8
0.99
0.96
0.96
0.0
10.5
0.94
0.90
10.4
9.9
0.90
0.90
44.6
44.3
42.1
0.99
0.97
0.96
28.5
27.4
27.8
0.99
0.97
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
20.5
0.98
116.1
0.98
13.4
0.97
51.9
0.84
43.9
1.00
34.0
0.90
25.1
0.97
20.9
0.97
38.5
0.90
9.3
0.92
16.3
0.93
26.1
0.93
14.1
0.90
38.7
0.97
26.7
0.98
2013
21.0
0.98
116.4
1.00
14.0
0.97
54.4
0.86
39.7
1.00
35.3
0.90
11.5
0.99
23.0
0.99
21.5
1.00
41.4
0.90
10.4
0.92
19.6
0.93
27.5
0.93
15.0
0.90
41.6
1.00
18.2
0.98
Forecast Load
2014
2017
20.7
21.4
0.98
0.98
114.5
118.0
1.00
1.00
15.6
16.4
0.97
0.97
54.0
56.3
0.86
0.86
39.5
41.2
1.00
1.00
34.3
34.5
0.90
0.90
11.3
15.9
0.99
0.98
22.6
23.1
0.99
0.99
21.2
21.9
1.00
1.00
41.1
43.1
0.90
0.90
12.4
13.0
0.92
0.92
18.3
18.9
0.93
0.93
26.7
24.8
0.93
0.93
14.9
15.8
0.90
0.90
42.1
41.6
1.00
1.00
17.8
16.2
0.98
0.98
2018
21.9
0.98
120.5
1.00
16.9
0.97
57.6
0.86
42.6
1.00
34.8
0.90
16.2
0.98
23.6
0.99
22.3
1.00
44.3
0.90
13.4
0.92
19.3
0.93
25.0
0.93
16.3
0.90
41.9
1.00
16.4
0.98
44
3.9
3.9.1
Lower North Shore Load Area
Description of Lower North Shore area
The Lower North Shore load area extends from Chatswood and Castle Cove in the north to North Sydney in the
south, and east to Mosman.
The Lower North Shore area has many gas pressure and oil-filled cables, both of which are obsolete technology.
These cables require specialist skills to repair and maintain, outage times can be lengthy, and spares are not
readily available.
The network in the Lower North Shore area:

is supplied from TransGrid’s transmission system at Sydney East via four 132kV feeders to Lindfield switching
station

includes Castle Cove, Mosman and RNSH 132/11kV zone substations and Willoughby sub-transmission
substation, which are supplied at 132kV from Lindfield switching station

includes 33/11kV zone substations at Crows Nest, Chatswood, Gore Hill and North Sydney, which are supplied
radially at 33kV from Willoughby sub-transmission substation

supplies high rise commercial load in Chatswood and North Sydney

predominantly serves residential and commercial load, and

includes the 33kV supplies to two major customers, the Lane Cove Tunnel and Sydney Trains.
Figure 12: Lower North Shore Load Area
Table 10 – Identified system limitations in Lower North Shore load area
Location
1.
Nil
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
Refer to
DAPR section
Nil
-
45
3.9.2
Sub-transmission feeder load forecast
Lower North Shore Area - Feeder Load Forecast
Feeder name
Feeder 925/1
series reactor
Feeder 925/1
(Sydney East BSP to
Lindfield STSS)
Feeder 925/2
(Lindfiels STSS to
Willoughby T4)
Feeder 925/3
(Lindfield STSS to
Castle Cove ZS)
Feeder 925/4
(Castle Cove ZS to
Mosman ZS)
Feeder 9E3(1)
(Sydney East BSP to
Lindfield STSS)
Feeder 9E3(2)
(Lindfield STSS to
WilloughbyT3)
Feeder 9E4/1
(Sydney East BSP to
Lindfield STSS)
Feeder 9E4/2
(Lindfield STSS to
Willoughby T1)
Feeder 9E4/3
(Lindfield STSS to
Castle Cove ZS)
Feeder 9E4/4
(Castle Cove ZS to
Mosman ZS)
Feeder 9E5
series reactor
Feeder 9E5(1)
(Sydney East BSP to
Lindfield STSS)
Feeder 9E5(2)
(Lindfield STSS to
Willoughby T2)
Feeder 9H1
(Willoughby STS to
RNSH ZS T1)
Feeder 9H2
(Willoughby STS to
RNSH ZS T2)
Feeder 9H3
(Willoughby STS to
Crows Nest ZS)
Feeder 9H5
(Willoughby STS to
Crows Nest ZS)
Feeder 9P3
(Crows Nest ZS to North
Sydney ZS)
Feeder 9P5
(Crows Nest ZS to North
Sydney ZS)
Feeder 551
(Willoughby STS to
Chatswood ZS ZS T2)
Feeder 552
(Willoughby STS to
Chatswood ZS T1)
Feeder 554
(Willoughby STS to
Chatswood ZS T3)
Feeder 556
(Willoughby STS to
North Sydney ZS T5)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
181.8
158.9
158.5
161.8
165.5
168.4
180.7
169.8
144.9
148.8
150.9
153.0
240.1
240.1
240.1
240.1
240.1
240.1
240.1
240.1
240.1
240.1
240.1
240.1
179.7
157.7
157.1
160.3
163.8
166.5
177.9
167.5
143.6
147.1
149.1
151.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
285.0
67.0
47.7
48.6
49.5
47.6
48.4
66.8
55.7
34.4
40.5
41.0
41.7
234.0
259.0
259.0
259.0
259.0
259.0
234.0
234.0
234.0
259.0
259.0
259.0
129.6
132.3
130.8
133.3
136.7
139.7
129.3
129.0
124.6
126.1
127.6
129.5
165.5
165.5
177.0
177.0
177.0
177.0
175.6
175.6
175.6
177.0
177.0
177.0
63.4
63.7
64.3
66.5
69.4
72.3
78.1
75.4
73.0
73.7
74.5
75.4
165.5
165.5
165.5
165.5
165.5
165.5
175.6
175.6
175.6
175.6
175.6
175.6
83.0
120.3
131.2
146.2
147.1
147.0
77.1
67.3
106.3
119.6
121.0
122.5
226.0
226.0
226.0
226.0
226.0
226.0
254.0
254.0
254.0
254.0
254.0
254.0
88.8
124.1
155.9
177.3
176.0
176.5
83.4
72.7
109.5
140.3
141.3
142.4
140.6
140.6
260.0
260.0
260.0
260.0
149.3
149.3
149.3
260.0
260.0
260.0
186.6
166.4
165.5
169.3
174.6
176.9
185.5
177.0
151.9
157.9
160.9
163.9
286.0
286.0
286.0
286.0
286.0
286.0
286.0
286.0
286.0
286.0
286.0
286.0
70.9
48.3
47.2
49.4
52.3
51.6
73.8
65.6
45.1
45.8
47.6
49.4
160.3
160.3
260.0
260.0
260.0
260.0
170.1
170.1
170.1
260.0
260.0
260.0
129.4
132.1
130.4
133.1
136.6
139.5
128.8
128.8
124.0
125.8
127.5
129.1
165.5
165.5
177.0
177.0
177.0
177.0
175.6
175.6
175.6
177.0
177.0
177.0
63.5
63.9
64.2
66.8
69.7
72.3
78.5
75.7
73.1
73.7
74.5
75.5
165.5
165.5
165.5
165.5
165.5
165.5
175.6
175.6
175.6
175.6
175.6
175.6
90.3
126.4
143.4
163.9
163.2
163.8
78.5
69.2
110.0
128.9
130.0
131.3
240.0
240.0
240.0
240.0
240.0
240.0
240.0
240.0
240.0
240.0
240.0
240.0
76.4
124.9
141.2
160.7
160.1
160.7
71.6
62.6
109.2
127.5
128.5
129.8
226.0
285.0
285.0
285.0
285.0
285.0
254.0
254.0
285.0
285.0
285.0
285.0
93.6
128.1
144.6
164.0
163.4
163.9
75.7
66.3
111.9
130.7
131.7
132.8
259.0
259.0
259.0
259.0
259.0
259.0
234.0
234.0
259.0
259.0
259.0
259.0
18.1
18.1
18.1
17.9
18.1
18.1
6.3
11.0
11.0
11.0
11.0
11.0
166.0
166.0
166.0
166.0
166.0
166.0
174.0
174.0
174.0
174.0
174.0
174.0
17.8
18.2
18.2
17.9
18.2
18.1
6.3
11.0
11.0
11.0
11.0
11.0
166.0
166.0
166.0
166.0
166.0
166.0
174.0
174.0
174.0
174.0
174.0
174.0
-
84.6
104.0
127.2
127.3
127.0
-
-
78.7
99.0
99.9
100.9
-
272.0
272.0
272.0
272.0
272.0
-
-
280.0
280.0
280.0
280.0
-
85.0
104.5
127.4
127.7
127.7
-
-
78.8
99.3
100.2
101.3
-
272.0
272.0
272.0
272.0
272.0
-
-
280.0
280.0
280.0
280.0
-
85.9
94.5
105.6
105.7
105.2
-
-
70.5
80.9
81.6
82.5
-
272.0
272.0
272.0
272.0
272.0
-
-
280.0
280.0
280.0
280.0
-
86.3
94.9
105.9
106.0
105.7
-
-
70.6
81.2
81.8
82.7
-
272.0
272.0
272.0
272.0
272.0
-
-
280.0
280.0
280.0
280.0
24.0
23.8
23.1
23.4
24.0
24.1
21.8
22.0
21.3
21.5
21.7
21.9
58.1
58.1
58.1
58.1
58.1
58.1
61.6
61.6
61.6
61.6
61.6
61.6
24.0
23.5
23.1
23.4
23.8
24.0
22.2
22.1
21.4
21.6
21.8
22.0
58.0
58.0
58.0
58.0
58.0
58.0
61.6
61.6
61.6
61.6
61.6
61.6
24.0
23.5
23.1
23.4
23.8
24.0
22.2
22.1
21.4
21.6
22.0
22.0
34.5
34.5
34.5
34.5
34.5
34.5
38.2
38.2
38.2
38.2
38.2
38.2
9.9
-
-
-
-
-
15.7
7.3
-
-
-
-
30.5
-
-
-
-
-
30.5
30.5
-
-
-
-
Distribution and Transmission Annual Planning Report December 2013
46
Lower North Shore Area - Feeder Load Forecast
Summer (MVA)
Feeder name
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder 557
Load
4.9
(Willoughby STS to
North Sydney ZS T1)
33 Rating
29.8
Feeder 558
Load
4.9
(Willoughby STS to
North Sydney ZS T1)
33 Rating
28.3
Feeder 562
Load
0.4
(Willoughby STS to
Crows Nest ZS T1)
33 Rating
19.5
Feeder 563
Load
14.9
(Willoughby STS to
Crows Nest ZS T4)
33 Rating
20.2
Feeder 564
Load
14.9
(Willoughby STS to
20.2
Crows Nest ZS T3)
33 Rating
Feeder 565
Load
14.9
(Willoughby STS to
Crows Nest ZS T2)
33 Rating
17.4
Feeder 566
Load
9.9
(Willoughby STS to
27.8
North Sydney ZS T2)
33 Rating
Feeder 567
Load
9.9
(Willoughby STS to
27.8
North Sydney ZS T3)
33 Rating
Feeder 568
Load
9.9
(Willoughby STS to
North Sydney ZS T4)
33 Rating
27.8
Feeder 571
Load
21.4
20.7
20.0
20.1
20.0
20.0
(Willoughby STS to Gore
Hill ZS T1)
33 Rating
40.2
40.2
40.2
40.2
40.2
40.2
Feeder 572
Load
21.4
20.8
20.1
20.0
20.0
20.1
(Willoughby STS to Gore
Hill ZS T2)
40.2
40.2
40.2
40.2
40.2
40.2
33 Rating
Feeder 573
Load
21.5
20.8
20.1
20.0
20.1
20.1
(Willoughby STS to Gore
40.2
40.2
40.2
40.2
40.2
40.2
Hill ZS T3)
33 Rating
Feeder 574
Load
21.5
20.8
20.1
20.0
20.1
20.1
(Willoughby STS to Gore
Hill ZS T4)
33 Rating
40.2
40.2
40.2
40.2
40.2
40.2
3.9.3
Winter (MVA)
2015
2016
2013
2014
7.8
3.7
-
-
2017
-
2018
-
29.8
29.8
-
-
-
-
7.8
3.7
-
-
-
-
28.3
28.3
-
-
-
-
0.4
0.4
-
-
-
-
19.5
19.5
-
-
-
-
12.6
13.3
-
-
-
-
20.2
20.2
-
-
-
-
12.9
13.6
-
-
-
-
20.2
20.2
-
-
-
-
12.6
13.3
-
-
-
-
17.4
17.4
-
-
-
-
15.6
7.3
-
-
-
-
27.8
27.8
-
-
-
-
15.6
7.3
-
-
-
-
27.8
27.8
-
-
-
-
15.7
7.3
-
-
-
-
27.8
27.8
-
-
-
-
17.7
17.4
17.0
17.3
17.6
18.0
43.6
43.6
43.6
43.6
43.6
43.6
17.8
17.5
17.1
17.4
17.7
18.0
43.6
43.6
43.6
43.6
43.6
43.6
17.8
17.5
17.1
17.4
17.7
18.0
43.6
43.6
43.6
43.6
43.6
43.6
17.8
17.5
17.1
17.4
17.7
18.1
43.6
43.6
43.6
43.6
43.6
43.6
STS and ZS load forecast
Lower North Shore Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Willoughby 132/33kV STS
Castle Cove 132/11kV ZS
Chatswood 33/11kV ZS
Crows Nest 132/11kV ZS
Crows Nest 33/11kV ZS
Gore Hill 33/11kV ZS
Mosman 132/11kV ZS
North Sydney 132/11kV ZS
North Sydney 33/11kV ZS
RNS Hospital 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
453.2
152.4
121.9
114.3
93.2
151.3
152.4
171.5
152.4
97.3
453.2
152.4
122.1
114.3
94.6
151.3
152.6
171.5
152.7
97.3
313.6
90.7
67.1
57.1
60.0
96.9
82.5
114.3
113.0
53.5
313.6
96.3
70.5
57.1
60.0
96.9
89.1
114.3
119.7
53.5
313.6
100.8
67.1
63.5
60.0
96.9
92.2
127.1
113.0
59.9
313.6
115.5
70.5
57.7
60.0
96.9
92.2
137.2
119.7
64.2
13.8
13.8
11.2
13.8
13.8
11.2
11.2
13.8
13.8
11.2
22.2
5.0
5.0
5.0
5.0
19.1
3.5
19.1
19.1
19.1
1.25
1.31
0.47
0.22
1.22
0.17
0.03
3.50
1.78
3.37
4.00
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
47
SUMMER - Lower North Shore Area STS and ZS Load Forecast
Substation
Willoughby 132/33kV STS
Castle Cove 132/11kV ZS
Chatswood 33/11kV ZS
Crows Nest 132/11kV ZS
Crows Nest 33/11kV ZS
Gore Hill 33/11kV ZS
Mosman 132/11kV ZS
North Sydney 132/11kV ZS
North Sydney 33/11kV ZS
RNS Hospital 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
272.1
296.5
297.6
245.4
249.0
228.9
188.2
163.9
143.6
144.6
145.2
0.95
0.93
0.84
0.90
0.90
0.91
0.91
0.92
0.93
0.93
0.93
75.0
78.0
80.5
65.1
69.9
68.2
70.3
68.5
68.7
69.2
69.4
0.91
0.91
0.92
0.90
0.94
0.98
0.98
0.98
0.98
0.98
0.98
43.9
44.9
47.5
40.3
43.4
46.2
45.4
44.7
45.2
45.9
46.4
0.95
0.93
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
21.4
42.8
43.1
43.3
0.86
0.86
0.86
0.86
43.6
47.5
45.5
37.9
39.4
42.9
42.9
21.4
0.95
0.93
0.86
0.86
0.86
0.86
0.86
0.86
79.2
78.8
83.7
72.7
66.1
64.6
62.7
60.8
60.6
60.7
60.6
0.95
0.93
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
65.2
68.5
74.3
60.0
63.8
67.1
67.5
67.9
70.2
72.9
75.4
0.90
0.90
0.93
0.93
0.99
1.00
1.00
1.00
1.00
1.00
1.00
38.9
75.2
72.8
72.5
72.4
72.1
0.91
0.91
0.91
0.91
0.91
0.91
89.0
88.2
90.1
80.5
78.7
38.9
0.95
0.93
0.89
0.91
0.91
0.91
6.8
12.4
17.9
17.9
17.9
17.9
17.9
17.9
1.00
0.99
0.99
0.99
0.99
0.99
0.99
0.99
WINTER - Lower North Shore Area STS and ZS Load Forecast
Substation
Willoughby 132/33kV STS
Castle Cove 132/11kV ZS
Chatswood 33/11kV ZS
Crows Nest 132/11kV ZS
Crows Nest 33/11kV ZS
Gore Hill 33/11kV ZS
Mosman 132/11kV ZS
North Sydney 132/11kV ZS
North Sydney 33/11kV ZS
RNS Hospital 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
246.2
0.97
72.5
0.92
49.2
0.97
44.5
0.97
69.6
0.97
95.5
0.93
76.2
0.97
-
Actual Load
2009
2010
2011
230.7
236.9
224.1
0.99
0.98
0.90
66.5
66.4
64.0
0.92
0.92
0.92
43.7
44.6
42.4
0.99
0.90
0.89
38.1
41.4
39.4
0.99
0.87
0.87
66.7
68.1
67.6
0.99
0.90
0.90
84.0
85.9
86.8
0.93
0.93
0.92
70.2
68.7
66.4
0.99
0.95
0.95
-
Distribution and Transmission Annual Planning Report December 2013
2012
204.2
0.97
59.1
0.87
42.0
0.90
36.3
0.87
61.0
0.90
79.5
0.93
63.2
0.96
7.3
0.90
2013
221.5
0.97
55.4
0.95
43.9
0.90
37.4
0.87
55.3
0.90
79.5
0.97
61.5
0.96
8.0
0.90
2014
191.4
0.97
57.6
0.95
44.1
0.90
39.5
0.87
54.3
0.90
77.2
0.97
29.4
0.96
29.4
0.96
13.6
0.90
Forecast Load
2015
2016
141.7
125.1
0.98
0.98
55.9
56.4
0.95
0.95
42.7
43.0
0.90
0.90
19.1
38.4
0.87
0.87
19.2
0.87
53.1
54.0
0.90
0.90
74.9
75.5
0.97
0.97
57.0
57.4
0.96
0.96
13.6
13.6
0.90
0.90
2017
126.5
0.98
57.1
0.95
43.4
0.90
38.8
0.87
55.0
0.90
76.2
0.97
57.9
0.96
13.6
0.90
2018
128.1
0.98
57.8
0.95
43.8
0.90
39.1
0.87
56.0
0.90
77.1
0.97
58.4
0.96
13.6
0.90
48
3.10
Maitland Load Area
3.10.1 Description of Maitland area
The Maitland network area extends in the north from Luskintyre and Woodville and south to Heddon Greta and
Black Hill. The area is traversed from west to east by the Hunter River. The associated flood plains create the
northern and eastern boundary along with Hexham Wetlands to the south. The majority of existing urban
development lies along the New England Highway and railway transport corridor which passes from east to west
through the middle portion of the area.
Major residential development is continuing to the east of Maitland and around Thornton, and also to the west,
north of Aberglassyn. The surrounding suburbs and villages contain a mixture of urban and rural development, with
increasing amounts of light to medium industry along the main transport corridor. Intensive agricultural activities are
also prevalent along the Hunter River flood plain.
The network in the Maitland area includes:

Kurri and Beresfield sub-transmission substations (STS) which are supplied via 132kV feeders from
TransGrid’s transmission system at Killingworth

seven zone substations, three supplied from the 33kV network from Kurri STS , and four supplied from the
33kV network from Beresfield STS

two 33kV connected mining customers and a 33kV connection for Hunter Water supply at Tarro

33kV feeder interconnections to the Tomago and Waratah 33kV networks via Tarro zone substation, and

provides the main 33kV supply to the Essential Energy network supplying Martin’s Creek and Gresford.
Figure 13: Maitland Load Area
Table 11 – Identified system limitations in Maitland load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Tarro 33/11kV zone substation
Capacity
5.3.14
2.
Telarah 33/11kV zone substation
Capacity
5.3.14
3.
Telarah 33/11kV zone substation
Asset Condition
5.3.14
Distribution and Transmission Annual Planning Report December 2013
49
3.10.2 Sub-transmission feeder load forecast
Maitland Area - Feeder Load Forecast
Feeder name
Feeder 30012
(Rutherford To Telarah)
Feeder 30025(1)
(Thornton to East
Maitland)
Feeder 30025(2)
(Thornton to East
Maitland)
Feeder 30025
(Thornton to Metford)
Feeder 30028(1)
(East Maitland to
Maitland)
Feeder 30028(2)
(East Maitland to
Maitland)
Feeder 30028
(Metford to Maitland)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder 33854 (Beresfield
STS To Tarro)
33 Rating
Load
Feeder 33859 (Beresfield
STS To Thornton)
33 Rating
Feeder 33874(1)
Load
(Beresfield STS to East
Maitland)
33 Rating
Feeder 33874(2)
Load
(Beresfield STS to East
Maitland)
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
27.4
27.7
28.0
28.6
29.5
29.5
25.9
25.5
25.5
26.4
27.2
28.1
31.2
31.2
31.2
31.2
31.2
31.2
41.4
41.4
41.4
41.4
41.4
41.4
32.1
32.7
-
-
-
-
20.6
20.9
-
-
-
-
45.7
45.7
-
-
-
-
45.7
45.7
-
-
-
-
33.0
33.7
-
-
-
-
20.9
21.3
-
-
-
-
60.0
60.0
-
-
-
-
65.2
65.2
-
-
-
-
-
-
32.6
32.9
33.3
33.8
-
-
22.8
23.2
23.7
24.3
-
-
45.7
45.7
45.7
45.7
-
-
45.7
45.7
45.7
45.7
24.8
24.9
-
-
-
-
13.0
17.4
-
-
-
-
31.2
31.2
-
-
-
-
41.4
41.4
-
-
-
-
24.8
24.9
-
-
-
-
13.0
17.4
-
-
-
-
31.2
31.2
-
-
-
-
41.4
41.4
-
-
-
-
-
-
25.0
25.4
26.0
26.5
0.0
0.0
17.0
17.2
17.4
17.7
-
-
53.0
53.0
53.0
53.0
0.0
0.0
54.0
54.0
54.0
54.0
26.9
27.6
27.9
28.8
30.3
31.3
21.9
19.8
20.1
21.1
22.0
23.1
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
47.3
43.9
41.8
42.3
43.1
44.0
26.2
26.3
24.0
24.8
25.6
26.5
60.0
60.0
60.0
60.0
60.0
60.0
65.2
65.2
65.2
65.2
65.2
65.2
33.5
33.3
-
-
-
-
20.3
20.6
-
-
-
-
60.0
60.0
-
-
-
-
65.2
65.2
-
-
-
-
32.8
32.5
-
-
-
-
19.8
20.2
-
-
-
-
45.7
45.7
-
-
-
-
45.7
45.7
-
-
-
-
Load
Feeder 33874 (Beresfield
STS to Metford)
33 Rating
-
-
31.8
32.0
32.5
33.1
-
-
22.1
22.5
23.0
23.6
-
-
45.7
45.7
45.7
45.7
-
-
45.7
45.7
45.7
45.7
Load
Feeder 33899 (Beresfield
STS To Thornton)
33 Rating
47.0
43.5
41.4
41.9
42.6
43.6
26.0
26.1
23.8
24.5
25.3
26.3
60.0
60.0
60.0
60.0
60.0
60.0
65.2
65.2
65.2
65.2
65.2
65.2
Feeder 33904(1)
(Beresfield STS to Tarro)
Load
33 Rating
Load
Feeder 33904(2)
(Beresfield STS to Tarro)
Feeder KU4(1)
(Kurri STS to tee Telarah
and Maitland)
33 Rating
Feeder KU4(2)
(tee to Telarah)
33 Rating
Feeder KU4(3)
(tee to Maitland)
33 Rating
Feeder KU5
(Kurri STS To Telarah)
Feeder KU8
(Kurri STS To
Rutherford)
Feeder KU13
(Kurri STS To Telarah)
Feeder 34099(1)
(Thornton to Essential
Energy)
Feeder 34099(4)
(tee to Wallalong ZS)
Feeder 34099(3)
(Thornton to Essential
Energy)
Feeder 34099(5)
(Thornton to Essential
Energy)
33 Rating
Load
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
27.3
28.0
28.3
29.2
30.8
31.8
22.2
20.0
20.3
21.4
22.3
23.5
60.0
60.0
60.0
60.0
60.0
60.0
62.2
62.2
62.2
62.2
62.2
62.2
26.7
27.3
27.6
28.5
29.9
30.9
21.8
19.7
20.0
21.0
21.9
23.0
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
31.3
31.8
32.1
33.0
34.0
34.9
22.5
20.0
19.8
20.4
20.9
21.5
41.6
41.6
41.6
41.6
41.6
41.6
56.1
56.1
56.1
56.1
56.1
56.1
11.5
11.9
12.0
12.4
13.0
12.6
10.5
13.2
13.3
13.7
14.0
14.5
31.2
31.2
31.2
31.2
31.2
31.2
41.4
41.4
41.4
41.4
41.4
41.4
24.8
24.9
25.0
25.3
25.9
26.4
0.0
17.0
16.8
17.4
17.4
17.8
53.0
53.0
53.0
53.0
53.0
53.0
0.0
54.0
54.0
54.0
54.0
54.0
14.3
14.6
14.7
15.1
15.7
16.0
10.7
9.3
9.2
9.5
9.8
10.1
18.6
18.6
18.6
18.6
18.6
18.6
24.3
24.3
24.3
24.3
24.3
24.3
31.8
32.2
32.5
33.5
34.6
33.9
28.8
28.8
28.8
28.9
28.4
31.2
36.0
36.0
36.0
36.0
36.0
36.0
44.9
44.9
44.9
44.9
44.9
44.9
23.7
24.0
24.3
25.0
25.9
26.3
18.4
16.5
16.5
16.9
17.4
18.0
26.8
26.8
26.8
26.8
26.8
26.8
35.5
35.5
35.5
35.5
35.5
35.5
10.7
5.9
5.9
5.9
6.0
6.1
5.6
3.1
3.1
3.1
3.2
3.2
60.0
60.0
60.0
60.0
60.0
60.0
65.2
65.2
65.2
65.2
65.2
65.2
4.7
-
-
-
-
-
3.1
-
-
-
-
-
21.0
-
-
-
-
-
27.5
-
-
-
-
-
10.6
5.9
6.5
6.5
6.6
6.7
5.6
3.1
3.4
3.5
3.6
3.6
11.3
11.3
11.3
11.3
11.3
11.3
14.5
14.5
14.5
14.5
14.5
14.5
5.7
5.7
6.2
6.3
6.4
6.5
3.0
3.0
3.4
3.4
3.5
3.6
9.7
9.7
9.7
9.7
9.7
9.7
16.0
16.0
16.0
16.0
16.0
16.0
Distribution and Transmission Annual Planning Report December 2013
50
3.10.3 STS and ZS load forecast
Maitland Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Beresfield 132/33kV STS
Brandy Hill 132/11kV ZS
East Maitland 33/11kV ZS
Maitland 33/11kV ZS
Maitland Central 33/11kV ZS
Metford 33/11kV ZS
Rutherford 33/11kV ZS
Tarro 33/11kV ZS
Telarah 33/11kV ZS
Thornton 33/11kV ZS
Wallalong 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
240.0
37.5
45.7
66.0
38.4
76.0
76.2
45.7
28.9
99.0
5.8
240.0
38.0
45.7
66.0
38.4
76.0
76.2
45.7
30.5
99.0
6.3
142.9
37.5
30.5
38.0
23.8
38.0
38.1
22.9
15.2
72.6
0.0
142.9
37.5
30.5
38.0
23.8
38.0
38.1
22.9
15.2
72.6
0.0
142.9
10.0
34.1
42.5
26.7
42.5
42.6
25.6
18.3
86.1
5.0
142.9
10.0
36.6
45.6
28.6
45.6
45.7
27.4
18.3
86.1
5.5
2.9
11.2
11.2
11.2
11.2
11.2
11.2
11.2
2.9
2.9
2.9
5.0
5.0
5.0
5.0
5.0
5.0
5.0
5.0
3.5
3.5
3.5
0.20
1.55
0.84
1.22
0.86
0.62
2.03
0.32
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
Yes
No
No
No
SUMMER - Maitland Area STS and ZS Load Forecast
Substation
MVA
PF
MVA
Brandy Hill 132/11kV ZS
PF
MVA
East Maitland 33/11kV ZS
PF
MVA
Maitland 33/11kV ZS
PF
MVA
Maitland Central 33/11kV ZS PF
MVA
Metford 33/11kV ZS
PF
MVA
Rutherford 33/11kV ZS
PF
MVA
Tarro 33/11kV ZS
PF
MVA
Telarah 33/11kV ZS
PF
MVA
Thornton 33/11kV ZS
PF
MVA
Wallalong 33/11kV ZS
PF
Beresfield 132/33kV STS
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
113.2
0.91
32.4
0.91
21.7
0.98
24.5
0.98
22.6
0.91
19.3
0.98
36.4
0.91
4.2
0.91
102.4
0.91
31.9
0.91
19.9
1.00
24.1
1.00
22.7
0.91
18.4
1.00
35.5
0.91
4.1
0.91
107.2
0.96
33.0
1.00
22.2
0.90
31.6
0.93
27.4
0.91
16.1
0.94
32.7
0.93
4.9
0.92
96.3
0.94
23.4
1.00
16.3
0.90
23.0
0.99
22.7
0.90
13.2
0.94
24.5
0.93
2.0
0.97
97.7
1.00
31.0
0.99
20.8
0.93
30.0
0.94
24.6
0.91
18.1
0.95
32.2
0.99
4.5
0.90
96.5
1.00
0.9
0.95
32.2
1.00
26.0
0.93
28.7
1.00
24.1
0.91
16.1
0.95
37.0
0.98
4.6
0.90
93.8
1.00
8.7
0.93
32.8
1.00
26.1
0.93
29.0
1.00
24.6
0.91
16.5
0.95
37.0
0.98
-
94.1
1.00
8.8
0.93
26.2
0.93
33.5
0.98
29.2
1.00
25.1
0.91
16.9
0.95
37.0
0.98
-
95.4
1.00
8.9
0.93
26.6
0.93
33.8
0.98
29.9
1.00
25.9
0.91
17.4
0.95
37.4
0.98
-
97.3
1.00
9.1
0.93
27.2
0.93
34.4
0.98
30.7
1.00
26.9
0.91
18.2
0.95
38.1
0.98
-
99.4
1.00
9.3
0.93
27.8
0.93
35.0
0.98
31.6
1.00
28.0
0.91
18.9
0.95
38.9
0.98
-
Actual Load
2010
2011
2012
2013
2014
Forecast Load
2015
2016
2017
2018
79.9
0.93
20.1
0.98
12.0
0.96
21.2
0.99
19.0
0.92
10.1
0.98
21.2
0.96
2.8
0.90
67.2
0.93
1.5
0.97
21.5
1.00
12.6
0.96
23.2
1.00
19.9
0.92
10.7
0.97
19.9
1.00
3.0
0.90
68.6
0.93
2.4
0.97
21.9
1.00
15.8
0.96
23.2
1.00
18.1
0.92
8.0
0.97
22.7
0.99
3.0
0.90
66.9
0.93
10.2
0.94
15.6
0.96
23.8
0.98
23.2
1.00
18.4
0.92
8.0
0.97
22.7
0.99
-
70.8
0.93
10.5
0.94
16.0
0.96
25.1
0.98
24.7
1.00
20.1
0.92
8.5
0.97
24.2
0.99
-
73.1
0.93
10.7
0.94
16.2
0.96
25.9
0.98
25.5
1.00
21.1
0.92
8.8
0.97
25.1
0.99
-
WINTER - Maitland Area STS and ZS Load Forecast
Substation
2008
2009
MVA
Beresfield 132/33kV STS
PF
MVA
Brandy Hill 132/11kV ZS
PF
MVA
East Maitland 33/11kV ZS
PF
MVA
Maitland 33/11kV ZS
PF
MVA
Maitland Central 33/11kV ZS PF
MVA
Metford 33/11kV ZS
PF
MVA
Rutherford 33/11kV ZS
PF
MVA
Tarro 33/11kV ZS
PF
MVA
Telarah 33/11kV ZS
PF
MVA
Thornton 33/11kV ZS
PF
MVA
Wallalong 33/11kV ZS
PF
78.1
0.96
22.0
0.96
14.6
0.99
21.2
0.99
20.7
0.96
15.7
0.99
27.0
0.96
4.0
0.96
83.3
0.91
21.8
0.91
14.3
1.00
17.9
1.00
17.4
0.91
12.5
1.00
25.0
0.91
3.0
0.91
71.1
0.96
21.5
0.99
12.9
0.93
18.1
0.94
20.0
0.93
12.8
0.96
22.5
0.97
2.5
0.97
69.3
0.94
20.2
1.00
12.4
0.97
20.2
0.97
18.5
0.94
9.9
0.98
20.1
0.97
3.1
0.96
Distribution and Transmission Annual Planning Report December 2013
68.9
0.93
10.3
0.94
15.8
0.96
24.5
0.98
23.9
1.00
19.2
0.92
8.2
0.97
23.4
0.99
-
51
3.11
Manly Warringah Load Area
3.11.1 Manly Warringah area
The Manly Warringah area is bordered on three sides by Middle Harbour and the Tasman Sea. It is separated from
the adjoining Terrey Hills and Pittwater area by Narrabeen Lakes and bushland. The network serves both urban
residential and commercial areas, with major industrial demand in Brookvale and Dee Why West, and retail
demand at Warringah Mall.
The area is principally residential. There is substantial high density development along the beachfront forming the
eastern boundary of the area whereas the rest of the area is characterised by detached dwellings. There is a
proposed implementation of Planning NSW strategies including an employment land strategy at Brookvale,
development of commercial centres at Dee Why and Manly, and potential development of a major centre at
Frenchs Forest.
An additional 19,500 jobs and 17,300 dwellings are forecast for the North-East sub-region by 2031. This includes
13,500 new jobs and 12,700 new dwellings in Manly Warringah. New dwellings will mainly take the form of higher
density construction, which will replace existing dwellings.
Jobs growth will arise from development in the Dee Why / Brookvale and Manly area. The establishment of a new
hospital at Forestville (close to Beacon Hill zone substation) is also proposed for the area.
The Manly Warringah network supplies Manly and most of Warringah Shire, and:

is supplied at 33kV from Warringah sub-transmission substation (STS), which is in turn supplied from
TransGrid’s Sydney East bulk supply point by four 132kV circuits

includes eight 33/11kV zone substations and one 132/33/11kV zone substation, and

is supplied by a complex network of 33kV feeders, comprising both overhead lines, which generally cover
inland areas, and underground cables, which generally cover coastal areas.
Figure 14 Manly Warringah Load Area
Distribution and Transmission Annual Planning Report December 2013
52
Table 12 – Identified system limitations in Manly-Warringah load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Feeder S08(3) - S08TEE to Harbord ZS
Asset Condition
5.2.6
2.
Feeder S08(2) - S08TEE to Manly ZS
Asset Condition
5.2.6
3.
Feeder S10 - S10TEE to Kangaroo Park to Manly ZS
Asset Condition
5.2.6
4.
Feeder S10(4) - Kangaroo Park Terminal to North Head ZS
Asset Condition
5.2.6
Distribution and Transmission Annual Planning Report December 2013
53
3.11.2 Sub-transmission feeder load forecast
Manly Warringah Area - Feeder Load Forecast
Feeder name
Feeder 9M5
(Warringah STS to
Balgowlah North ZS)
Feeder 9M4
(Sydney East BSP to
Warringah STS)
Feeder 9M3
(Sydney East BSP to
Warringah STS)
Feeder 9M2
(Sydney East BSP to
Warringah STS)
Feeder S10(1)
(Warringah STS to Tee
Kangaroo Park )
Feeder S10(3)
(Tee Warringah STS to
Kangaroo Park Terminal)
Feeder S10(4)
(Kangaroo Park Terminal
to North Head ZS)
Feeder S10(5)
(Kangaroo Park Terminal
to Manly ZS)
Feeder S18
(Harbord ZS to North
Head ZS)
Feeder S01(4)
(Warringah STS to
Balgowlah North ZS)
Feeder S14
(Warringah STS to
Killarney ZS)
Feeder S02(1)
(Warringah STS to tee
Killarney/Belrose ZS)
Feeder S02(2)
(Tee Warringah
STS/Killarney/Belrose
ZS to Killarney ZS)
Feeder S02(3) (Tee
Warringah STS
/Killarney/Belrose ZS to
Belrose ZS)
Feeder S09
(Warringah STS to
Beacon Hill ZS)
Feeder S12
(Warringah STS to
Beacon Hill ZS)
Feeder S03(1)
(Warringah STS to tee
CP Oxford Falls/Belrose
ZS)
Feeder S03(2)
(Tee
Warringah/CP/Belrose
ZS to Belrose ZS)
Feeder S05(1)
(Warringah STS to Tee
CP/Dee Why West ZS)
Feeder S05(2)
(Tee Warringah
STS/CP/Dee Why West
ZS to Dee Why West
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
22.6
22.7
22.8
23.8
24.8
25.7
34.3
33.8
33.3
34.2
35.1
36.2
198.0
198.0
198.0
198.0
198.0
198.0
208.5
208.5
208.5
208.5
208.5
208.5
105.9
105.8
106.6
109.5
113.3
117.1
127.5
124.7
122.2
124.5
126.8
129.4
503.9
503.9
503.9
503.9
503.9
503.9
503.9
503.9
503.9
503.9
503.9
503.9
105.5
105.4
106.2
109.1
112.9
116.7
127.0
124.3
121.7
124.0
126.3
128.9
454.1
454.1
454.1
454.1
454.1
454.1
454.1
454.1
454.1
454.1
454.1
454.1
74.9
74.9
75.4
77.5
80.2
82.9
89.8
87.8
86.0
87.6
89.3
91.2
102.2
102.2
102.2
102.2
102.2
102.2
179.5
179.5
179.5
179.5
179.5
179.5
23.0
23.0
23.0
23.3
23.8
24.4
29.2
28.5
27.8
28.0
28.3
28.5
51.4
51.4
51.4
51.4
51.4
51.4
62.1
62.1
62.1
62.1
62.1
62.1
22.9
23.0
22.9
23.2
23.8
24.2
28.9
28.2
27.5
27.7
27.9
28.2
37.1
37.1
37.1
37.1
37.1
37.1
42.8
42.8
42.8
42.8
42.8
42.8
9.4
9.4
9.4
9.4
9.4
9.4
13.1
13.1
13.1
13.1
13.1
13.1
22.9
22.9
22.9
22.9
22.9
22.9
24.6
24.6
24.6
24.6
24.6
24.6
17.3
17.2
16.8
16.7
16.9
17.0
20.8
20.2
19.6
19.8
20.0
20.1
53.9
53.9
53.9
53.9
53.9
53.9
57.2
57.2
57.2
57.2
57.2
57.2
9.5
9.5
9.5
9.5
9.5
9.5
13.1
13.1
13.1
13.1
13.1
13.1
26.6
26.6
26.6
26.6
26.6
26.6
28.6
28.6
28.6
28.6
28.6
28.6
21.8
21.9
22.1
22.9
24.0
24.9
33.8
33.3
32.8
33.7
34.6
35.6
37.4
37.4
37.4
37.4
37.4
37.4
50.9
50.9
50.9
50.9
50.9
50.9
11.9
11.8
11.7
12.0
12.3
12.6
13.6
13.2
12.8
12.9
13.0
13.1
25.7
25.7
25.7
25.7
25.7
25.7
34.3
34.3
34.3
34.3
34.3
34.3
26.9
26.7
26.5
27.0
27.7
28.4
31.8
30.9
29.9
30.2
30.4
30.8
51.4
51.4
51.4
51.4
51.4
51.4
57.2
57.2
57.2
57.2
57.2
57.2
11.9
11.8
11.8
12.1
12.3
12.6
13.5
13.1
12.7
12.8
12.9
13.0
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
24.4
24.2
24.0
24.4
25.0
25.7
29.1
28.2
27.4
27.6
27.9
28.2
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
21.6
21.5
21.2
21.7
22.3
22.9
18.7
18.1
17.5
17.7
17.9
18.1
41.0
41.0
41.0
41.0
41.0
41.0
43.2
43.2
43.2
43.2
43.2
43.2
21.6
21.4
21.2
21.7
22.4
22.9
18.7
18.1
17.5
17.7
17.9
18.1
40.5
40.5
40.5
40.5
40.5
40.5
42.6
42.6
42.6
42.6
42.6
42.6
24.5
24.2
23.9
24.5
25.0
25.7
29.2
28.2
27.4
27.6
27.9
28.2
37.4
37.4
37.4
37.4
37.4
37.4
50.9
50.9
50.9
50.9
50.9
50.9
24.5
24.2
24.0
24.5
25.0
25.7
29.1
28.2
27.3
27.6
27.9
28.2
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
37.0
37.5
37.8
39.4
41.3
43.2
47.5
46.7
45.8
47.3
48.4
49.8
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
57.2
36.2
36.6
36.9
38.4
40.1
41.9
46.1
45.3
44.5
45.9
46.9
48.3
68.8
68.8
68.8
68.8
68.8
68.8
71.4
71.4
71.4
71.4
71.4
71.4
Distribution and Transmission Annual Planning Report December 2013
54
Manly Warringah Area - Feeder Load Forecast
Feeder name
Feeder S06
(Warringah STS to Dee
Why West ZS)
Feeder S16
(Warringah STS to
Brookvale ZS)
Feeder S17
(Warringah STS to
Brookvale ZS)
Feeder S07(1)
(Warringah STS to Tee
Brookvale/Harbord ZS)
Feeder S07(3)
(Tee Warringah
STS/Brookvale/Harbord
ZS to Harbord ZS)
Feeder S07(2)
(Tee Warringah
STS/Brrokvale/Harbord
ZS to Brookvale ZS)
Feeder S08(1)
(Warringah STS to Tee
Manly/Harbord ZS)
Feeder S08(3)
(Tee warringah
STS/Manly/Harbord ZS
to Harbord ZS)
Feeder S08(2)
(Tee warringah
STS/Manly/Harbord ZS
to Manly ZS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
37.2
37.6
38.0
39.6
41.4
43.3
47.4
47.0
46.0
47.3
48.6
50.1
56.9
56.9
56.9
56.9
56.9
56.9
62.9
62.9
62.9
62.9
62.9
62.9
19.5
19.3
20.1
20.7
21.4
22.0
15.5
15.4
15.3
15.8
16.2
16.9
36.3
36.3
36.3
36.3
36.3
36.3
38.3
38.3
38.3
38.3
38.3
38.3
22.0
21.8
22.7
23.3
24.0
24.7
17.8
17.7
17.6
18.1
18.6
19.3
36.3
36.3
36.3
36.3
36.3
36.3
38.3
38.3
38.3
38.3
38.3
38.3
31.8
31.8
32.2
33.0
33.8
34.7
37.3
36.5
35.8
36.2
36.7
37.2
64.5
64.5
64.5
64.5
64.5
64.5
71.4
71.4
71.4
71.4
71.4
71.4
20.7
20.8
20.7
21.1
21.5
22.0
29.4
28.6
27.9
28.0
28.1
28.3
47.6
47.6
47.6
47.6
47.6
47.6
55.0
55.0
55.0
55.0
55.0
55.0
17.7
17.5
18.2
18.7
19.4
19.9
14.1
14.1
14.0
14.4
14.8
15.3
43.3
43.3
43.3
43.3
43.3
43.3
46.0
46.0
46.0
46.0
46.0
46.0
22.9
22.9
23.0
23.5
24.0
24.6
28.8
28.1
27.5
27.7
28.0
28.3
39.8
39.8
39.8
39.8
39.8
39.8
54.3
54.3
54.3
54.3
54.3
54.3
17.1
17.3
17.5
18.1
18.9
19.6
24.0
23.4
22.8
23.0
23.1
23.3
47.2
47.2
47.2
47.2
47.2
47.2
52.3
52.3
52.3
52.3
52.3
52.3
17.3
17.0
16.8
16.9
17.0
17.1
20.9
20.3
19.6
19.8
20.0
20.2
42.1
42.1
42.1
42.1
42.1
42.1
46.8
46.8
46.8
46.8
46.8
46.8
3.11.3 STS and ZS load forecast
Manly Warringah Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Warringah 132/33kV STS
Balgowlah North 132/11kV ZS
Beacon Hill 33/11kV ZS
Belrose 33/11kV ZS
Brookvale 33/11kV ZS
Dee Why West 33/11kV ZS
Harbord 33/11kV ZS
Killarney 33/11kV ZS
Manly 33/11kV ZS
North Head 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
273.7
53.2
54.1
67.7
87.6
79.4
73.7
43.6
47.6
43.0
301.1
53.2
54.1
67.7
87.6
87.3
75.1
43.7
52.0
43.0
217.4
37.9
26.7
43.0
54.3
53.5
37.3
21.1
23.2
23.4
229.8
37.9
26.7
44.8
54.3
58.8
37.5
21.1
25.4
23.6
217.4
41.1
26.7
51.6
54.3
53.5
44.7
21.1
25.2
23.4
229.8
45.5
26.7
52.4
54.3
58.8
44.5
21.1
29.3
23.6
11.2
2.9
13.8
2.9
13.8
11.2
2.9
2.9
11.2
8.6
5.0
3.5
5.0
3.5
19.1
3.5
3.5
3.5
5.0
3.5
1.22
0.75
1.45
0.46
1.59
1.15
0.80
0.23
0.07
3.80
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
55
SUMMER - Manly Warringah Area STS and ZS Load Forecast
Substation
Warringah 132/33kV STS
Balgowlah 33/11kV ZS
Balgowlah North 132/11kV ZS
Beacon Hill 33/11kV ZS
Belrose 33/11kV ZS
Brookvale 33/11kV ZS
Dee Why West 33/11kV ZS
Harbord 33/11kV ZS
Killarney 33/11kV ZS
Manly 33/11kV ZS
North Head 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
176.3
197.0
210.3
150.0
161.6
158.9
158.7
160.1
164.2
169.0
173.4
0.95
0.95
0.98
0.98
0.98
1.00
1.00
1.00
1.00
1.00
1.00
18.6
22.6
23.1
0.95
0.95
0.97
24.8
29.7
28.0
28.2
28.4
29.4
30.5
31.6
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
24.6
24.5
25.6
23.8
24.6
21.4
21.2
21.0
21.5
22.0
22.5
0.95
0.95
0.87
0.87
0.87
0.97
0.97
0.97
0.97
0.96
0.96
23.8
25.7
26.8
21.1
27.2
26.8
26.5
26.3
26.8
27.4
28.0
0.95
0.95
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
0.91
47.3
45.1
49.6
44.4
43.9
45.7
45.3
46.9
48.1
49.4
50.7
0.95
0.95
0.94
0.95
0.87
0.88
0.88
0.87
0.87
0.87
0.87
32.1
38.1
39.2
31.4
37.7
36.4
36.8
37.1
38.5
40.1
41.6
0.95
0.95
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
27.0
27.3
28.2
24.3
18.3
18.9
19.2
19.5
20.4
21.4
22.4
0.95
0.95
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
16.6
17.2
17.6
13.2
14.3
12.8
12.7
12.6
12.9
13.3
13.5
0.95
0.95
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
18.6
18.8
18.7
16.6
17.6
17.8
17.4
17.0
17.2
17.4
17.5
0.95
0.95
0.91
0.90
0.91
0.91
0.91
0.91
0.91
0.91
0.91
21.6
21.7
20.6
21.4
20.3
20.9
20.9
20.9
20.9
20.9
20.9
0.95
0.95
0.92
0.91
0.92
0.92
0.92
0.92
0.92
0.92
0.92
WINTER - Manly Warringah Area STS and ZS Load Forecast
Substation
Warringah 132/33kV STS
Balgowlah 33/11kV ZS
Balgowlah North 132/11kV ZS
Beacon Hill 33/11kV ZS
Belrose 33/11kV ZS
Brookvale 33/11kV ZS
Dee Why West 33/11kV ZS
Harbord 33/11kV ZS
Killarney 33/11kV ZS
Manly 33/11kV ZS
North Head 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
2009
247.2
0.99
29.0
0.99
23.7
0.99
28.7
0.99
42.0
0.99
49.0
0.99
41.8
0.99
20.2
0.99
25.0
0.99
23.1
0.99
229.7
1.00
26.3
1.00
22.2
1.00
25.9
1.00
40.5
1.00
50.6
1.00
37.5
1.00
17.5
1.00
23.0
1.00
23.6
1.00
Actual Load
2010
2011
230.2
1.00
27.0
0.90
23.3
0.93
26.3
0.90
39.5
0.94
51.8
0.97
37.6
0.96
17.9
0.96
23.1
0.95
21.9
0.86
218.9
1.00
30.3
0.94
20.8
0.93
24.3
0.94
39.4
0.98
47.2
0.97
35.4
0.96
16.6
0.96
21.6
0.95
23.4
0.86
Distribution and Transmission Annual Planning Report December 2013
2012
2013
2014
Forecast Load
2015
2016
2017
2018
171.1
0.99
32.1
0.98
21.6
0.93
23.6
0.94
36.8
0.98
41.5
0.98
22.1
0.96
14.8
0.96
20.8
0.95
21.2
0.87
172.1
1.00
34.2
0.98
20.0
1.00
28.6
0.94
38.5
0.98
44.7
0.98
23.8
0.96
13.4
0.96
21.1
0.95
21.7
0.87
168.8
1.00
33.7
0.98
19.4
1.00
27.7
0.94
38.3
0.98
44.2
0.98
23.1
0.96
13.0
0.96
20.4
0.95
21.7
0.87
167.3
0.99
33.3
0.98
18.9
1.00
26.9
0.94
38.0
0.98
43.6
0.98
22.3
0.96
12.6
0.96
19.8
0.95
21.7
0.87
171.2
1.00
34.9
0.98
19.2
1.00
27.4
0.94
40.6
0.98
45.7
0.98
22.7
0.96
12.8
0.96
20.2
0.95
21.7
0.87
174.4
1.00
35.9
0.98
19.4
1.00
27.7
0.94
42.1
0.98
46.9
0.98
22.9
0.96
12.9
0.96
20.4
0.95
21.7
0.87
170.0
0.99
34.1
0.98
19.0
1.00
27.1
0.94
39.3
0.98
44.6
0.98
22.5
0.96
12.7
0.96
20.0
0.95
21.7
0.87
56
3.12
Newcastle Inner City Load Area
3.12.1 Newcastle Inner City area
The Newcastle Inner City network area lies on the eastern seaboard of Newcastle. It is bounded by the Hunter
River to the north and Glenrock State recreation area to the south and extends west to New Lambton. The area
includes the principal CBD precinct for Newcastle, comprising a mixture of commercial and high density residential
load. The surrounding suburbs contain a mixture of residential, commercial and industrial areas. Newcastle Harbour
and the Hunter River, which form the northern boundary of the Newcastle Inner City area include the Honeysuckle
development precinct along the foreshore and also contain several larger industrial 11kV customers including Port
Waratah coal loading facility and State Dockyards at Carrington.
The network in the Newcastle Inner City area:

is predominantly supplied at 33kV from Merewether sub-transmission substation (STS)

is traversed by two 132kV feeders (960 & 961) which supply Merewether STS from TransGrid’s transmission
system at Killingworth and a 132kV oil-filled cable, (9N9) which provides an alternative 132kV supply to
Merewether STS from Waratah STS

comprises six zone substations of which five are currently supplied from the 33kV network originating from
Merewether STS and one is supplied from the 132kV network

consists of around 36km of 33kV oil-filled cables and 15km of overhead 33kV feeders, and

includes an underground 11kV triplex network supplying the Newcastle CBD area.
Figure 15: Newcastle Inner City Load Area
Distribution and Transmission Annual Planning Report December 2013
57
Table 13 – Identified system limitations in Newcastle Inner City load area
Location
Identified Limitation
Refer to
DAPR section
1.
Kotara 33/11kV zone substation
Asset Condition
5.3.15
2.
Feeder 773 - Merewether to Kotara
Asset Condition
5.2.9
3.
Feeder 775 - Merewether to Kotara
Asset Condition
5.2.9
4.
Feeder 775 - Merewether to Kotara
Asset Condition
5.2.9
3.12.2 Sub-transmission feeder load forecast
Newcastle Inner City Area - Feeder Load Forecast
Feeder name
Feeder 3060(2)
(Broadmeadow to New
Lambton)
Feeder 3061(2)
(Broadmeadow to New
Lambton)
Feeder 762 (Merewether
STS to Broadmeadow)
Feeder 762 (Merewether
STS to New Lambton)
Feeder 3809 (Carrington
to Newcastle CBD)
Feeder H763
(Merewether STS to
Carrington)
Feeder H763
(Merewether STS to
Tighes Hill)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Feeder H764
(Merewether STS to
Newcastle CBD)
33 Rating
Feeder H768
(Merewether STS to
Broadmeadow)
33 Rating
Load
Load
Feeder H768
Load
(Merewether STS to New
Lambton)
33 Rating
Feeder H769
(Merewether STS to
Carrington)
Feeder H769
(Merewether STS to
Tighes Hill)
Load
33 Rating
Load
33 Rating
Feeder H770
(Merewether STS to
Newcastle CBD)
33 Rating
Feeder H773
(Merewether STS to
Kotara)
33 Rating
Feeder H775
(Merewether STS to
Kotara)
33 Rating
Feeder H776
(Merewether STS to
Newcastle CBD)
Load
Load
Load
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
19.0
-
-
-
-
-
-
-
-
-
-
-
29.4
-
-
-
-
-
-
-
-
-
-
-
18.9
-
-
-
-
-
-
-
-
-
-
-
29.3
-
-
-
-
-
-
-
-
-
-
-
18.5
-
-
-
-
-
-
-
-
-
-
-
60.0
-
-
-
-
-
-
-
-
-
-
-
-
9.0
8.9
9.0
9.1
9.3
-
4.7
4.6
4.6
4.6
4.6
27.7
-
29.3
29.3
29.3
29.3
29.3
-
27.7
27.7
27.7
27.7
16.3
16.2
-
-
-
-
10.9
10.8
10.5
-
-
-
40.0
40.0
-
-
-
-
40.0
40.0
40.0
-
-
-
22.4
22.3
-
-
-
-
15.7
20.0
19.7
-
-
-
33.4
33.4
-
-
-
-
33.4
33.4
33.4
-
-
-
-
-
13.4
13.5
13.7
13.9
-
-
-
12.1
12.4
12.7
-
-
43.3
43.3
43.3
43.3
-
-
-
43.3
43.3
43.3
27.4
27.3
31.6
32.0
32.6
33.4
18.1
18.2
17.7
25.0
24.2
25.0
36.0
36.0
36.0
36.0
36.0
36.0
38.9
38.9
38.9
38.9
38.9
38.9
-
18.3
-
-
-
-
-
-
-
-
-
-
60.0
-
-
-
-
-
-
-
-
-
-
-
-
9.3
9.2
9.3
9.4
9.6
-
4.9
4.7
4.7
4.7
4.7
-
29.3
29.3
29.3
29.3
29.3
-
38.5
38.5
38.5
38.5
38.5
22.4
22.3
-
-
-
-
15.7
20.0
19.7
-
-
-
33.4
33.4
-
-
-
-
33.4
33.4
33.4
-
-
-
-
-
13.4
13.5
13.7
13.9
-
-
-
12.1
12.4
12.7
-
-
43.3
43.3
43.3
43.3
-
-
-
43.3
43.3
43.3
26.2
26.3
31.5
31.8
32.4
33.3
23.4
18.5
19.2
24.6
24.2
24.7
42.0
42.0
42.0
42.0
42.0
42.0
40.7
43.0
43.0
43.0
43.0
43.0
25.9
25.8
25.6
25.6
25.8
25.9
15.8
15.3
14.8
14.8
14.7
14.8
30.3
30.3
30.3
30.3
30.3
30.3
32.9
32.9
32.9
32.9
32.9
32.9
25.9
25.8
25.6
25.6
25.8
25.9
15.8
15.3
14.8
14.8
14.7
14.8
30.3
30.3
30.3
30.3
30.3
30.3
32.9
32.9
32.9
32.9
32.9
32.9
18.4
18.4
16.0
16.1
16.5
16.9
12.6
12.4
12.0
12.0
12.0
12.0
36.0
36.0
36.0
36.0
36.0
36.0
38.9
38.9
38.9
38.9
38.9
38.9
Distribution and Transmission Annual Planning Report December 2013
58
3.12.3 STS and ZS load forecast
Newcastle Inner City Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Adamstown 132/11kV ZS
Broadmeadow 132/11kV ZS
Broadmeadow 33/11kV ZS
Carrington 33/11kV ZS
Kotara 33/11kV ZS
New Lambton 33/11kV ZS
Newcastle CBD 33/11kV ZS
Tighes Hill 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
125.2
100.0
37.8
61.0
30.5
45.7
68.6
70.0
130.0
100.0
42.8
61.0
30.5
45.7
68.6
70.0
63.0
60.0
18.9
30.5
30.5
22.9
45.7
43.4
65.0
60.0
21.4
30.5
30.5
22.9
45.7
43.4
75.6
66.7
21.0
33.9
26.5
27.4
50.9
43.4
75.3
72.0
25.7
36.6
26.5
27.4
54.9
43.4
2.9
13.8
13.8
13.8
11.2
2.9
13.8
13.8
3.5
19.1
19.1
19.1
5.0
3.5
19.1
19.1
1.81
0.80
0.85
0.92
0.87
1.02
-
1.96
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
SUMMER - Newcastle Inner City Area STS and ZS Load Forecast
Substation
Adamstown 132/11kV ZS
Adamstown 33/11kV ZS
Broadmeadow 132/11kV ZS
Broadmeadow 33/11kV ZS
Carrington 33/11kV ZS
Kotara 33/11kV ZS
New Lambton 33/11kV ZS
Newcastle CBD 33/11kV ZS
Newcastle City Main 33/11kV ZS
Tighes Hill 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
17.3
23.0
32.4
24.9
25.1
25.3
25.8
26.5
27.2
0.93
0.94
0.96
1.00
1.00
1.00
1.00
1.00
1.00
23.9
24.7
13.0
2.2
0.99
0.99
0.95
0.98
33.9
33.3
32.7
32.5
32.6
32.7
0.93
0.93
0.93
0.93
0.93
0.93
25.4
29.3
30.1
25.9
23.1
0.99
0.99
0.92
0.92
0.93
24.9
25.8
26.6
24.1
26.4
25.9
25.8
0.99
0.99
0.92
0.90
0.92
0.92
0.92
28.6
26.0
29.7
20.6
24.7
24.6
24.3
24.1
24.1
24.3
24.5
0.99
0.99
0.94
0.94
0.95
0.95
0.95
0.95
0.95
0.95
0.95
24.9
26.8
28.2
20.7
21.8
18.3
18.2
18.2
18.3
18.6
18.8
0.99
0.99
0.94
0.94
0.96
0.96
0.96
0.96
0.96
0.96
0.96
45.8
47.9
52.0
43.7
50.2
51.7
51.7
51.6
52.2
53.1
54.2
0.99
0.99
0.96
0.98
0.99
1.00
1.00
1.00
1.00
1.00
1.00
25.6
25.8
26.2
26.6
0.92
0.92
0.92
0.92
WINTER - Newcastle Inner City Area STS and ZS Load Forecast
Substation
Adamstown 132/11kV ZS
Adamstown 33/11kV ZS
Broadmeadow 132/11kV ZS
Broadmeadow 33/11kV ZS
Carrington 33/11kV ZS
Kotara 33/11kV ZS
New Lambton 33/11kV ZS
Newcastle CBD 33/11kV ZS
Newcastle City Main 33/11kV ZS
Tighes Hill 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
29.3
0.97
21.1
0.97
25.3
0.97
23.1
0.97
18.7
0.97
40.3
0.97
30.7
0.97
-
2009
27.8
0.99
21.0
0.99
23.4
0.99
20.3
0.99
18.6
0.99
33.6
0.99
-
Actual Load
2010
2011
9.2
26.9
0.97
0.97
21.8
2.0
0.97
0.99
19.2
18.8
0.94
0.94
26.1
23.0
0.93
0.95
19.2
15.1
0.96
0.97
20.9
17.2
0.96
0.97
33.9
34.3
0.98
0.95
-
Distribution and Transmission Annual Planning Report December 2013
2012
24.4
0.97
20.0
0.95
22.7
0.94
16.8
0.97
15.2
0.97
32.9
0.99
-
2013
22.2
0.99
0.5
0.95
21.6
0.94
15.3
0.97
10.8
0.97
35.8
1.00
-
2014
22.4
0.99
26.6
0.95
23.6
0.94
14.9
0.97
10.5
0.97
35.3
1.00
-
Forecast Load
2015
2016
22.7
23.6
0.99
0.99
26.0
26.2
0.95
0.95
23.4
0.94
14.4
14.4
0.97
0.97
10.2
10.1
0.97
0.97
34.2
34.2
1.00
1.00
23.4
0.94
2017
24.6
0.99
26.4
0.95
14.3
0.97
10.1
0.97
34.2
1.00
23.8
0.94
2018
25.5
1.00
26.7
0.95
14.4
0.97
10.1
0.97
34.3
1.00
24.4
0.94
59
3.13
Newcastle Ports Load Area
3.13.1 Description of Newcastle Ports Load area
The Newcastle Ports network area extends from Hexham and Kooragang Island in the north to Mayfield and
Waratah in the south. It is bordered on the east by Newcastle Harbour and extends west to Jesmond, Shortland
and Sandgate. The area contains significant heavy industrial development including coal transport and ship-loading
facilities, steel manufacturing and processing and other port related activities. General urban residential and
commercial development is also present around the Mayfield and Shortland areas. The University of Newcastle is
located at Callaghan, which is adjacent to the existing Shortland zone substation.
The principal heavy industrial development is located on either side of the south-arm of the Hunter River at Mayfield
North and on Kooragang Island. There are a significant number of proposals and enquiries for further heavy
industrial development in these areas including the construction of a third major coal-loader on Kooragang Island
anticipated for completion in mid 2015. Two additional coal-loaders are also proposed near Kooragang. The former
BHP-Billiton steel-works site (between Tubemakers and Carrington substations) is now largely unused and has
been targeted for future development for port-based commercial and industrial activities.
The network in the Newcastle Ports area:

receives supply from TransGrid’s Bulk Supply Points at Newcastle BSP and Waratah West BSP. The 132kV
network emanating from these substations supply both sub-transmission (STS) and zone substations (ZS)
within the area

both the 132kV and 33kV sub-transmission networks exist to supply customers in Newcastle Ports area

there are a number of 132kV feeders that interconnect with adjacent areas – Port Stephens, Newcastle
Western Corridor and Newcastle Inner City, and

there is also one major customer (Onesteel) that is supplied from the 132kV network.
Figure 16: Newcastle Ports load area
Distribution and Transmission Annual Planning Report December 2013
60
Table 14 – Identified system limitations in Newcastle Ports load area
Location
Waratah 132/33kV sub-transmission substation
1.
Identified
Limitation
Refer to
DAPR section
Asset Condition
5.3.16
3.13.2 Sub-transmission feeder load forecast
Newcastle Ports Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder 33730
(Kooragang STS to
Hexham SS)
Feeder 96X
(Waratah West BSP to
Kooragang STS)
Feeder 96Y
(Waratah West BSP to
Mayfield West ZS)
Feeder 97M
(Mayfield West ZS to
Kooragang STS)
Feeder 97W
(Mayfield West ZS to
Onesteel)
Feeder 97Z
(Mayfield West ZS to
Onesteel)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
8.4
8.4
8.4
8.4
8.4
8.4
8.5
8.5
8.5
8.5
8.5
8.5
33.7
33.7
33.7
33.7
33.7
33.7
36.6
36.6
36.6
36.6
36.6
36.6
75.9
76.1
76.8
76.9
77.8
78.7
83.8
83.0
81.8
82.6
82.6
82.7
214.0
214.0
214.0
214.0
214.0
214.0
240.0
240.0
240.0
240.0
240.0
240.0
76.0
76.2
76.6
77.1
77.9
78.8
83.5
82.8
82.0
82.1
82.4
82.1
76.0
76.2
76.6
77.1
77.9
78.8
240.0
240.0
240.0
240.0
240.0
240.0
44.0
44.2
45.0
45.0
45.9
46.8
43.9
43.1
41.8
42.4
42.4
42.5
249.0
249.0
249.0
249.0
249.0
249.0
271.0
271.0
271.0
271.0
271.0
271.0
7.6
7.6
7.6
7.6
7.6
7.6
10.1
10.1
10.1
10.1
10.1
10.1
214.0
214.0
214.0
214.0
214.0
214.0
240.0
240.0
240.0
240.0
240.0
240.0
7.6
7.6
7.6
7.6
7.6
7.6
10.1
10.1
10.1
10.1
10.1
10.1
214.0
214.0
214.0
214.0
214.0
214.0
240.0
240.0
240.0
240.0
240.0
240.0
3.13.3 STS and ZS load forecast
Newcastle Port Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Kooragang 132/33kV STS
Waratah (Comsteel) 132/33kV STS
Waratah (Domestic) 132/33kV STS
Jesmond 132/11kV ZS
Mayfield 33/11kV ZS
Mayfield West 132/11kV ZS
Shortland 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
285.8
0.0
120.0
107.5
90.2
-
285.8
0.0
120.0
107.5
90.2
-
142.9
0.0
90.0
57.5
31.7
-
142.9
0.0
90.0
57.5
33.7
-
142.9
0.0
90.0
64.3
35.4
-
142.9
0.0
90.0
69.0
40.5
-
8.6
8.6
8.6
11.2
11.2
-
4.8
4.8
4.8
5.0
5.0
-
0.01
2.39
0.85
-
0.55
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
SUMMER - Newcastle Port Area STS and ZS Load Forecast
Substation
Kooragang 132/33kV STS
Waratah (Comsteel) 132/33kV STS
Waratah (Domestic) 132/33kV STS
Jesmond 132/11kV ZS
Mayfield 33/11kV ZS
Mayfield West 132/11kV ZS
Shortland 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
34.0
56.2
61.6
63.0
63.0
63.0
63.0
63.0
63.0
0.93
0.87
0.94
0.94
0.94
0.94
0.94
0.94
0.94
58.9
58.3
58.6
56.9
58.0
58.0
58.0
58.0
58.0
58.0
58.0
0.94
0.90
0.90
0.96
0.94
0.94
0.94
0.94
0.94
0.94
0.94
108.7
80.3
96.4
34.1
23.3
20.5
20.5
20.5
20.5
20.5
20.5
0.96
0.98
0.98
0.97
0.90
0.90
0.90
0.90
0.90
0.90
0.90
4.4
31.9
45.8
45.1
44.9
44.6
44.9
45.4
45.9
1.00
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
23.6
4.5
6.1
0.3
0.99
0.99
0.91
0.96
24.0
23.8
25.1
25.5
33.7
34.0
34.2
34.9
35.8
36.8
0.90
0.92
0.90
0.92
0.92
0.92
0.92
0.92
0.92
0.92
30.0
29.8
28.4
3.6
0.96
0.98
0.94
0.98
-
Distribution and Transmission Annual Planning Report December 2013
61
WINTER - Newcastle Port Area STS and ZS Load Forecast
Substation
Kooragang 132/33kV STS
Waratah (Comsteel) 132/33kV STS
Waratah (Domestic) 132/33kV STS
Jesmond 132/11kV ZS
Mayfield 33/11kV ZS
Mayfield West 132/11kV ZS
Shortland 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
58.7
0.97
112.9
0.97
21.1
0.97
28.6
0.97
2009
98.4
0.98
18.8
0.99
24.9
0.98
Actual Load
2010
2011
39.8
0.90
57.7
0.95
60.2
50.5
0.98
1.00
24.6
0.96
4.4
0.3
0.87
0.96
17.7
21.3
0.95
0.92
22.6
6.9
0.97
0.99
Distribution and Transmission Annual Planning Report December 2013
2012
61.1
0.92
58.7
0.92
24.4
0.62
34.1
0.97
21.0
0.93
-
2013
68.4
0.92
58.7
0.92
9.0
0.73
35.8
0.93
27.4
0.93
-
2014
68.4
0.92
58.7
0.92
9.0
0.73
35.3
0.93
26.6
0.93
-
Forecast Load
2015
2016
68.4
68.4
0.92
0.92
58.7
58.7
0.92
0.92
9.0
9.0
0.73
0.73
34.7
35.2
0.93
0.93
25.8
25.8
0.93
0.93
-
2017
68.4
0.92
58.7
0.92
9.0
0.73
35.7
0.93
25.8
0.93
-
2018
68.4
0.92
58.7
0.92
9.0
0.73
36.3
0.93
25.9
0.93
-
62
3.14
Newcastle Western Corridor Load Area
3.14.1 Description of Newcastle Western Corridor area
The Newcastle Western Corridor network area is bounded by Hexham Wetlands to the north, and extends south to
Boolaroo and Holmesville. It includes the suburbs of Wallsend and Cardiff to the east and extends west to the F3
Freeway and Mount Sugarloaf. The area includes a mixture of residential, light industrial and commercial
development as well as several coal mining operations. It contains the principal urban expansion areas for
Newcastle and Lake Macquarie. There is ongoing residential development, particularly around Maryland and
Fletcher, as well as between Edgeworth and Cameron Park. The Glendale area is becoming an increasingly
important commercial and transport hub as urban development in the area continues.
The network in the Newcastle Western Corridor area:

is currently supplied from Argenton sub-transmission substation

consists of two older zone substations, supplied from the 33kV network

includes new 132/11kV zone substations at Maryland and Argenton

contains two 33kV connected mining customers

consists of approximately 40km of predominantly overhead 33kV feeder network

contains TransGrid’s 330/132kV Newcastle Bulk Supply Point at Killingworth, and

is traversed by several 132kV overhead feeders between Killingworth Bulk Supply Point and a number of
Ausgrid substations.
Figure 17: Newcastle Western Corridor Load Area
Distribution and Transmission Annual Planning Report December 2013
63
Table 15 – Identified system limitations in Newcastle Western Corridor load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Edgeworth 33/11kV ZS
Capacity
5.3.17
2.
Edgeworth 33/11kV ZS
Asset Condition
5.3.17
3.
Feeder 80258 - Argenton STS to Edgeworth ZS
Capacity
5.2.10
3.14.2 Sub-transmission feeder load forecast
Newcastle Western Corridor Area - Feeder Load Forecast
Summer (MVA)
Feeder name
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Feeder 80252
Load
21.5
21.5
21.6
21.9
22.3
22.8
(Argenton STS To Cardiff
33 Rating
40.3
40.3
40.3
40.3
40.3
40.3
ZS)
Feeder 80266
Load
21.5
21.5
21.6
21.9
22.3
22.8
(Argenton STS To Cardiff
40.3
40.3
40.3
40.3
40.3
40.3
ZS)
33 Rating
Feeder 80258
Load
27.7
29.2
30.8
31.7
33.0
34.6
(Argenton STS To
33 Rating
29.4
29.4
29.4
29.4
29.4
29.4
Edgeworth ZS)
Feeder 80262(1)
Load
28.3
29.6
30.9
31.9
33.0
34.1
(Argenton STS to tee
Edgeworth and Stockton 33 Rating
40.3
40.3
40.3
40.3
40.3
40.3
Feeder 80262(2)
(tee to Edgeworth ZS)
Feeder 80262(3)
(tee to Stockton
Borehole SS)
Feeder 3587(1)
(Edgeworth ZS to West
Wallsend Colliery)
Feeder 3587(3)
Edgeworth to West
Wallsend Colliery)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
12.6
13.8
13.9
14.3
14.8
15.4
43.8
43.8
43.8
43.8
43.8
43.8
12.7
13.8
13.9
14.3
14.8
15.4
40.3
40.3
40.3
40.3
40.3
40.3
22.0
18.3
19.3
20.0
20.7
21.6
35.7
35.7
35.7
35.7
35.7
35.7
25.8
20.0
20.6
21.1
21.4
22.2
43.8
43.8
43.8
43.8
43.8
43.8
27.3
28.7
30.2
31.4
32.7
33.9
21.8
18.1
19.1
19.8
20.5
21.3
46.8
46.8
46.8
46.8
46.8
46.8
63.7
63.7
63.7
63.7
63.7
63.7
14.3
14.6
14.6
14.4
14.5
14.5
14.1
15.9
15.9
15.8
15.4
15.8
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
4.4
4.4
4.4
4.4
4.4
4.4
5.2
5.2
5.2
5.2
5.2
5.2
31.4
31.4
31.4
31.4
31.4
31.4
41.9
41.9
41.9
41.9
41.9
41.9
4.4
4.4
4.4
4.4
4.4
4.4
5.2
5.2
5.2
5.2
5.2
5.2
13.8
13.8
13.8
13.8
13.8
13.8
17.7
17.7
17.7
17.7
17.7
17.7
3.14.3 STS and ZS load forecast
Newcastle Western Corridor Area - STS and ZS details
Winter
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
Summer
Licence
95% Peak Load
Capacity (MVA)
Exceeded
Winter
Substation
Argenton 132/33kV STS
Awaba 132/33kV STS
Argenton 132/11kV ZS
Cardiff 33/11kV ZS
Edgeworth 33/11kV ZS
Maryland 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
285.8
202.9
121.4
45.7
37.5
76.2
285.8
205.8
121.4
45.7
37.5
76.2
142.9
137.2
60.8
22.9
22.9
38.1
142.9
137.2
64.2
22.9
22.9
38.1
142.9
137.2
68.0
25.4
27.4
45.7
142.9
137.2
77.0
27.4
27.4
45.7
2.9
11.2
11.2
13.8
2.9
2.9
5.0
19.1
5.0
5.0
3.5
3.5
1.81
1.36
1.47
1.62
8.30
2.25
Identified
Limitation
in next 5
years
No
No
No
No
Yes
No
SUMMER - Newcastle Western Corridor Area STS and ZS Load Forecast
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Substation
Argenton 132/33kV STS
Awaba 132/33kV STS
Argenton 132/11kV ZS
Boolaroo 33/11kV ZS
Cardiff 33/11kV ZS
Edgeworth 33/11kV ZS
Maryland 132/11kV ZS
Wallsend 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
128.2
0.95
26.8
0.95
30.0
0.95
26.9
0.95
30.6
0.91
17.5
0.96
49.9
0.95
93.1
0.95
16.8
0.95
19.5
0.95
21.7
0.95
21.2
0.95
27.7
0.95
16.1
0.98
94.4
0.95
36.2
0.94
34.1
0.92
5.2
0.95
23.3
0.99
18.0
0.96
31.3
0.93
9.4
0.96
85.9
0.94
25.4
0.92
33.6
0.92
17.5
0.99
17.1
0.95
17.7
0.92
5.4
0.96
Distribution and Transmission Annual Planning Report December 2013
101.8
0.94
24.2
0.94
35.8
0.94
22.7
0.98
22.2
0.95
24.3
0.94
-
98.5
0.94
27.7
0.94
38.3
0.94
21.6
0.94
23.1
0.95
23.2
0.94
-
100.4
0.94
27.3
0.94
38.5
0.94
21.6
0.94
24.5
0.95
22.6
0.94
-
102.3
0.94
10.3
0.94
38.7
0.94
21.7
0.94
25.9
0.95
22.0
0.94
-
104.6
0.94
10.3
0.94
39.3
0.94
21.9
0.94
26.9
0.95
21.6
0.94
-
107.7
0.94
10.3
0.94
40.1
0.94
22.4
0.94
28.2
0.95
21.4
0.94
-
111.0
0.94
10.3
0.94
41.1
0.94
22.8
0.94
29.5
0.95
21.1
0.94
-
64
WINTER - Newcastle Western Corridor Area STS and ZS Load Forecast
Substation
Argenton 132/33kV STS
Awaba 132/33kV STS
Argenton 132/11kV ZS
Boolaroo 33/11kV ZS
Cardiff 33/11kV ZS
Edgeworth 33/11kV ZS
Maryland 132/11kV ZS
Wallsend 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
2009
123.5
0.96
26.0
0.96
24.0
0.97
19.4
0.97
27.3
0.94
14.3
0.97
21.8
0.97
94.5
0.98
14.7
0.95
13.5
0.98
16.9
0.97
17.1
0.97
20.7
0.95
13.8
0.98
Actual Load
2010
2011
31.5
0.98
64.7
0.95
28.8
0.91
4.0
0.98
18.8
0.99
12.7
0.99
19.1
0.95
12.0
0.97
68.9
0.97
25.8
0.96
30.2
0.97
17.4
1.00
11.5
0.98
17.7
0.95
6.3
0.98
Distribution and Transmission Annual Planning Report December 2013
2012
2013
2014
Forecast Load
2015
2016
2017
2018
68.3
0.95
22.5
0.95
27.7
0.96
16.8
0.97
13.6
0.98
13.6
0.96
-
66.1
0.95
19.9
0.95
30.7
0.96
14.0
0.97
12.8
0.98
12.8
0.96
-
67.0
0.95
19.8
0.95
30.0
0.96
15.2
0.97
13.8
0.98
12.4
0.96
-
67.5
0.95
19.8
0.95
29.9
0.96
15.3
0.97
14.9
0.98
12.0
0.96
-
71.0
0.95
7.6
0.95
31.6
0.96
16.3
0.97
16.4
0.98
12.0
0.96
-
73.2
0.95
7.6
0.95
32.6
0.96
17.0
0.97
17.2
0.98
12.0
0.96
-
69.2
0.95
7.6
0.95
30.8
0.96
15.8
0.97
15.6
0.98
12.0
0.96
-
65
3.15
North East Lake Macquarie Load Area
3.15.1 Description of North East Lake Macquarie area
The North East Lake Macquarie load area is bounded by Lake Macquarie to the west and the Pacific Ocean to the
east. The load area extends from Charlestown in the north to Catherine Hill Bay in the south. The North East Lake
Macquarie area includes the Charlestown CBD precinct, which comprises typical inner city commercial load. The
surrounding suburbs contain a mixture of residential and commercial areas. The opportunity exists for significant
future beachside and lakeside developments, particularly to the south of Swansea Channel. Increasing densities
within both residential and commercial areas are anticipated for much of the area, particularly around Charlestown,
which is becoming the principal commercial centre for Lake Macquarie.
The network in the North East Lake Macquarie area:

is currently supplied from both Merewether sub-transmission substation (STS) and Argenton STS which are
both supplied via 132kV feeders from TransGrid’s transmission system at Killingworth

consists of eight 33/11kV zone substations, of which six are supplied from the 33kV network originating
Merewether STS, and two (Mt Hutton and Croudace Bay) are supplied from the 33kV network from Argenton
STS

is a predominantly overhead 33kV feeder network with a combined total length of more than 110 km, and

is traversed on its northern boundary by a double circuit 132kV tower line from Newcastle 330kV substation to
Merewether STS.
Figure 18: North East Lake Macquarie Load Area
Distribution and Transmission Annual Planning Report December 2013
66
Table 16 – Identified system limitations in North East Lake Macquarie load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Swansea 33/11kV ZS
Asset Condition
5.3.18
2.
Feeder 760 - Merewether to Jewells
Asset Condition
5.2.11
3.
Feeder 766 - Merewether to Gateshead
Asset Condition
5.2.11
3.15.2 Sub-transmission feeder load forecast
North East Lake Macquarie Area - Feeder Load Forecast
Feeder name
Feeder 3239(1)
(Gateshead to Pelican)
Feeder 3239(2)
(Gateshead to Pelican)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
Feeder 760 (Merewether
STS to Dudley)
33 Rating
Feeder 760 (Merewether
STS to Jewells)
33 Rating
Feeder 772 (Merewether
STS to Gateshead)
Feeder 3231
(Jewells To Pelican)
Feeder 3240
(Pelican To Swansea)
Feeder 3431 (Gateshead
to Jewells)
Feeder 3691
(Pelican To Swansea)
Feeder 34405
(Mt Hutton To Croudace
Bay)
Feeder 80249
(Argenton STS To Mt
Hutton)
Feeder 80255
(Argenton STS To
Croudace Bay)
Feeder 80263
(Argenton STS To Mt
Hutton)
Feeder H766
(Merewether STS to
Dudley)
Feeder H766
(Merewether STS to
Gateshead)
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder 3087
(Dudley to Gateshead)
33 Rating
Feeder 3095
(Dudley to Jewells)
33 Rating
Load
2013
2014
Winter (MVA)
2015
2016
2017
2018
23.4
23.1
22.7
22.6
22.3
22.9
20.7
21.4
21.4
20.6
20.7
20.5
29.3
29.3
29.3
29.3
29.3
29.3
38.5
38.5
38.5
38.5
38.5
38.5
23.9
23.6
23.2
23.1
22.8
23.4
21.1
21.9
20.9
21.1
20.9
21.1
29.3
29.3
29.3
29.3
29.3
29.3
38.5
38.5
38.5
38.5
38.5
38.5
-
-
-
-
-
-
25.8
-
-
-
-
-
-
-
-
-
-
-
51.4
-
-
-
-
-
23.8
23.9
23.9
24.0
24.3
24.4
0.0
20.4
19.8
20.1
20.2
20.6
29.4
29.4
29.4
29.4
29.4
29.4
29.4
29.4
29.4
29.4
29.4
27.9
28.0
28.0
28.1
28.6
28.7
21.5
23.9
23.3
23.6
23.9
24.4
30.3
30.3
30.3
30.3
30.3
30.3
32.9
32.9
32.9
32.9
32.9
32.9
23.4
23.0
22.6
22.5
22.6
22.7
20.6
21.2
20.5
20.5
20.4
20.5
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
13.0
13.0
13.0
13.2
13.5
13.7
11.1
10.7
10.4
10.4
10.4
10.4
18.0
18.0
18.0
18.0
18.0
18.0
20.0
20.0
20.0
20.0
20.0
20.0
24.2
24.0
24.1
23.9
24.4
24.4
21.2
21.4
20.5
20.7
20.6
20.4
30.3
30.3
30.3
30.3
30.3
30.3
33.8
33.8
33.8
33.8
33.8
33.8
13.0
13.0
13.0
13.1
13.5
13.7
11.1
10.8
10.4
10.4
10.4
10.5
18.0
18.0
18.0
18.0
18.0
18.0
20.0
20.0
20.0
20.0
20.0
20.0
22.3
22.6
22.7
23.3
24.0
24.7
17.6
15.7
15.6
15.9
16.3
16.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
21.1
21.3
21.4
21.9
22.4
23.1
15.5
14.4
14.1
14.3
14.4
14.7
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
23.3
23.6
23.9
24.5
25.3
26.2
18.3
16.5
16.2
16.7
16.9
17.5
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
22.7
23.0
23.0
23.6
24.2
24.9
16.8
15.5
15.2
15.4
15.6
15.9
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
-
-
-
-
-
-
26.2
-
-
-
-
-
-
-
-
-
-
-
56.6
-
-
-
-
-
29.7
29.6
29.5
29.7
30.1
30.5
-
25.3
24.8
25.1
25.4
25.8
40.3
40.3
40.3
40.3
40.3
40.3
-
40.3
40.3
40.3
40.3
40.3
-
-
-
-
-
-
27.7
-
-
-
-
-
-
-
-
-
-
-
43.8
-
-
-
-
-
-
-
-
-
-
-
22.1
-
-
-
-
-
-
-
-
-
-
-
32.7
-
-
-
-
-
Distribution and Transmission Annual Planning Report December 2013
67
3.15.3 STS and ZS load forecast
North East Lake Macquarie Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Merewether 132/33kV STS
Charlestown 132/11kV ZS
Croudace Bay 33/11kV ZS
Dudley 33/11kV ZS
Gateshead 33/11kV ZS
Jewells 33/11kV ZS
Mt Hutton 33/11kV ZS
Pelican 33/11kV ZS
Swansea 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
411.5
100.0
72.9
30.3
44.4
30.8
59.8
45.7
29.9
411.5
100.0
76.2
33.3
44.4
32.5
65.8
45.7
29.9
274.4
60.0
38.1
16.7
24.1
16.9
32.7
22.9
16.4
274.4
60.0
38.1
18.3
24.4
18.1
34.3
22.9
16.4
274.4
64.7
45.7
20.0
26.9
20.3
39.2
25.0
19.7
274.4
69.4
45.7
22.0
25.8
21.8
41.2
26.0
16.5
11.2
11.2
2.9
2.9
11.2
2.9
2.9
11.2
2.9
5.0
5.0
3.5
3.5
3.5
3.5
3.5
5.0
3.5
1.70
1.69
0.03
1.14
1.29
1.42
0.52
1.00
3.80
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
SUMMER - North East Lake Macquarie Area STS and ZS Load Forecast
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Substation
Merewether 132/33kV STS
Charlestown 132/11kV ZS
Charlestown 33/11kV ZS
Croudace Bay 33/11kV ZS
Dudley 33/11kV ZS
Gateshead 33/11kV ZS
Jewells 33/11kV ZS
Mt Hutton 33/11kV ZS
Pelican 33/11kV ZS
Swansea 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
269.5
0.99
31.4
0.99
24.6
0.95
10.8
0.99
15.7
0.99
17.4
0.99
18.2
0.95
11.9
0.99
13.1
0.99
253.2
0.99
29.6
0.99
26.2
0.95
10.7
0.99
14.4
0.99
17.2
0.99
19.3
0.95
11.7
0.99
13.6
0.99
242.8
0.98
33.7
0.95
29.2
0.98
11.4
0.94
16.6
0.92
18.8
0.93
21.0
0.98
12.2
0.99
13.5
1.00
187.1
0.99
19.0
0.99
19.7
0.98
7.4
0.94
12.6
0.90
12.7
0.94
14.8
0.98
9.5
0.93
9.4
1.00
197.4
0.98
39.0
0.90
26.9
0.97
5.0
0.94
12.6
0.94
17.3
0.95
20.1
0.96
12.0
0.94
13.6
0.98
152.6
0.98
33.7
0.90
23.8
0.99
15.3
0.94
15.9
0.95
20.3
0.88
12.0
0.94
12.7
0.89
152.1
0.98
32.7
0.90
24.0
0.99
15.5
0.94
15.9
0.95
20.4
0.88
11.7
0.94
12.7
0.89
151.6
0.98
31.7
0.90
24.3
0.99
15.8
0.94
15.9
0.95
20.4
0.88
11.4
0.94
12.7
0.89
152.6
0.98
31.0
0.90
24.8
0.99
15.9
0.94
16.0
0.95
20.7
0.88
11.2
0.94
12.8
0.89
154.6
0.98
30.6
0.90
25.5
0.99
16.2
0.94
16.3
0.95
21.1
0.88
11.1
0.94
13.0
0.89
156.9
0.98
30.1
0.90
26.3
0.99
16.5
0.94
16.5
0.95
21.5
0.88
11.0
0.94
13.2
0.89
WINTER - North East Lake Macquarie Area STS and ZS Load Forecast
Substation
Merewether 132/33kV STS
Charlestown 132/11kV ZS
Charlestown 33/11kV ZS
Croudace Bay 33/11kV ZS
Dudley 33/11kV ZS
Gateshead 33/11kV ZS
Jewells 33/11kV ZS
Mt Hutton 33/11kV ZS
Pelican 33/11kV ZS
Swansea 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
2009
275.5
0.97
26.0
0.97
23.3
0.96
11.9
0.97
16.7
0.97
17.8
0.97
13.4
0.97
12.0
0.97
14.1
0.97
238.0
0.99
22.0
0.99
19.7
0.98
10.9
0.99
20.0
0.99
15.9
0.99
16.0
0.97
11.1
0.99
11.6
0.99
Actual Load
2010
2011
204.8
0.99
19.7
1.00
20.0
0.95
9.5
0.97
13.2
0.96
14.7
0.96
15.8
0.93
10.4
0.96
11.9
1.00
187.9
1.00
20.4
0.98
20.1
0.95
9.4
0.97
12.1
0.96
14.3
0.97
15.1
0.93
10.0
0.97
12.5
0.98
Distribution and Transmission Annual Planning Report December 2013
2012
2013
2014
Forecast Load
2015
2016
2017
2018
168.8
0.99
18.5
0.99
18.1
0.96
8.5
0.98
11.6
0.97
13.3
0.97
14.3
0.98
10.1
0.96
11.8
0.98
113.8
1.00
33.7
0.91
18.3
0.96
13.5
0.97
13.0
0.97
14.4
0.89
10.8
0.86
10.9
0.98
114.8
1.00
32.7
0.91
16.5
0.97
13.7
0.97
12.6
0.97
13.9
0.89
11.7
0.86
10.6
0.98
112.2
1.00
31.7
0.91
16.3
0.97
13.9
0.97
12.3
0.97
13.5
0.89
11.3
0.86
10.3
0.98
113.7
1.00
31.7
0.91
17.0
0.97
14.9
0.97
12.2
0.97
13.5
0.89
11.3
0.86
10.2
0.98
114.9
1.00
31.8
0.91
17.5
0.96
15.5
0.97
12.2
0.97
13.5
0.89
11.3
0.86
10.3
0.98
113.0
1.00
31.7
0.91
16.7
0.97
14.4
0.97
12.2
0.97
13.5
0.89
11.3
0.86
10.3
0.98
68
3.16
North West Sydney Load Area
3.16.1 Description of North West Sydney area
The North West network area includes the area from Sydney North bulk supply point (BSP) in the north, north-east
to Berowra and south to Pennant Hills. The area is relatively geographically isolated, bordering Ku-ring-gai Chase
National Park and other bush land. The main Sydney to Newcastle freeway and railway run through the eastern
edge of this area.
Most loads in this area arise from urban residential development in the south-eastern half of the area. Development
is mixed and ranges from high-value residential properties in the Cherrybrook area to large scale apartment
development at Hornsby. There has been significant high density residential development at Hornsby in recent
years, which is expected to continue. The “City of Cities – A Plan for Sydney’s Future”- Dept of Planning 2006
metropolitan strategy released by the NSW Government forecasts that 11,000 new dwellings will be constructed in
the area over the next 25 years, Pennant Hills, Hornsby and Berowra zone substations are constructed in
residential areas in close proximity to residential housing.
Much of the distribution development in the area over the last twenty years has utilised an entirely underground
distribution network. Any new sub-transmission construction through urban areas will also require underground
construction. The western and northern parts of the area are separated from the rest of the area by Galston Gorge
(Berowra Valley Regional Park) and are characterised by a largely semi-rural population.
The network in the North West area:

is supplied from TransGrid’s transmission system at Sydney North Bulk Supply Point (BSP)

consists of four 132/11kV zone substations (ZS) – Berowra, Hornsby, Pennant Hills and Galston ZS supplied
on a 132kV ring from Sydney North (BSP), and

includes a 66kV supply to Sydney Trains from Berowra zone substation.
Figure 19 North West Sydney Load Area
Distribution and Transmission Annual Planning Report December 2013
69
Table 17 – Identified system limitations in North West Sydney load area
Location
1.
Identified
Limitation
Refer to
DAPR section
Nil
-
Nil
3.16.2 Sub-transmission feeder load forecast
North West Area - Feeder Load Forecast
Feeder name
Feeder 250
(Sydney North BSP to
Berowra ZS)
Feeder 251
(Sydney North BSP to
Pennant Hills ZS)
Feeder 252
(Berowra ZS to Hornsby
ZS)
Feeder 253
(Pennant Hills ZS to
Hornsby ZS)
Feeder 257
(Sydney North BSP to
Galston ZS)
Feeder 258
(Sydney North BSP to
Galston ZS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
174.3
168.2
171.8
173.8
Winter (MVA)
2015
2016
2017
2018
163.4
169.0
163.2
168.4
173.1
165.6
275.0
275.0
275.0
275.0
275.0
275.0
302.0
302.0
302.0
302.0
302.0
302.0
167.1
163.6
165.3
168.3
170.8
160.8
165.2
160.8
162.7
165.4
169.3
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
151.4
148.1
145.0
145.8
148.7
150.1
139.1
145.0
140.1
142.4
145.0
149.2
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
228.6
93.2
92.5
91.6
93.6
96.3
98.8
91.8
90.8
89.0
90.6
92.7
95.5
275.0
275.0
275.0
275.0
275.0
275.0
285.8
285.8
285.8
285.8
285.8
285.8
8.4
8.1
7.9
8.1
8.1
8.2
5.3
5.2
5.1
5.1
5.2
5.3
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
Load
132 Rating
167.0
2014
170.5
Load
132 Rating
170.5
2013
8.4
8.1
7.9
8.1
8.1
8.2
5.3
5.2
5.1
5.1
5.2
5.3
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
68.6
3.16.3 STS and ZS load forecast
North West Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Berowra 132/11kV ZS
Galston 132/11kV ZS
Hornsby 132/11kV ZS
Pennant Hills 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
82.9
76.2
171.5
164.1
85.5
76.2
171.5
171.5
42.3
38.1
114.3
106.9
44.6
38.1
114.3
114.3
50.8
45.7
137.2
128.3
51.1
43.2
130.3
130.0
2.9
2.9
2.9
2.9
3.5
3.5
5.0
3.5
1.54
0.63
1.94
3.84
-
Identified
Limitation
in next 5
years
No
No
No
No
SUMMER - North West Area STS and ZS Load Forecast
Substation
MVA
PF
MVA
Galston 132/11kV ZS
PF
MVA
Hornsby 132/11kV ZS
PF
MVA
Pennant Hills 132/11kV ZS PF
Berowra 132/11kV ZS
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
20.9
23.3
26.3
17.4
24.3
22.5
22.2
22.0
22.3
22.8
23.2
0.91
0.91
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
8.3
9.5
9.4
9.2
9.0
9.0
9.1
9.2
0.90
0.92
0.92
0.92
0.92
0.92
0.92
0.92
78.6
77.6
80.5
60.1
70.3
73.5
73.0
72.5
73.9
76.0
77.8
0.98
0.96
0.96
0.97
0.97
0.98
0.98
0.98
0.98
0.98
0.98
94.7
88.2
91.3
61.3
80.4
81.6
79.1
76.5
76.1
76.2
76.0
0.91
0.91
0.93
0.96
0.95
0.95
0.95
0.95
0.95
0.95
0.95
WINTER - North West Area STS and ZS Load Forecast
Substation
MVA
Berowra 132/11kV ZS
PF
MVA
Galston 132/11kV ZS
PF
MVA
Hornsby 132/11kV ZS
PF
MVA
Pennant Hills 132/11kV ZS PF
2008
27.2
0.95
84.7
0.99
95.1
0.95
2009
25.1
0.95
79.4
0.99
91.1
0.96
Actual Load
2010
2011
25.7
24.4
0.97
0.97
3.6
0.90
77.9
72.4
0.99
0.99
81.8
74.0
0.97
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
21.2
0.97
8.7
0.96
62.7
0.90
69.3
0.90
2013
23.2
0.97
8.2
0.96
67.8
0.95
67.4
0.90
2014
22.5
0.97
8.0
0.96
67.5
0.95
72.2
0.90
Forecast Load
2015
2016
21.8
21.9
0.97
0.97
7.8
7.8
0.96
0.96
66.5
67.8
0.95
0.95
70.0
70.2
0.90
0.90
2017
22.0
0.97
7.9
0.96
69.5
0.94
70.6
0.90
2018
22.3
0.97
8.1
0.96
71.6
0.94
71.5
0.90
70
3.17
Pittwater and Terrey Hills Load Area
3.17.1 Description of Pittwater and Terrey Hills area
The Terrey Hills & Pittwater network area forms a long, narrow corridor beginning at Sydney East sub-transmission
substation (west of Belrose), and extending from Terrey Hills to Palm Beach in the north, and down the coast to
Narrabeen. The area is bounded to the west by bushland and Broken Bay, and to the north and east by the
Tasman Sea.
The area is primarily low density residential, although there is continuing development of medium density housing in
the Warriewood area. The customer load is primarily domestic load of relatively low density with some commercial
load, including the recently expanded Austlink Business Park in Belrose. Multiple zone substations are required to
supply this long load corridor. Geographic constraints on development and residential load densities limit the
maximum load which can be supplied from a single zone substation.
The network in the Pittwater & Terrey Hills area:

is supplied from TransGrid’s transmission system at the TransGrid/Ausgrid Sydney East sub-transmission
substation via two 120MVA transformers and three overhead 33kV feeders to Terrey Hills and Narrabeen zone
substations, and Warriewood sub-transmission switching station

has 33kV feeders approaching their voltage and thermal limits. These 33kV feeders are long and therefore
have relatively high losses and voltage drops

has two connection points with the Manly-Warringah distribution network to the south, which provides limited
emergency back-up in the event of multiple 132/33kV transformer outages, and

has a 5MW landfill gas generator at Belrose which feeds in at the 33kV busbar supplying the network.
Figure 20: Pittwater and Terrey Hills load area
Distribution and Transmission Annual Planning Report December 2013
71
Table 18 – Identified system limitations in Pittwater and Terrey Hills load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Careel Bay 33/11kV ZS
Asset Condition
5.3.7
2.
Mona Vale 33/11kV ZS
Asset Condition
5.3.7
3.
Narrabeen 33/11kV ZS
Asset Condition
5.3.7
4.
Terrey Hills 33/11kV ZS
Asset Condition
5.3.7
5.
Feeder S20 - Sydney East STS to Warriewood STSS
Asset Condition
5.2.7
Distribution and Transmission Annual Planning Report December 2013
72
3.17.2 Sub-transmission feeder load forecast
Pittwater & Terrey Hills Area - Feeder Load Forecast
Summer (MVA)
Feeder name
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder S22
(Sydney East BSP to
Terrey Hills ZS)
33 Rating
Feeder S24
(Sydney East BSP to
Terrey Hills ZS)
33 Rating
Feeder S40
(Terrey Hills to
Warriewood STSS)
33 Rating
Feeder S42(1)
(Warriewood STSS to
S42 TEE)
33 Rating
Feeder S42(2)
(S42 Tee to Newport ZS)
33 Rating
Feeder S44
(Warriewood STSS to
Newport ZS)
33 Rating
Feeder S46
(Warriewood STSS to
Mona Vale ZS)
Feeder S43
(Warriewood STSS to
Mona Vale ZS)
Feeder S45
(Warriewood STSS to
Mona Vale ZS)
Feeder S47
(Newport ZS to Careel
Bay ZS)
Load
Load
Load
Load
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Feeder S50
(Newport ZS to Careel
Bay ZS)
33 Rating
Feeder S21(1)
(Sydney East BSP to
S21 TEE1)
33 Rating
Feeder S21(2)
(S21 Tee1 to S21 Tee2)
33 Rating
Feeder S21(3)
(S21 Tee1 to CP Belrose
ZS)
33 Rating
Feeder S21(4)
(S21 Tee 2T TO
NARRABEEN)
33 Rating
Feeder S21(5)
(S21 Tee 2 to
Warriewood STSS)
33 Rating
Feeder S20(1)
(Sydney East BSP to
S20 Tee1)
Feeder S20(2)
(S20 Tee1 to S20 Tee2)
Feeder S20(3)
(S20 Tee1 to CP Belrose
ZS)
Winter (MVA)
Load
Load
Load
Load
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Feeder S20(4)
(S20 Tee2 to
Warriewood STSS)
33 Rating
Feeder S20(5)
(S20 Tee2 to Narrabeen
ZS)
33 Rating
Load
Load
2013
2014
2015
2016
2017
2018
29.3
29.5
29.2
29.8
31.0
31.9
31.3
31.1
30.2
30.7
31.4
32.2
51.6
51.6
51.6
51.6
51.6
51.6
59.4
59.4
59.4
59.4
59.4
59.4
34.5
34.7
34.4
34.9
36.3
37.3
37.5
37.2
36.0
36.6
37.4
38.5
66.0
66.0
66.0
66.0
66.0
66.0
68.6
68.6
68.6
68.6
68.6
68.6
34.2
34.7
34.5
35.4
36.8
38.0
41.6
41.3
39.9
40.4
41.2
42.2
55.0
55.0
55.0
55.0
55.0
55.0
61.1
61.1
61.1
61.1
61.1
61.1
16.8
16.6
16.5
16.9
17.4
17.9
30.4
29.8
29.0
29.6
30.1
30.8
44.3
44.3
44.3
44.3
44.3
44.3
49.3
49.3
49.3
49.3
49.3
49.3
16.8
16.6
16.5
16.9
17.4
17.9
30.3
29.6
28.9
29.5
30.0
30.7
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
16.9
16.8
16.7
17.1
17.6
18.1
31.2
30.0
29.8
30.3
30.9
31.1
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
18.6
19.2
19.3
20.0
20.7
21.4
17.3
17.0
16.5
16.7
16.9
17.2
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
34.3
18.6
19.1
19.2
19.9
20.6
21.3
17.4
17.0
16.6
16.8
17.0
17.2
31.7
31.7
31.7
31.7
31.7
31.7
34.3
34.3
34.3
34.3
34.3
34.3
18.7
19.3
19.4
20.0
20.8
21.5
17.3
17.0
16.6
16.8
16.9
17.1
31.7
31.7
31.7
31.7
31.7
31.7
34.3
34.3
34.3
34.3
34.3
34.3
9.5
9.3
9.1
9.1
9.2
9.2
14.2
13.2
13.3
13.5
13.7
14.0
20.0
20.0
20.0
20.0
20.0
20.0
22.9
22.9
22.9
22.9
22.9
22.9
9.5
9.3
9.1
9.2
9.2
9.2
13.4
13.0
12.7
12.8
13.0
13.2
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
32.6
33.1
32.9
33.7
35.2
36.3
39.6
39.4
37.9
38.3
39.2
40.2
53.8
53.8
53.8
53.8
53.8
53.8
57.2
57.2
57.2
57.2
57.2
57.2
32.2
32.8
32.5
33.4
34.8
35.8
39.0
38.8
37.3
37.8
38.6
39.5
60.1
60.1
60.1
60.1
60.1
60.1
65.5
65.5
65.5
65.5
65.5
65.5
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
61.7
61.7
61.7
61.7
61.7
61.7
67.2
67.2
67.2
67.2
67.2
67.2
10.2
9.9
9.6
9.5
9.5
9.5
11.2
12.2
11.8
11.8
11.9
12.1
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
31.8
32.2
32.1
32.9
34.1
35.1
38.0
37.8
36.5
37.0
37.7
38.5
61.7
61.7
61.7
61.7
61.7
61.7
67.2
67.2
67.2
67.2
67.2
67.2
26.8
27.1
26.8
27.4
28.6
29.4
32.5
32.8
31.4
31.8
32.4
33.3
54.0
54.0
54.0
54.0
54.0
54.0
57.2
57.2
57.2
57.2
57.2
57.2
26.4
26.7
26.4
27.0
28.1
28.8
31.8
32.0
30.8
31.1
31.7
32.5
61.7
61.7
61.7
61.7
61.7
61.7
67.2
67.2
67.2
67.2
67.2
67.2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
37.1
37.1
37.1
37.1
37.1
37.1
42.8
42.8
42.8
42.8
42.8
42.8
17.1
17.5
17.6
18.2
18.8
19.5
20.3
19.5
19.0
19.3
19.6
20.0
47.8
47.8
47.8
47.8
47.8
47.8
52.1
52.1
52.1
52.1
52.1
52.1
10.6
10.2
9.9
9.8
9.9
9.9
11.5
12.6
12.3
12.3
12.4
12.5
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
42.9
Distribution and Transmission Annual Planning Report December 2013
73
3.17.3 STS and ZS load forecast
Pittwater and Terrey Hills Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Sydney East 132/33kV STS
Careel Bay 33/11kV ZS
Mona Vale 33/11kV ZS
Narrabeen 33/11kV ZS
Newport 33/11kV ZS
Terrey Hills 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
205.8
30.5
97.8
44.7
45.1
60.7
205.8
30.5
97.8
45.9
45.2
60.7
102.9
15.2
53.5
19.6
22.4
30.5
102.9
15.3
55.7
20.3
22.4
30.5
102.9
15.2
53.5
19.6
25.6
30.5
102.9
15.3
55.7
20.3
26.9
30.5
2.9
2.9
11.2
2.9
2.9
13.8
5.0
3.5
5.0
3.5
3.5
19.1
0.45
1.16
0.75
0.61
0.44
5.00
1.02
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
SUMMER - Pittwater and Terrey Hills Area STS and ZS Load Forecast
Substation
Sydney East 132/33kV STS
Careel Bay 33/11kV ZS
Mona Vale 33/11kV ZS
Narrabeen 33/11kV ZS
Newport 33/11kV ZS
Terrey Hills 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
72.9
77.4
83.5
63.2
82.5
74.6
75.2
74.7
76.6
78.9
81.0
0.97
0.97
0.94
0.97
0.98
0.98
0.98
0.98
0.98
0.98
0.98
12.4
11.1
12.1
9.3
12.1
10.0
9.8
9.5
9.6
9.6
9.7
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
30.5
33.1
38.1
29.5
36.7
36.3
37.5
37.6
38.8
40.1
41.4
0.97
0.97
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
0.92
15.3
11.2
11.9
15.0
11.2
11.4
11.0
10.7
10.6
10.6
10.6
0.97
0.97
0.89
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
15.0
16.0
14.1
10.9
13.3
12.9
13.1
13.3
13.9
14.6
15.3
0.97
0.97
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
16.6
17.1
17.7
14.4
16.7
16.7
16.5
16.2
16.5
16.8
17.1
0.97
0.97
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
0.94
WINTER - Pittwater and Terrey Hills Area STS and ZS Load Forecast
Substation
Sydney East 132/33kV STS
Careel Bay 33/11kV ZS
Mona Vale 33/11kV ZS
Narrabeen 33/11kV ZS
Newport 33/11kV ZS
Terrey Hills 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
103.0
0.95
15.0
0.95
34.8
0.95
19.1
0.95
22.8
0.95
14.2
0.95
2009
88.9
1.00
13.8
1.00
30.1
1.00
15.1
1.00
21.4
1.00
13.4
1.00
Actual Load
2010
2011
90.0
86.2
0.97
1.00
13.9
13.5
0.90
0.90
31.4
34.4
0.94
0.94
13.3
12.4
0.93
0.93
21.1
15.9
0.95
0.95
13.4
12.4
0.96
0.95
Distribution and Transmission Annual Planning Report December 2013
2012
79.4
0.98
13.0
0.90
31.3
0.94
11.7
0.93
16.4
0.90
13.2
0.95
2013
82.6
1.00
12.9
0.90
33.8
0.94
11.1
0.93
16.0
0.90
13.6
0.95
2014
82.1
1.00
12.6
0.90
33.1
0.94
12.1
0.93
15.8
0.90
13.5
0.95
Forecast Load
2015
2016
80.3
81.5
1.00
1.00
12.2
12.4
0.90
0.90
32.4
32.7
0.94
0.94
11.8
11.8
0.93
0.93
15.5
15.8
0.90
0.90
13.3
13.7
0.95
0.95
2017
82.7
1.00
12.5
0.90
33.1
0.94
11.9
0.93
16.2
0.90
14.0
0.95
2018
84.2
1.00
12.7
0.90
33.5
0.94
12.0
0.93
16.6
0.90
14.4
0.95
74
3.18
Port Stephens Load Area
3.18.1 Description of Port Stephens Load area
The Port Stephens network area approximately coincides with Port Stephens local shire area. It extends from
Nelson Bay and the coastline in the east, to Raymond Terrace in the west, and from Karuah in the north, to
Stockton and Tomago in the south. The area is very diverse and includes tourism-based commercial development,
heavy industrial development, the RAAF Fighter Base, and Newcastle Airport at Williamtown.
The Port Stephens area has been targeted for future development and continues to grow steadily. Medium density
tourist-related and residential urban development is prevalent around Nelson Bay. Two precincts have been
identified at Medowie and Raymond Terrace for major subdivision developments. Tanilba Bay and Anna Bay have
been earmarked for other large residential developments. The industrial developments at Heatherbrae and Tomago
both have large portions of land subdivided for industrial development.
The network in the Port Stephens area:

is supplied from Tomago sub-transmission substation (STS)

includes six zone substations all of which are supplied from the 33kV network from Tomago

includes 33kV customer connections for the RAAF Fighter Base at Williamtown and Hunter Water Corporation
at Tomago

provides the main 33kV supply to Tea Gardens for Essential Energy

includes a single transformer 33/11kV zone substation at Tanilba Bay, with a portable 11kV switchroom, which
was commissioned in early 2006, and

consists of approximately 195km of predominantly overhead 33kV feeder network.
Figure 21: Port Stephens Load Area
Table 19 – Identified system limitations in Port Stephens load area
Location
1.
Nelson Bay 33/11kV ZS
2.
Feeder TM4 - Tomago STS to Medowie ZS
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
Refer to
DAPR section
Asset Condition
5.3.19
Capacity
5.2.12
75
3.18.2 Sub-transmission feeder load forecast
Port Stephens Area - Feeder Load Forecast
Feeder name
Feeder 3300 (1)
(Williamtown to tee
Tomaree and Tanilba
Feeder 3300 (2)
(tee to Tomaree)
Feeder 3300 (3)
(tee to Tanilba Bay)
Feeder 3301
(Williamtown to
Stockton)
Feeder 3305
(Williamtown to
Stockton)
Feeder 33366
(Tomaree to Nelson Bay)
Feeder 34084
(Williamtown to
Williamtown RAAF)
Feeder TM1
(Tomago STS To
Raymond Terrace)
Feeder TM10
(Tomago STS To
Williamtown ZS)
Feeder TM11
(Tomago STS To HDWB
Tomago)
Feeder TM12
(Tomago STS To
Raymond Terrace)
Feeder TM2(1)
(Tomago STS to tee
Williamtown and Nelson
Feeder TM2(2)
(tee to Nelson Bay)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder TM2(3)
(tee to Williamtown)
33 Rating
Feeder TM3
Load
(Tomago STS to Tomago
ZS)
33 Rating
Feeder TM4 (1) (Tomago
Load
STS to Salt Ash and
Tanilba Bay)
33 Rating
Feeder TM4 (2)
(tee to Salt Ash)
Feeder TM4 (3)
(tee to Tanilba Bay)
Feeder TM4
(Tomago STS to
Medowie)
Feeder TM5 (1) (Tomago
STS to Raymond
Terrace)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
Feeder TM5
(Tomago STS to AGL)
33 Rating
Feeder 81204
Load
(AGL to Raymond
Terrace)
33 Rating
Feeder TM6
Load
(Tomago STS to Tomago
33 Rating
ZS)
Feeder TM7 (Tomago
STS To Williamtown)
Feeder TM8
(Tomago STS To HDWB
Tomago)
Feeder TM9
(Tomago STS to Nelson
Bay ZS)
Feeder 81405 (1)
(Medowie to Tanilba
Bay)
Feeder 81405 (2)
(Medowie to Tanilba
Bay)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
20.5
20.6
20.5
20.8
21.1
21.6
17.7
18.1
17.7
17.7
17.7
17.6
46.9
46.9
46.9
46.9
46.9
46.9
52.5
52.5
52.5
52.5
52.5
52.5
20.2
20.3
20.2
20.5
20.8
21.2
17.8
18.2
17.9
17.8
17.8
17.7
31.2
31.2
31.2
31.2
31.2
31.2
41.4
41.4
41.4
41.4
41.4
41.4
7.9
7.9
7.9
8.1
8.3
8.5
-
6.4
6.2
6.1
6.1
6.2
25.7
25.7
25.7
25.7
25.7
25.7
-
28.5
28.5
28.5
28.5
28.5
7.9
8.1
8.4
8.7
9.2
9.6
5.6
5.4
5.2
5.2
5.2
5.2
18.2
18.2
18.2
18.2
18.2
18.2
22.5
23.5
24.5
25.5
26.5
27.5
7.9
8.1
8.4
8.7
9.2
9.6
5.6
5.4
5.3
5.2
5.2
5.2
18.2
18.2
18.2
18.2
18.2
18.2
22.5
23.5
24.5
25.5
26.5
27.5
15.2
15.2
15.1
15.3
15.4
15.7
4.6
15.5
14.9
15.1
15.1
14.9
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
7.2
7.2
7.2
7.2
7.2
7.2
5.5
5.5
5.5
5.5
5.5
5.5
20.9
20.9
20.9
20.9
20.9
20.9
23.4
23.4
23.4
23.4
23.4
23.4
18.7
17.5
17.6
17.9
18.3
18.7
10.3
7.9
5.0
5.0
5.1
5.2
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
22.0
22.2
22.3
22.7
23.2
23.7
22.3
14.9
14.5
14.5
14.5
14.5
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
4.6
4.6
4.6
4.6
4.6
4.6
3.6
3.6
3.6
3.6
3.6
3.6
11.1
11.1
11.1
11.1
11.1
11.1
28.7
28.7
28.7
28.7
28.7
28.7
18.7
17.5
17.6
17.9
18.3
18.7
10.3
7.9
5.0
5.0
5.1
5.2
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
22.4
22.7
22.8
23.1
23.7
24.2
22.6
15.3
15.0
15.0
15.0
15.0
40.3
40.3
40.3
40.3
40.3
40.3
43.8
43.8
43.8
43.8
43.8
43.8
22.3
22.4
22.3
22.5
22.9
23.4
18.8
19.5
19.0
19.2
19.1
19.1
31.5
31.5
31.5
31.5
31.5
31.5
35.2
35.2
35.2
35.2
35.2
35.2
9.1
9.2
9.3
9.6
9.8
10.1
11.7
10.8
10.5
10.6
10.6
10.6
46.9
46.9
46.9
46.9
46.9
46.9
52.5
52.5
52.5
52.5
52.5
52.5
21.5
23.0
24.0
24.4
25.1
25.8
19.8
21.9
21.9
22.1
22.3
22.6
40.3
40.3
40.3
40.3
40.3
40.3
43.8
43.8
43.8
43.8
43.8
43.8
-
-
-
-
-
-
6.8
-
-
-
-
-
-
-
-
-
-
-
28.6
-
-
-
-
-
-
-
-
-
-
-
0.1
-
-
-
-
-
-
-
-
-
-
-
34.9
-
-
-
-
-
-
-
-
-
-
-
6.6
-
-
-
-
-
-
-
-
-
-
-
24.6
-
-
-
-
-
-
-
-
-
-
-
-
23.0
22.2
22.3
22.5
22.8
25.7
25.7
25.7
25.7
25.7
25.7
-
28.5
28.5
28.5
28.5
28.5
4.9
-
-
-
-
-
-
-
-
-
-
-
27.0
-
-
-
-
-
-
-
-
-
-
-
-
9.8
9.8
9.9
10.0
10.1
-
4.3
3.5
3.5
3.5
3.6
-
27.0
27.0
27.0
27.0
27.0
-
30.3
30.3
30.3
30.3
30.3
-
6.7
6.7
6.7
6.7
6.7
-
1.3
3.0
3.0
3.0
3.0
-
27.0
27.0
27.0
27.0
27.0
-
30.3
30.3
30.3
30.3
30.3
21.5
23.0
24.0
24.4
25.1
25.8
19.7
21.8
21.9
22.1
22.3
22.6
40.3
40.3
40.3
40.3
40.3
40.3
43.8
43.8
43.8
43.8
43.8
43.8
22.6
22.9
23.0
23.4
23.9
24.5
23.0
15.3
15.0
15.0
14.9
15.0
29.4
29.4
29.4
29.4
29.4
29.4
32.7
32.7
32.7
32.7
32.7
32.7
6.6
6.6
6.6
6.6
6.6
6.6
2.0
2.0
2.0
2.0
2.0
2.0
11.1
11.1
11.1
11.1
11.1
11.1
28.7
28.7
28.7
28.7
28.7
28.7
20.8
21.0
21.0
21.3
21.7
22.2
18.3
16.9
16.6
16.5
16.5
16.5
40.3
40.3
40.3
40.3
40.3
40.3
43.8
43.8
43.8
43.8
43.8
43.8
7.7
7.8
7.8
7.9
8.1
8.3
6.6
6.3
6.1
6.1
6.0
6.1
20.0
20.0
20.0
20.0
20.0
20.0
24.6
25.0
25.0
25.0
25.0
25.0
7.9
7.9
7.9
8.1
8.3
8.5
-
6.4
6.2
6.1
6.1
6.2
25.7
25.7
25.7
25.7
25.7
25.7
-
6.4
6.2
6.1
6.1
6.2
Distribution and Transmission Annual Planning Report December 2013
76
3.18.3 STS and ZS load forecast
Port Stephens Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Tomago 132/33kV STS
Medowie 33/11kV ZS
Nelson Bay 33/11kV ZS
Raymond Terr NEW 33/11kV ZS
Raymond Terrace 33/11kV ZS
Salt Ash 33/11kV ZS
Stockton 33/11kV ZS
Tanilba Bay 33/11kV ZS
Tomago 33/11kV ZS
Tomaree 33/11kV ZS
Williamtown 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
137.2
66.0
65.6
73.6
52.0
11.6
40.0
38.8
66.0
66.0
45.3
137.2
66.0
68.6
73.6
53.2
12.7
40.0
40.5
66.0
66.0
49.8
91.5
38.0
45.7
38.1
35.4
0.0
20.0
18.7
38.0
38.0
24.8
91.5
38.0
45.7
38.1
35.4
0.0
20.0
18.8
38.0
38.0
25.6
91.5
45.6
54.9
42.6
39.7
10.0
22.4
18.7
42.5
45.6
29.7
91.5
43.4
54.9
45.7
42.5
10.0
24.0
18.8
45.6
39.6
26.5
13.8
2.9
2.9
11.2
11.2
2.9
11.2
2.9
11.2
2.9
2.9
5.0
3.5
3.5
5.0
5.0
3.5
5.0
3.5
3.5
3.5
3.5
2.01
1.41
0.21
0.53
0.74
0.09
0.93
1.22
6.45
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
SUMMER - Port Stephens Area STS and ZS Load Forecast
Substation
Tomago 132/33kV STS
Medowie 33/11kV ZS
Nelson Bay 33/11kV ZS
Raymond Terr NEW 33/11kV ZS
Raymond Terrace 33/11kV ZS
Salt Ash 33/11kV ZS
Stockton 33/11kV ZS
Tanilba Bay 33/11kV ZS
Tomago 33/11kV ZS
Tomaree 33/11kV ZS
Williamtown 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
136.7
147.0
135.4
99.1
127.8
133.0
131.8
133.1
135.2
138.1
141.3
0.95
0.98
0.98
0.98
0.93
0.93
0.93
0.93
0.93
0.93
0.92
14.8
15.0
15.1
15.5
16.0
16.5
0.94
0.94
0.94
0.94
0.94
0.94
44.8
45.7
43.4
31.9
28.5
25.5
25.7
25.7
26.0
26.4
26.9
0.95
0.98
0.97
0.97
0.98
0.98
0.98
0.98
0.98
0.98
0.98
20.0
21.1
22.8
19.5
19.6
20.0
20.5
21.0
0.96
0.95
0.96
0.96
0.96
0.96
0.96
0.96
36.4
38.0
39.4
15.2
15.0
0.95
0.98
0.92
0.96
0.97
2.8
2.4
2.3
1.9
2.7
0.95
0.98
0.94
0.93
0.86
7.5
7.6
7.8
6.1
8.2
7.7
7.9
8.1
8.4
8.8
9.2
0.95
0.98
0.94
0.95
0.96
0.96
0.96
0.96
0.96
0.96
0.96
7.7
8.4
8.9
6.2
8.6
9.9
9.9
9.9
10.0
10.2
10.5
0.95
0.98
0.99
0.99
0.90
0.89
0.89
0.89
0.88
0.88
0.88
4.1
20.8
22.2
23.2
23.6
24.2
24.9
0.93
0.95
0.95
0.95
0.95
0.95
0.95
16.3
16.3
16.2
16.4
16.6
16.9
1.00
1.00
1.00
1.00
0.99
0.99
17.4
17.0
19.6
13.3
16.2
3.1
3.1
3.2
3.3
3.4
3.5
0.95
0.98
0.93
0.93
0.94
0.94
0.94
0.94
0.94
0.94
0.94
WINTER - Port Stephens Area STS and ZS Load Forecast
Substation
Tomago 132/33kV STS
Medowie 33/11kV ZS
Nelson Bay 33/11kV ZS
Raymond Terr NEW 33/11kV ZS
Raymond Terrace 33/11kV ZS
Salt Ash 33/11kV ZS
Stockton 33/11kV ZS
Tanilba Bay 33/11kV ZS
Tomago 33/11kV ZS
Tomaree 33/11kV ZS
Williamtown 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
2008
2009
2010
138.6
108.0
106.3
0.96
0.98
0.99
42.9
40.4
36.8
0.96
0.98
0.99
29.7
27.4
31.5
0.96
0.98
0.94
2.7
1.9
1.9
0.96
0.98
0.96
6.8
6.0
5.9
0.96
0.98
0.96
9.2
7.5
7.7
0.96
0.98
1.00
15.4
13.1
12.8
0.96
0.98
0.98
2011
103.9
1.00
35.3
1.00
29.2
0.96
1.8
0.94
5.8
0.96
7.0
0.98
12.6
0.98
Distribution and Transmission Annual Planning Report December 2013
2012
102.6
0.99
36.6
0.98
16.5
0.97
13.3
0.97
5.7
0.97
5.6
0.97
7.1
0.90
2.6
0.87
11.8
0.97
2013
94.2
1.00
20.5
1.00
10.2
0.97
5.5
0.97
8.5
0.93
19.3
0.96
14.4
0.98
12.1
0.97
Forecast Load
2014
2015
2016
95.6
91.3
91.6
1.00
1.00
1.00
14.8
14.5
14.7
0.97
0.97
0.97
20.0
19.6
19.6
1.00
1.00
1.00
9.1
5.4
5.5
0.97
0.97
0.97
5.3
5.2
5.2
0.97
0.97
0.97
8.2
7.9
7.9
0.93
0.94
0.94
21.2
21.3
21.5
0.96
0.96
0.96
14.0
13.6
13.5
0.98
0.98
0.98
2.9
2.9
2.9
0.97
0.96
0.96
2017
91.9
1.00
14.8
0.97
19.6
1.00
5.6
0.97
5.2
0.97
7.9
0.94
21.7
0.96
13.5
0.98
2.9
0.96
2018
92.5
1.00
15.0
0.97
19.6
1.00
5.7
0.97
5.2
0.97
7.9
0.94
22.0
0.96
13.6
0.98
3.0
0.96
77
3.19
Singleton Load Load Area
3.19.1 Description of Singleton Load area
The Singleton network area extends from Liddell in the west and Westbrook to the north, through to Branxton in the
east and south to the Putty Valley. The area is very diverse and includes residential customers, light to heavy
industry, coal mining, agriculture, a number of vineyards and wineries, as well as dairy and beef farms and several
horse studs. There are a number of residential developments to the north of Singleton. and there is also likely to be
increasing industrial activity in the Whittingham area south-east of Singleton.
The principal developed areas are clustered around the New England Highway and rail network, with the main
township of Singleton centrally located. There are many smaller rural communities around Singleton, including
Bulga, Branxton, Greta, Broke, Jerry’s Plains, Putty Valley, Belford, Elderslie, Mitchell’s Flat and Glendon Brook.
The network in the Singleton area:

is supplied from the Singleton 132/66kV STS and the Liddell 33kV Switching Station at Liddell Power Station

has an expansive 66kV sub-transmission system comprising two closed ring networks

includes a 66kV interconnection to Kurri STS via Branxton zone substation

includes a smaller 33kV network supplied from Macquarie Generation auxiliary 33kV supply at Liddell, which
supplies a number of mining operations and conveyors

includes eight 66/11kV zone substations and a number of Ausgrid-owned switching station sites on the Liddell
33kV network

has over twenty 66kV and 33kV connected mining customers.
Figure 22: Singleton Load Area
Table 20 – Identified system limitations in Singleton load area
Location
Identified Limitation
Refer to
DAPR section
1.
Branxton 66/11kV ZS
Asset Condition
5.3.20
2.
Singleton 66/11kV ZS
Asset Condition
5.3.20
Distribution and Transmission Annual Planning Report December 2013
78
3.19.2 Sub-transmission feeder load forecast
Singleton Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
Feeder 33474 (Singleton
ZS to Singleton North)
66 Rating
Feeder 6011(1)
(Singleton STS to
Lemington ZS)
66 Rating
Feeder 6011(2)
(tee to Lemington Mine)
66 Rating
Feeder 6011(3)
(Singleton STS to
Lemington ZS)
66 Rating
Feeder 6011(4)
(tee to Wambo Mine)
Feeder 6011(5)
(Singleton STS to
Lemington ZS)
Feeder 6011(6)
(tee to United Colliery)
Feeder 6011(7)
(Singleton STS to
Lemington ZS)
Feeder 6011(8)
(tee to Wambo Mine)
Load
Load
Load
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Feeder 6011(9)
(tee to South Lemington
Mine)
66 Rating
Feeder 6011(10)
(tee to South Lemington
Mine)
66 Rating
Feeder 6012(1)
(Singleton STS to
Singleton North ZS)
66 Rating
Feeder 6012(2)
(tee to Rix's Creek Coal)
66 Rating
Feeder 6012(3)
(Singleton STS to
Singleton North ZS)
66 Rating
Feeder 6012(4)
(tee to Camberwell and
Glennies Creek)
66 Rating
Feeder 6012(5)
(tee to Camberwell Coal)
Feeder 6012(6) (tee to
Glennies Creek)
Feeder 6012(9)
(Singleton STS to
Singleton North ZS)
Feeder 6017(1)
(Singleton STS to
Newdell ZS)
Feeder 6017(2)
(tee to Ashton Mine)
Feeder 6017(3)
(Singleton STS to
Newdell ZS)
Feeder 6017(4)
(tee to Glendell Mine)
Feeder 6017(5)
(Singleton STS to
Newdell ZS)
Load
Load
Load
Load
Load
Load
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
66 Rating
Feeder 6018(1)
(Singleton STS to Mt
Thorley ZS)
66 Rating
Feeder 6018(2)
(Singleton STS to Mt
Thorley ZS)
66 Rating
Feeder 6018(3)
(Singleton STS to Mt
Thorley ZS)
66 Rating
Load
Load
Load
2013
2014
Winter (MVA)
2015
2016
2017
2018
21.7
21.9
22.0
22.2
22.5
22.8
21.3
21.3
21.5
21.5
21.5
21.6
83.0
83.0
83.0
83.0
83.0
83.0
112.0
112.0
112.0
112.0
112.0
112.0
37.8
51.8
71.8
71.8
71.8
71.8
40.4
48.0
78.9
78.9
78.9
78.9
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
6.2
6.2
6.2
6.2
6.2
6.2
6.2
6.2
6.2
6.2
6.2
6.2
15.0
15.0
15.0
15.0
15.0
15.0
38.3
38.3
38.3
38.3
38.3
38.3
34.5
48.0
67.0
67.0
67.0
67.0
35.3
42.5
71.8
71.9
71.8
71.9
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
12.0
12.0
12.0
12.0
12.0
12.0
15.4
15.4
15.4
15.4
15.4
15.4
37.0
37.0
37.0
37.0
37.0
37.0
48.6
48.6
48.6
48.6
48.6
48.6
22.4
35.9
54.7
54.7
54.7
54.7
19.7
27.0
56.0
56.0
56.0
56.0
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
0.6
13.6
13.6
13.6
13.6
13.6
0.6
0.6
13.6
13.6
13.6
13.6
42.1
42.1
42.1
42.1
42.1
42.1
55.0
55.0
55.0
55.0
55.0
55.0
22.0
27.4
46.0
46.0
46.0
46.0
19.3
26.4
45.1
45.1
45.1
45.1
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
18.8
18.8
18.8
18.8
18.8
18.8
18.4
18.4
18.4
18.4
18.4
18.4
42.1
42.1
42.1
42.1
42.1
42.1
55.0
55.0
55.0
55.0
55.0
55.0
0.2
0.2
0.2
0.2
0.2
0.2
0.0
0.0
0.0
0.0
0.0
0.0
40.0
40.0
40.0
40.0
40.0
40.0
51.2
51.2
51.2
51.2
51.2
51.2
0.2
0.2
0.2
0.2
0.2
0.2
0.0
0.0
0.0
0.0
0.0
0.0
39.1
39.1
39.1
39.1
39.1
39.1
51.2
51.2
51.2
51.2
51.2
51.2
46.3
46.6
46.8
47.1
47.7
48.3
42.7
42.8
43.2
43.4
43.6
44.0
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
3.5
3.5
3.5
3.5
3.5
3.5
3.4
3.4
3.4
3.4
3.4
3.4
42.1
42.1
42.1
42.1
42.1
42.1
55.0
55.0
55.0
55.0
55.0
55.0
43.3
43.6
43.7
44.1
44.7
45.2
40.0
40.0
40.5
40.6
40.8
41.2
94.0
94.0
94.0
94.0
94.0
94.0
127.0
127.0
127.0
127.0
127.0
127.0
9.5
9.5
9.5
9.5
9.5
9.5
11.0
11.0
11.0
11.0
11.0
11.0
39.1
39.1
39.1
39.1
39.1
39.1
51.2
51.2
51.2
51.2
51.2
51.2
6.5
6.5
6.5
6.5
6.5
6.5
6.3
6.3
6.3
6.3
6.3
6.3
39.1
39.1
39.1
39.1
39.1
39.1
51.2
51.2
51.2
51.2
51.2
51.2
10.5
10.5
10.5
10.5
10.5
10.5
12.0
12.0
12.0
12.0
12.0
12.0
34.3
34.3
34.3
34.3
34.3
34.3
48.1
48.1
48.1
48.1
48.1
48.1
34.4
34.7
34.8
35.1
35.7
36.3
30.1
30.1
30.6
30.7
30.9
31.2
83.1
83.1
83.1
83.1
83.1
83.1
112.0
112.0
112.0
112.0
112.0
112.0
28.4
33.8
52.2
52.2
52.2
52.2
26.6
33.8
52.1
52.1
52.1
52.2
83.0
83.0
83.0
83.0
83.0
83.0
112.0
112.0
112.0
112.0
112.0
112.0
11.8
11.8
11.8
11.8
11.8
11.8
11.4
11.4
11.4
11.4
11.4
11.4
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
22.0
27.3
45.0
44.9
44.9
44.9
19.3
26.3
43.9
43.9
43.9
44.1
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
0.4
0.4
0.4
0.4
0.4
0.4
0.4
0.4
0.4
0.4
0.4
0.4
72.0
72.0
72.0
72.0
72.0
72.0
89.7
89.7
89.7
89.7
89.7
89.7
21.8
27.0
44.5
44.5
44.5
44.4
19.1
26.0
43.4
43.5
43.5
43.6
127.0
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
53.6
54.1
54.3
54.6
55.2
55.7
56.8
56.9
57.6
57.8
58.0
58.4
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
53.6
54.1
54.3
54.6
55.2
55.7
56.8
56.9
57.6
57.8
58.0
58.4
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
53.6
54.1
54.3
54.6
55.2
55.7
56.8
56.9
57.6
57.8
58.0
58.4
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
Distribution and Transmission Annual Planning Report December 2013
79
Singleton Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
Feeder 6019 (Singleton
STS to Mt Thorley ZS)
66 Rating
Feeder 60208(1)
(Newdell ZS to
Lemington ZS)
66 Rating
Feeder 60208(2) (tee to
Newdell Mine)
66 Rating
Feeder 60208(3)
(Newdell ZS to
Lemington ZS)
66 Rating
Feeder 60208(4)
(Newdell ZS to
Lemington ZS)
Load
Load
Load
Load
66 Rating
Feeder 60208(6)
(Newdell ZS to
Lemington ZS)
66 Rating
Feeder 60208(7)
(tee to Hunter Valley
CPP)
66 Rating
Feeder 60208(8)
(Newdell ZS to
Lemington ZS)( )
66 Rating
(Singleton ZS to Mt
Thorley ZS and Branxton
ZS)
66 Rating
Feeder 66011(2)
(Singleton ZS to
Braxnton ZS)
Load
Load
Load
Load
Load
66 Rating
Load
Feeder 66011(3)
(tee to Mitchells Flat ZS)
66 Rating
Feeder 66011(4)
(Singleton ZS to
Branxton ZS)
66 Rating
Feeder 66011(5)
(Singleton ZS to Mt
Thorley ZS)
66 Rating
Feeder 66011(6)
(tee to Bulga Coal)
66 Rating
Feeder 66011(7)
(tee to Bulga Coal)
Load
Load
Load
Load
66 Rating
Feeder 66011(9)
(Singleton ZS to Mt
Thorley ZS)
66 Rating
Feeder 66011(10)
(Singleton ZS to Mt
Thorley ZS)
66 Rating
Feeder 66090(1)
(Mt Thorley ZS to
Warkworth Mine)
66 Rating
Feeder 66090(2)
(Mt Thorley ZS to
Warkworth Mine)
66 Rating
Feeder 66092(1)
(Mt Thorley ZS to Mt
Thorley Mine)
Load
Load
Load
Load
Load
66 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
53.1
53.6
53.8
54.1
54.6
55.1
56.2
56.2
57.1
57.2
57.4
57.8
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
14.1
14.1
29.8
29.8
29.8
29.8
13.3
13.4
29.6
29.6
29.6
29.6
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
21.1
21.1
21.1
21.1
21.1
21.1
62.0
62.0
62.0
62.0
62.0
62.0
13.2
18.4
36.0
36.0
36.0
36.0
10.9
17.8
35.4
35.4
35.4
35.4
88.4
88.4
88.4
88.4
88.4
88.4
120.0
120.0
120.0
120.0
120.0
120.0
13.2
18.4
36.0
36.0
36.0
36.0
10.9
17.8
35.4
35.4
35.4
35.4
88.4
88.4
88.4
88.4
88.4
88.4
120.0
120.0
120.0
120.0
120.0
120.0
14.1
14.1
29.8
29.8
29.8
29.8
13.3
13.4
29.6
29.6
29.6
29.6
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
8.6
21.1
21.1
21.1
21.1
21.1
21.1
62.0
62.0
62.0
62.0
62.0
62.0
20.5
25.8
43.9
43.9
43.9
43.9
18.7
25.7
43.8
43.8
43.8
43.8
93.6
93.6
93.6
93.6
93.6
93.6
127.0
127.0
127.0
127.0
127.0
127.0
31.6
31.7
31.8
32.1
32.7
33.2
23.6
24.1
24.1
24.3
24.6
25.3
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
9.8
10.0
10.1
10.3
10.6
10.9
5.9
5.3
5.7
5.6
5.5
5.5
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
1.5
1.5
1.4
1.5
1.5
1.5
0.9
0.9
0.8
0.8
0.8
0.8
6.4
6.4
6.4
6.4
6.4
6.4
7.3
7.3
7.3
7.3
7.3
7.3
11.1
11.3
11.5
11.7
12.1
12.5
6.1
5.5
5.4
5.3
5.2
5.1
42.1
42.1
42.1
42.1
42.1
42.1
55.0
55.0
55.0
55.0
55.0
55.0
41.2
41.5
41.8
42.3
43.1
44.0
28.3
28.3
29.2
29.3
29.5
30.2
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
32.9
32.9
32.9
32.9
32.9
32.9
34.8
34.8
34.8
34.8
34.8
34.8
39.1
39.1
39.1
39.1
39.1
39.1
51.3
51.3
51.3
51.3
51.3
51.3
32.9
32.9
32.9
32.9
32.9
32.9
34.8
34.8
34.8
34.8
34.8
34.8
39.1
39.1
39.1
39.1
39.1
39.1
51.3
51.3
51.3
51.3
51.3
51.3
62.8
63.0
63.4
63.9
64.8
65.7
57.0
56.9
57.5
57.6
57.9
58.4
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
62.8
63.0
63.4
63.9
64.8
65.7
57.0
56.9
57.5
57.6
57.9
58.4
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
24.6
24.6
24.6
24.6
24.6
24.6
24.3
24.3
24.3
24.3
24.3
24.3
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
24.6
24.6
24.6
24.6
24.6
24.6
24.3
24.3
24.3
24.3
24.3
24.3
93.7
93.7
93.7
93.7
93.7
93.7
127.3
127.3
127.3
127.3
127.3
127.3
9.2
9.2
9.2
9.2
9.2
9.2
9.4
9.4
9.4
9.4
9.4
9.4
15.0
15.0
15.0
15.0
15.0
15.0
38.3
38.3
38.3
38.3
38.3
38.3
9.2
9.2
9.2
9.2
9.2
9.2
9.4
9.4
9.4
9.4
9.4
9.4
15.0
15.0
15.0
15.0
15.0
15.0
38.3
38.3
38.3
38.3
38.3
38.3
Feeder 66092(3)
(Mt Thorley ZS to Mt
Thorley Mine)
66 Rating
Feeder KU12(1)
(Kurri STS to Branxton
ZS)
12.0
12.0
12.0
12.0
12.0
12.0
15.4
15.4
15.4
15.4
15.4
15.4
66 Rating
37.0
37.0
37.0
37.0
37.0
37.0
48.6
48.6
48.6
48.6
48.6
48.6
Feeder 60200
Load
(Newdell ZS to
Ravensworth North Mine) 66 Rating
5.0
11.0
31.3
31.3
31.3
31.3
-
11.0
31.3
31.3
31.3
31.3
93.0
93.0
93.0
93.0
93.0
93.0
-
127.0
127.0
127.0
127.0
127.0
Load
Load
Distribution and Transmission Annual Planning Report December 2013
80
3.19.3 STS and ZS load forecast
Summer
Winter
Summer
Winter
Solar
PV
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Singleton 132/66kV STS
Branxton 66/11kV ZS
Lemington 66/11kV ZS
Mitchells Flat 66/11kV ZS
Mt Thorley 66/11kV ZS
Newdell 66/11kV ZS
Singleton 66/11kV ZS
Singleton North 66/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
405.7
28.9
32.4
6.0
35.2
53.7
45.7
76.2
446.2
30.5
35.6
6.7
35.2
58.0
45.7
76.2
284.4
15.1
13.4
0.0
20.3
26.8
22.9
38.1
300.7
15.2
14.7
0.0
20.3
29.0
22.9
38.1
284.4
16.8
10.0
5.3
24.3
29.4
25.6
45.7
300.7
18.3
10.0
5.8
20.4
30.7
27.4
40.1
8.6
13.8
2.9
2.9
2.9
13.8
11.2
2.4
4.8
3.5
3.5
3.5
22.2
22.2
5.0
3.5
1.03
0.02
0.12
0.42
0.03
0.64
1.02
Identified
Limitation
in next 5
years
151.00
No
No
No
No
No
No
No
12.80
No
Other
Singleton Area - STS and ZS details
SUMMER - Singleton Area STS and ZS Load Forecast
Substation
MVA
PF
MVA
PF
Branxton 66/11kV ZS
MVA
PF
Lemington 66/11kV ZS
MVA
PF
Mitchells Flat 66/11kV ZS
MVA
PF
Mt Thorley 66/11kV ZS
MVA
PF
Newdell 66/11kV ZS
MVA
PF
Singleton 66/11kV ZS
MVA
Singleton North 66/11kV ZS PF
Singleton 132/66kV STS
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
136.2
150.9
139.2
134.5
153.1
145.2
159.8
180.0
180.6
181.7
182.8
0.93
0.96
0.96
0.93
0.95
0.95
0.95
0.94
0.94
0.94
0.94
12.1
12.7
13.6
9.6
13.5
10.9
11.1
11.3
11.5
11.9
12.2
0.93
0.96
0.96
0.97
0.95
0.95
0.95
0.95
0.95
0.95
0.95
3.2
3.2
3.1
2.4
2.9
2.9
2.9
2.9
2.9
2.9
2.9
0.93
0.96
0.90
0.91
0.92
0.92
0.92
0.92
0.92
0.92
0.92
1.4
1.4
1.4
0.9
1.3
1.4
1.4
1.4
1.4
1.5
1.5
0.93
0.96
0.97
0.99
0.98
0.98
0.98
0.98
0.98
0.98
0.98
8.8
9.9
10.2
7.5
9.3
9.6
10.3
10.4
10.6
10.8
11.1
0.93
0.96
0.92
0.92
0.93
0.93
0.93
0.93
0.93
0.93
0.93
8.5
9.0
12.6
7.7
9.8
4.8
4.8
4.8
4.8
4.8
4.8
0.93
0.96
0.90
0.92
0.91
0.91
0.91
0.91
0.91
0.91
0.91
23.7
23.2
21.7
16.3
20.3
21.9
22.0
22.0
22.2
22.6
22.9
0.93
0.96
0.91
0.90
0.91
0.91
0.91
0.91
0.91
0.91
0.91
15.4
16.6
18.5
13.4
17.6
19.3
19.4
19.5
19.7
20.0
20.4
0.93
0.96
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
WINTER - Singleton Area STS and ZS Load Forecast
Substation
MVA
PF
Singleton 132/66kV STS
MVA
PF
Branxton 66/11kV ZS
MVA
PF
Lemington 66/11kV ZS
MVA
PF
Mitchells Flat 66/11kV ZS
MVA
PF
Mt Thorley 66/11kV ZS
MVA
PF
Newdell 66/11kV ZS
MVA
PF
Singleton 66/11kV ZS
MVA
Singleton North 66/11kV ZS PF
2008
144.8
0.96
9.9
0.96
2.3
0.96
1.1
0.96
6.9
0.96
8.3
0.96
16.2
0.96
13.2
0.96
Actual Load
2009
2010
2011
147.9
156.7
121.2
0.96
0.93
0.96
9.2
9.1
8.5
0.96
0.96
1.00
2.6
1.8
2.0
0.96
0.95
0.91
1.0
1.0
0.9
0.96
1.00
1.00
7.0
6.9
7.6
0.96
0.96
0.96
8.8
9.0
9.0
0.96
0.92
0.93
15.7
13.9
13.2
0.96
0.94
0.94
11.7
13.1
12.0
0.96
0.99
0.99
Distribution and Transmission Annual Planning Report December 2013
2012
138.7
0.97
9.3
0.98
2.0
0.94
0.9
1.00
7.3
0.94
8.7
0.94
13.5
0.95
12.4
0.96
2013
142.0
0.97
6.0
0.98
1.8
0.94
0.9
1.00
7.1
0.94
9.0
0.94
12.4
0.95
14.4
0.96
2014
145.6
0.97
5.5
0.98
1.8
0.94
0.9
1.00
7.2
0.94
5.0
0.94
12.8
0.95
14.4
0.96
Forecast Load
2015
2016
175.8
176.1
0.97
0.97
5.3
5.2
0.98
0.98
1.8
1.8
0.94
0.94
0.8
0.8
1.00
1.00
7.7
7.9
0.94
0.94
5.0
5.0
0.94
0.94
12.9
13.0
0.95
0.95
14.5
14.7
0.96
0.96
2017
176.5
0.97
5.1
0.98
1.8
0.94
0.8
1.00
8.1
0.94
5.0
0.94
13.2
0.95
14.9
0.96
2018
177.2
0.97
5.1
0.98
1.8
0.94
0.8
1.00
8.4
0.94
5.0
0.94
13.4
0.95
15.2
0.96
81
3.20
St George Load Area
3.20.1 Description of St George load area
The St George network area extends west from Arncliffe and Sans Souci on Botany Bay, and inland to Peakhurst.
This is a predominantly urban area that includes high density residential developments and commercial areas such
as the Hurstville retail district. Population growth continues to drive load growth along the rail corridor. The East
Hills and Illawarra railway lines and Princes Highway pass through the area. There are limited opportunities for
connection with other areas of the network because of various geographic, network and physical features of the
area, including water, transport infrastructure and customer load control frequencies.
The network in the St George area:

is supplied from Peakhurst sub-transmission substation via two 132kV feeders from TransGrid’s transmission
system at Sydney South Bulk Supply Point

Includes six 33/11kV zone substations and two 132/11kV zone substations, and

is traversed by 132kV XLPE cables from Peakhurst to Canterbury and Beaconsfield West.
Figure 23: St George load area
Distribution and Transmission Annual Planning Report December 2013
82
Table 21 – Identified system limitations in St George load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Arncliffe ZS
Asset Condition
5.3.8
2.
Rockdale ZS
Asset Condition
5.3.8
3.
Peakhurst STS
Asset Condition
5.3.8
4.
Feeders 775 & 776 - Peakhurst STS to Rockdale ZS
Asset Condition
5.2.8
5.
Feeder 769 (Peakhurst STS to Blakehurst ZS)
Capacity
5.2.8
6.
Feeder 770 (Peakhurst STS to Blakehurst ZS)
Capacity
5.2.8
3.20.2 Sub-transmission feeder load forecast
St George Area - Feeder Load Forecast
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder name
Feeder 670
Load
15.0
15.0
15.1
15.5
16.1
16.7
(Peakhurst STS to
34.3
34.3
34.3
34.3
34.3
34.3
Riverwood ZS)
33 Rating
Feeder 706
Load
16.8
17.0
17.2
17.9
18.8
19.7
(Peakhurst STS to Sans
Rating
26.9
26.9
26.9
26.9
26.9
26.9
Souci ZS)
33
Feeder 708
Load
10.6
(Peakhurst STS to
28.5
Hurstville North ZS)
33 Rating
Feeder 765
Load
28.9
29.3
29.5
30.7
32.1
33.6
(Peakhurst STS to
35.4
35.4
35.4
35.4
35.4
35.4
Mortdale ZS)
33 Rating
Feeder 767
Load
23.3
22.7
21.8
21.6
21.5
21.8
(Peakhurst STS to
36.1
36.1
36.1
36.1
36.1
36.1
Arncliffe ZS)
33 Rating
Feeder 768
Load
23.5
(Peakhurst STS to
36.1
768tee)
33 Rating
Feeder 768
(768tee to Arncliffe ZS)
Feeder 769
(Peakhurst STS to
Blakehurst ZS)
Feeder 770
(Peakhurst STS to
Blakehurst ZS)
Feeder 774
(Peakhurst STS to
Hurstville North ZS)
Feeder 775
(Peakhurst STS to
Rockdale ZS)
Feeder 776
(Peakhurst STS to
Rockdale ZS)
Feeder 777
(Blakehurst to Sans
Souci ZS)
Feeder 778
(Peakhurst STS to
Riverwood ZS)
Feeder 779
(Peakhurst STS to
Riverwood ZS)
Feeder 785
(Peakhurst STS to
Mortdale ZS)
Feeder 786
(Peakhurst STS to
Mortdale ZS)
Feeder 768
(Peakhurst STS to
Arncliffe ZS)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Winter (MVA)
2013
2014
2015
2016
2017
12.7
12.1
11.7
11.8
11.8
2018
12.0
37.2
37.2
37.2
37.2
37.2
37.2
16.8
16.6
16.5
16.8
17.4
18.1
28.6
28.6
28.6
28.6
28.6
28.6
16.7
8.2
-
-
-
-
28.6
28.6
-
-
-
-
24.5
24.1
23.2
23.2
23.5
23.8
37.3
37.3
37.3
37.3
37.3
37.3
22.3
23.2
22.6
22.7
22.7
23.2
44.3
44.3
44.3
44.3
44.3
44.3
22.1
23.1
-
-
-
-
44.3
44.3
-
-
-
-
22.8
-
-
-
-
-
21.6
22.5
-
-
-
-
36.1
-
-
-
-
-
44.3
44.3
-
-
-
-
23.1
23.6
24.0
25.2
26.6
28.0
19.7
19.3
18.9
19.2
19.6
20.1
26.9
26.9
26.9
26.9
26.9
26.9
28.3
28.3
28.3
28.3
28.3
28.3
23.1
23.6
24.0
25.2
26.6
28.0
19.7
19.3
18.9
19.2
19.6
20.1
26.8
26.8
26.8
26.8
26.8
26.8
28.2
28.2
28.2
28.2
28.2
28.2
10.6
-
-
-
-
-
16.7
8.2
-
-
-
-
28.4
-
-
-
-
-
28.6
28.6
-
-
-
-
20.2
21.3
20.9
21.0
21.4
21.6
17.1
16.6
17.6
17.7
17.9
18.1
27.0
27.0
27.0
27.0
27.0
27.0
28.6
28.6
28.6
28.6
28.6
28.6
20.2
21.3
20.9
21.0
21.4
21.7
17.1
16.6
17.6
17.7
17.9
18.1
27.0
27.0
27.0
27.0
27.0
27.0
28.0
28.0
28.0
28.0
28.0
28.0
16.2
16.5
16.6
17.3
18.1
18.9
16.2
16.2
15.9
16.4
16.9
17.5
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
15.0
15.0
15.1
15.5
16.1
16.7
12.7
12.1
11.7
11.8
11.8
12.0
34.3
34.3
34.3
34.3
34.3
34.3
37.2
37.2
37.2
37.2
37.2
37.2
15.0
15.0
15.1
15.5
16.1
16.7
12.7
12.0
11.7
11.7
11.8
12.0
34.3
34.3
34.3
34.3
34.3
34.3
37.2
37.2
37.2
37.2
37.2
37.2
22.3
22.6
22.8
23.7
24.8
25.8
19.1
18.7
18.1
18.2
18.3
18.5
35.4
35.4
35.4
35.4
35.4
35.4
37.3
37.3
37.3
37.3
37.3
37.3
28.9
29.2
29.6
30.7
32.2
33.6
24.7
24.1
23.3
23.4
23.5
23.8
35.4
35.4
35.4
35.4
35.4
35.4
37.3
37.3
37.3
37.3
37.3
37.3
-
22.6
21.8
21.7
21.6
21.7
-
-
22.5
22.5
22.8
22.9
-
33.5
33.5
33.5
33.5
33.5
-
-
40.6
40.6
40.6
40.6
Distribution and Transmission Annual Planning Report December 2013
83
3.20.3 STS and ZS load forecast
St George Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Peakhurst 132/33kV STS
Arncliffe 33/11kV ZS
Blakehurst 33/11kV ZS
Hurstville North 132/11kV ZS
Hurstville North 33/11kV ZS
Kogarah 132/11kV ZS
Mortdale 33/11kV ZS
Riverwood 33/11kV ZS
Rockdale 33/11kV ZS
Sans Souci 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
349.8
60.6
47.4
124.6
67.6
170.8
114.3
65.7
58.0
49.9
349.8
62.4
47.4
124.6
67.6
170.8
114.3
65.7
60.3
52.5
233.2
39.1
31.6
62.2
41.7
114.3
64.3
42.8
27.1
26.9
233.2
42.9
31.6
65.0
42.0
114.3
70.7
42.8
27.1
26.9
233.2
43.4
31.6
69.2
41.7
127.7
64.3
42.8
27.1
26.9
233.2
46.8
31.6
78.0
42.0
120.6
70.7
42.8
27.1
26.9
2.9
11.2
2.9
13.8
13.8
11.2
2.9
2.9
11.2
2.9
5.0
5.0
3.5
5.0
5.0
5.0
3.5
3.5
5.0
3.5
0.58
0.83
0.68
2.20
1.97
1.55
0.38
0.44
1.26
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
SUMMER - St George Area STS and ZS Load Forecast
Substation
Peakhurst 132/33kV STS
Arncliffe 33/11kV ZS
Blakehurst 33/11kV ZS
Carlton 33/11kV ZS
Hurstville North 132/11kV ZS
Hurstville North 33/11kV ZS
Kogarah 132/11kV ZS
Mortdale 33/11kV ZS
Riverwood 33/11kV ZS
Rockdale 33/11kV ZS
Sans Souci 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
213.3
232.8
180.4
141.4
159.9
162.2
155.5
155.8
160.3
166.3
171.9
0.96
0.99
0.99
0.90
0.98
1.00
1.00
1.00
1.00
0.99
0.99
24.6
25.0
21.9
18.5
21.5
21.1
20.5
19.8
19.7
19.8
19.8
0.96
0.99
0.90
0.90
0.91
0.91
0.91
0.91
0.91
0.91
0.91
26.1
28.9
25.1
18.6
20.7
22.0
22.5
22.9
23.9
25.2
26.4
0.96
0.99
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
42.9
41.6
0.96
0.99
11.3
20.7
20.3
20.4
20.7
20.9
0.99
0.99
0.99
0.99
0.99
0.99
29.8
30.8
26.4
19.6
20.3
10.4
0.96
0.99
0.92
0.92
0.92
0.92
35.9
76.6
71.1
75.0
76.4
76.3
76.2
78.1
80.7
83.0
0.91
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
45.7
47.5
53.4
33.9
46.3
48.3
48.8
49.3
51.0
53.3
55.4
0.96
0.99
0.90
0.89
0.96
0.96
0.96
0.96
0.96
0.96
0.96
28.6
29.1
32.2
24.6
28.5
28.5
28.6
28.7
29.5
30.6
31.6
0.96
0.99
0.87
0.87
0.87
0.87
0.87
0.87
0.87
0.87
0.87
24.9
24.4
15.6
14.6
15.6
19.6
20.6
20.2
20.4
20.7
21.0
0.96
0.99
0.89
0.89
0.90
0.90
0.90
0.90
0.90
0.90
0.90
24.5
26.3
16.9
14.0
15.5
15.6
15.8
16.0
16.6
17.4
18.1
0.96
0.99
0.92
0.89
0.92
0.92
0.92
0.92
0.92
0.92
0.92
WINTER - St George Area STS and ZS Load Forecast
Substation
Peakhurst 132/33kV STS
Arncliffe 33/11kV ZS
Blakehurst 33/11kV ZS
Carlton 33/11kV ZS
Hurstville North 132/11kV ZS
Hurstville North 33/11kV ZS
Kogarah 132/11kV ZS
Mortdale 33/11kV ZS
Riverwood 33/11kV ZS
Rockdale 33/11kV ZS
Sans Souci 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
2008
2009
2010
264.2
233.9
185.1
0.98
0.99
1.00
29.5
25.5
22.4
0.98
0.99
0.93
29.4
28.9
22.3
0.98
0.99
0.95
42.2
42.0
0.98
0.99
28.0
22.9
27.5
0.98
0.99
0.96
59.0
0.90
52.4
42.5
54.2
0.98
0.99
0.93
29.6
26.7
25.2
0.98
0.99
0.95
24.2
21.8
22.0
0.98
0.99
0.92
29.8
26.3
18.7
0.98
0.99
0.95
2011
161.9
1.00
20.4
0.93
21.7
0.95
19.0
0.96
70.5
0.90
45.6
0.93
26.2
0.96
13.1
0.93
16.0
0.95
Distribution and Transmission Annual Planning Report December 2013
2012
141.9
1.00
18.9
0.93
18.1
0.96
16.1
0.95
65.3
0.90
41.4
0.98
23.2
0.96
12.8
0.93
15.2
0.95
2013
152.6
1.00
20.3
0.93
19.0
0.96
16.3
0.95
69.2
0.90
42.2
0.98
24.7
0.96
16.7
0.93
15.7
0.95
Forecast Load
2014
2015
2016
143.0
133.6
134.6
1.00
1.00
1.00
21.2
20.5
20.6
0.93
0.93
0.93
18.7
18.3
18.6
0.96
0.96
0.96
8.8
16.6
17.0
1.00
0.99
0.99
8.1
0.95
69.2
69.2
71.6
0.90
0.90
0.90
41.2
40.0
40.1
0.98
0.98
0.98
23.6
22.8
22.9
0.96
0.96
0.96
16.3
17.2
17.3
0.93
0.93
0.93
15.6
15.5
15.9
0.95
0.95
0.95
2017
135.8
1.00
20.8
0.93
18.9
0.96
17.5
0.99
74.2
0.90
40.3
0.98
23.1
0.96
17.4
0.93
16.3
0.95
2018
138.2
1.00
21.0
0.93
19.4
0.96
17.9
1.00
77.5
0.90
40.8
0.98
23.3
0.96
17.7
0.93
16.9
0.95
84
3.21
Sutherland Load Area
3.21.1 Description of Sutherland load area
The Sutherland network area extends from the Kurnell Peninsula in the north-east, along the southern side of
Botany Bay and the Georges River, south as far as Waterfall and east towards the coast. It serves a mixture of
residential, commercial and industrial areas.
The network in the Sutherland area:

is supplied from TransGrid’s bulk supply point at Sydney South, via two double circuit 132kV tower lines

includes six 33/11kV zone substations supplied from 132/33kV sub-transmission substations (STS) at Port
Hacking and Kurnell, together with three 132/11kV and one 132/33/11kV zone substations

consists mainly of overhead lines, operating at 132kV and 33kV

is exposed to a marine atmosphere in some places due to its proximity to the ocean (especially feeders 916
and 917)

has connections at 33kV to two landfill gas generators at Lucas Heights

supplies Sydney Trains at Heathcote and Port Hacking, ANSTO at Lucas Heights, Caltex oil refinery, Sydney
Water Desalination Plant at Kurnell, and Sydney Water at Woronora Dam, and

includes the ability to provide a 132kV back up supply to Endeavour Energy at Bellambi in the south.
Figure 24: Sutherland load area
Table 22 – Identified system limitations in Sutherland load area
Location
1.
Kurnell STS
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
Refer to
DAPR section
Asset Condition
5.3.9
85
3.21.2 Sub-transmission feeder load forecast
Sutherland Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder 280
(Port Hacking STS to
Kirrawee ZS)
132 Rating
Feeder 281
(Cronulla ZS to Kirrawee
ZS)
132 Rating
Feeder 284
(Sydney South BSP to
Menai ZS)
132 Rating
Feeder 285
(Port Hacking STS to
285tee)
132 Rating
Load
Load
Load
Load
Load
Feeder 285
(Menai ZS to 285tee)
132 Rating
Feeder 285
(285tee to RAC
Heathcote)
132 Rating
Load
Feeder 724
(Port Hacking STS to
Miranda ZS)
33 Rating
Feeder 725
(Port Hacking STS to
Gwawley Bay ZS)
33 Rating
Feeder 726
(Port Hacking STS to
Miranda ZS)
Feeder 728
(Port Hacking STS to
Caringbah ZS)
Feeder 730
(Port Hacking STS to
Jannali ZS)
Feeder 731
(Engadine ZS to
Woronora Dam)
Feeder 738
(Port Hacking STS to
Jannali ZS)
Feeder 739
(Kurnell STS to Kurnell
ZS)
Feeder 740
(Kurnell STS to Kurnell
ZS)
Feeder 741
(Kurnell STS to Kurnell
ZS)
Feeder 742
(Kurnell STS to Kurnell
ZS)
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Feeder 745
(Kurnell to Caringbah
ZS)
33 Rating
Feeder 747
(Port Hacking STS to
Engadine ZS)
33 Rating
Load
Load
Load
Feeder 749/1
(Jannali ZS to 749tee)
33 Rating
Feeder 749/2 (749tee to
Lucas Heights)
33 Rating
Load
Feeder 749/3
(749tee to Lucas
Heights generator)
33 Rating
Feeder 750/1 (Miranda
ZS to 750tee)
33 Rating
Load
Load
2013
2014
Winter (MVA)
2015
2016
2017
2018
76.7
78.0
78.4
81.0
84.5
87.8
92.0
90.6
88.3
88.6
89.2
90.4
260.0
260.0
260.0
260.0
260.0
260.0
283.7
283.7
283.7
283.7
283.7
283.7
40.6
42.0
42.6
44.5
46.8
49.1
53.8
53.1
52.0
52.2
52.5
53.2
275.0
275.0
275.0
275.0
275.0
275.0
340.4
340.4
340.4
340.4
340.4
340.4
150.5
148.0
147.4
151.3
156.6
161.7
149.9
144.6
139.3
139.5
141.2
143.6
239.6
239.6
239.6
239.6
239.6
239.6
259.0
259.0
259.0
259.0
259.0
259.0
108.8
-
-
-
-
-
108.7
104.3
-
-
-
-
239.6
-
-
-
-
-
274.4
274.4
-
-
-
-
115.5
-
-
-
-
-
114.8
110.5
-
-
-
-
260.0
-
-
-
-
-
283.7
283.7
-
-
-
-
6.6
-
-
-
-
-
6.2
6.2
-
-
-
-
168.0
-
-
-
-
-
203.7
203.7
-
-
-
-
31.1
30.7
30.2
30.7
31.4
31.9
28.0
27.1
26.2
26.4
26.4
26.9
41.2
41.2
41.2
41.2
41.2
41.2
44.6
44.6
44.6
44.6
44.6
44.6
33.8
33.9
33.9
34.8
36.0
37.3
27.2
26.6
25.6
25.6
25.8
26.1
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
31.1
30.7
30.2
30.7
31.4
31.9
28.0
27.1
26.2
26.4
26.4
26.9
44.0
44.0
44.0
44.0
44.0
44.0
45.7
45.7
45.7
45.7
45.7
45.7
21.3
20.8
20.3
20.3
20.6
20.7
18.3
19.7
19.7
20.4
21.2
22.1
45.1
45.1
45.1
45.1
45.1
45.1
45.7
45.7
45.7
45.7
45.7
45.7
31.8
30.0
28.7
30.0
31.8
33.4
33.5
32.9
29.4
27.4
27.7
28.5
39.3
43.2
43.2
43.2
43.2
43.2
43.0
45.7
45.7
45.7
45.7
45.7
1.7
1.7
-
-
-
-
1.9
1.9
1.9
-
-
-
10.3
10.3
-
-
-
-
10.3
10.3
10.3
-
-
-
32.0
30.2
28.8
30.2
32.0
33.6
33.8
33.1
29.6
27.5
27.9
28.6
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
-
-
-
-
-
-
12.6
-
-
-
-
-
-
-
-
-
-
-
18.4
-
-
-
-
-
-
-
-
-
-
-
6.2
-
-
-
-
-
-
-
-
-
-
-
17.0
-
-
-
-
-
-
-
-
-
-
-
7.0
-
-
-
-
-
-
-
-
-
-
-
18.4
-
-
-
-
-
-
-
-
-
-
-
7.0
-
-
-
-
-
-
-
-
-
-
-
18.2
-
-
-
-
-
21.7
21.2
20.7
20.8
21.0
21.2
18.7
20.1
20.1
20.8
21.6
22.6
35.2
35.2
35.2
35.2
35.2
35.2
40.5
40.5
40.5
40.5
40.5
40.5
-
29.7
14.9
-
-
-
-
33.6
32.5
16.0
-
-
45.7
45.7
-
-
-
-
45.7
45.7
45.7
-
-
-
7.7
6.3
6.3
6.3
6.3
6.3
11.6
11.7
11.7
11.7
11.7
11.7
16.8
16.8
16.8
16.8
16.8
16.8
20.5
20.5
20.5
20.5
20.5
20.5
10.6
6.1
4.0
4.0
4.0
4.0
9.4
9.4
9.4
9.4
9.4
9.4
16.2
16.2
16.2
16.2
16.2
16.2
17.6
17.6
17.6
17.6
17.6
17.6
3.6
3.6
3.6
3.6
3.6
3.6
2.8
2.8
2.8
2.8
2.8
2.8
20.0
20.0
20.0
20.0
20.0
20.0
23.7
23.7
23.7
23.7
23.7
23.7
19.2
9.3
-
-
-
-
19.6
18.9
8.3
-
-
-
45.7
45.7
-
-
-
-
45.7
45.7
45.7
-
-
-
Distribution and Transmission Annual Planning Report December 2013
86
Sutherland Area - Feeder Load Forecast
Feeder name
Feeder 750/2
(750tee to Engadine ZS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Feeder 750/3
(750tee to Lucas
Heights)
33 Rating
Feeder 751
(Kurnell STS to Kurnell
ZS)
33 Rating
Load
33 Rating
Feeder 912
(Sydney South BSP to
Port Hacking STS)
33 Rating
Feeder 285
(Menai ZS to Engadine
ZS)
33 Rating
Feeder 286
(Engadine ZS to RAC
Heathcote)
33 Rating
Feeder 289
(Engadine ZS to Port
Hacking STS)
Feeder 747
(Port Hacking STS to
Woronora Dam)
Feeder 750
(Miranda ZS to Lucas
Heights)
Winter (MVA)
2015
2016
2017
2018
28.0
14.5
-
-
-
-
31.5
30.6
15.6
-
-
-
45.7
-
-
-
-
45.7
45.7
45.7
-
-
-
11.1
6.9
-
-
-
-
15.2
11.6
9.0
-
-
-
30.4
30.4
-
-
-
-
37.3
28.9
28.9
-
-
-
Load
Load
2014
45.7
Load
Feeder 752
(Kurnell to Gwawley Bay
ZS)
2013
-
-
-
-
-
-
12.6
-
-
-
-
-
-
-
-
-
-
-
18.4
-
-
-
-
-
0.3
0.1
0.1
0.1
0.1
0.1
0.5
0.1
0.1
0.1
0.0
0.1
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
150.1
146.5
146.7
150.4
155.9
160.6
149.4
144.0
138.2
139.1
140.6
143.2
194.3
220.6
220.6
220.6
220.6
220.6
204.6
257.1
257.1
257.1
257.1
257.1
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
-
113.1
112.4
115.1
118.9
122.6
-
-
106.1
106.0
107.1
108.7
-
200.0
200.0
200.0
200.0
200.0
-
-
200.0
200.0
200.0
200.0
-
6.6
6.6
6.6
6.6
6.6
-
-
6.2
6.2
6.2
6.2
-
120.0
120.0
120.0
120.0
120.0
-
-
120.0
120.0
120.0
120.0
-
92.7
78.8
81.1
84.3
87.3
-
-
85.8
71.8
72.6
73.9
-
200.0
200.0
200.0
200.0
200.0
-
-
200.0
200.0
200.0
200.0
-
-
1.7
1.7
1.7
1.7
-
-
-
1.9
1.9
1.9
-
-
8.6
8.6
8.6
8.6
-
-
-
8.6
8.6
8.6
-
-
4.1
4.1
4.1
4.1
-
-
-
9.7
9.6
9.6
-
-
21.7
21.7
21.7
21.7
-
-
-
22.9
22.9
22.9
3.21.3 STS and ZS load forecast
Sutherland Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Kurnell 132/33kV STS
Port Hacking 132/33kV STS
Caringbah 33/11kV ZS
Cronulla 132/11kV ZS
Engadine 132/11kV ZS
Engadine 33/11kV ZS
Gwawley Bay 132/11kV ZS
Jannali 33/11kV ZS
Kirrawee 132/11kV ZS
Kurnell 33/11kV ZS
Kurnell 33/6.3kV ZS
Kurnell South 132/11kV ZS
Lucas Heights 33/11kV ZS
Menai 132/11kV ZS
Miranda 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
174.9
205.8
76.2
106.9
109.3
56.2
85.9
71.7
76.2
64.9
17.7
76.2
38.5
121.4
71.9
174.9
206.1
76.2
118.2
120.3
56.3
85.9
71.8
76.3
64.9
17.7
76.2
44.1
130.0
71.9
116.6
137.2
38.1
53.5
59.5
29.0
40.2
40.9
44.6
28.7
9.7
38.1
19.2
60.7
42.0
116.6
137.4
38.1
64.2
62.5
30.9
40.2
44.8
44.6
29.6
9.7
38.1
22.0
65.0
42.0
116.6
137.2
38.1
64.2
71.4
34.8
44.7
40.9
49.5
28.7
9.7
45.7
21.4
72.9
50.4
116.6
137.4
38.1
77.0
73.4
36.4
48.2
44.8
46.0
29.6
9.7
41.6
26.4
78.0
44.1
11.2
2.9
13.8
2.9
2.9
2.9
13.8
2.4
13.8
8.6
8.6
8.6
13.8
2.4
2.9
5.0
5.0
5.0
3.5
3.5
3.5
5.0
3.5
5.0
4.8
4.8
4.8
19.1
3.5
5.0
0.39
1.59
1.65
0.79
1.54
1.35
0.19
2.26
0.77
0.45
0.15
17.48
-
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
87
SUMMER - Sutherland Area STS and ZS Load Forecast
Substation
MVA
PF
MVA
Port Hacking 132/33kV STS PF
MVA
Caringbah 33/11kV ZS
PF
MVA
Cronulla 132/11kV ZS
PF
MVA
PF
Engadine 132/11kV ZS
MVA
PF
Engadine 33/11kV ZS
MVA
Gwawley Bay 132/11kV ZS PF
MVA
PF
Gwawley Bay 33/11kV ZS
MVA
Jannali 33/11kV ZS
PF
MVA
PF
Kirrawee 132/11kV ZS
MVA
PF
Kurnell 33/11kV ZS
MVA
PF
Kurnell 33/6.3kV ZS
MVA
Kurnell South 132/11kV ZS PF
MVA
Lucas Heights 33/11kV ZS PF
MVA
PF
Menai 132/11kV ZS
MVA
PF
Miranda 33/11kV ZS
Kurnell 132/33kV STS
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
54.8
58.7
57.0
50.1
46.5
32.0
24.5
23.9
24.0
24.3
24.5
0.83
0.99
0.90
0.90
0.86
1.00
0.86
0.86
0.86
0.86
0.86
110.9
101.5
111.7
116.9
89.5
89.8
77.2
64.6
66.2
68.3
70.2
0.99
0.97
0.93
0.92
0.94
0.94
0.94
0.94
0.94
0.94
0.94
27.5
27.3
26.9
21.5
21.5
23.2
22.7
22.2
22.3
22.5
22.7
0.83
0.99
0.89
0.89
0.89
0.89
0.89
0.89
0.89
0.89
0.89
49.5
51.5
57.0
46.4
51.6
52.5
54.3
55.1
57.3
60.1
62.8
0.97
0.92
0.96
0.97
0.97
0.97
0.97
0.97
0.97
0.97
0.97
13.2
26.2
26.6
27.2
27.7
0.97
0.97
0.97
0.97
0.97
28.8
30.3
33.3
24.7
28.2
26.6
13.2
0.99
0.97
0.97
0.97
0.97
0.97
0.97
31.2
31.7
31.8
31.7
32.5
33.6
34.6
0.90
0.90
0.90
0.90
0.90
0.90
0.90
32.5
33.3
36.3
28.6
0.99
0.97
0.90
0.92
31.1
30.5
34.3
26.9
29.7
30.2
30.7
31.2
32.6
34.3
36.0
0.99
0.97
0.94
0.92
0.94
0.94
0.94
0.94
0.94
0.94
0.94
30.2
33.4
39.2
32.3
35.5
37.5
37.3
37.1
37.8
38.9
39.9
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
0.90
25.2
26.4
25.7
20.3
17.2
8.4
0.83
0.99
0.97
0.96
0.99
0.99
9.0
9.3
8.3
9.8
9.6
4.8
0.83
0.99
0.85
0.85
0.85
0.85
12.9
25.5
24.7
24.6
24.7
24.8
0.96
0.96
0.96
0.96
0.96
0.96
7.3
7.5
7.1
7.4
7.1
7.6
7.6
7.6
7.6
7.6
7.6
0.99
0.97
0.90
0.90
0.91
0.91
0.91
0.91
0.91
0.91
0.91
46.5
47.5
50.8
37.8
44.0
43.2
43.3
43.4
44.7
46.4
47.9
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
38.4
38.0
35.2
29.5
31.8
32.5
32.1
31.7
32.1
32.8
33.3
0.99
0.97
0.92
0.94
0.95
0.95
0.95
0.95
0.95
0.95
0.95
WINTER - Sutherland Area STS and ZS Load Forecast
Substation
MVA
Kurnell 132/33kV STS
PF
MVA
Port Hacking 132/33kV STS PF
MVA
PF
Caringbah 33/11kV ZS
MVA
PF
Cronulla 132/11kV ZS
MVA
PF
Engadine 132/11kV ZS
MVA
Engadine 33/11kV ZS
PF
MVA
Gwawley Bay 132/11kV ZS PF
MVA
Gwawley Bay 33/11kV ZS
PF
MVA
Jannali 33/11kV ZS
PF
MVA
Kirrawee 132/11kV ZS
PF
MVA
Kurnell 33/11kV ZS
PF
MVA
Kurnell 33/6.3kV ZS
PF
MVA
Kurnell South 132/11kV ZS PF
MVA
Lucas Heights 33/11kV ZS PF
MVA
Menai 132/11kV ZS
PF
MVA
Miranda 33/11kV ZS
PF
Actual Load
2008
2009
2010
50.7
52.9
53.0
0.93
0.92
1.00
120.9
112.7
104.8
0.99
0.96
0.96
23.9
22.0
22.1
0.93
0.92
0.93
67.3
57.1
59.8
0.98
0.97
0.98
35.8
28.2
31.7
0.99
0.96
0.98
34.2
28.9
29.9
0.96
0.96
0.96
40.2
36.6
33.3
0.99
0.96
0.97
38.9
34.3
37.3
0.96
0.96
0.89
25.0
24.7
25.4
0.93
0.92
0.92
8.5
8.3
8.2
0.93
0.92
0.86
6.3
5.7
6.2
0.99
0.96
0.90
50.9
41.7
43.2
0.97
0.97
0.97
37.5
36.2
34.6
0.99
0.96
0.97
2011
55.9
0.90
126.1
0.96
22.8
0.91
58.1
0.98
31.0
0.98
27.9
0.97
31.6
0.97
40.7
0.89
21.3
0.92
8.4
0.85
6.3
0.91
45.7
0.97
30.3
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
43.4
0.91
115.3
0.97
18.4
0.93
56.1
0.99
28.7
0.98
25.9
0.97
32.2
0.98
36.8
0.89
16.6
0.92
8.6
0.85
6.3
0.92
37.6
0.97
28.2
0.98
2013
43.3
1.00
97.1
0.98
20.9
0.93
56.3
0.99
29.0
0.98
26.0
0.97
31.3
0.98
38.5
0.89
20.3
0.92
8.2
0.85
6.5
0.92
36.2
0.97
28.1
0.98
Forecast Load
2014
2015
2016
35.7
22.8
23.6
0.91
0.91
0.91
94.8
79.3
66.5
0.98
0.98
0.98
22.4
22.4
23.1
0.93
0.93
0.93
55.6
54.5
54.7
0.99
0.99
0.99
13.6
27.3
0.98
0.98
28.1
13.7
0.98
0.98
25.2
24.4
24.5
0.97
0.97
0.97
30.6
30.0
30.3
0.98
0.98
0.98
37.9
36.8
36.9
0.89
0.89
0.89
9.8
0.92
4.1
0.85
13.9
27.4
27.6
0.90
0.90
0.90
6.5
6.5
6.5
0.92
0.92
0.92
35.4
34.7
35.1
0.97
0.97
0.97
27.2
26.4
26.5
0.98
0.98
0.98
2017
24.4
0.91
67.2
0.98
24.0
0.93
55.0
0.99
27.5
0.98
24.6
0.97
30.8
0.98
37.1
0.89
27.8
0.90
6.5
0.92
35.6
0.97
26.7
0.98
2018
25.5
0.91
68.1
0.98
25.0
0.93
55.7
0.99
27.8
0.98
24.9
0.97
31.5
0.98
37.6
0.89
28.1
0.90
6.5
0.92
36.4
0.97
27.0
0.98
88
3.22
Sydney CBD Load Area
3.22.1 Description of Sydney CBD load area
The Sydney CBD network area extends from Circular Quay in the north, west to Darling Harbour, east to
Woolloomooloo, and south to Haymarket. Bounded by Darling Harbour, Central Railway Station and the Domain, it
comprises an area of less than 3 square kilometres. This is the commercial heart of Sydney, which contains
approximately 45% of Sydney’s office space and is home to some 49,000 residents.
The network in the Sydney CBD area:

includes 132/11kV zone substations at City Central, City North, City South and Dalley St. and a 33/11kV zone
substation at City East

is supplied at 132kV from TransGrid’s Haymarket Bulk Supply Point (BSP) and from Ausgrid’s Inner
Metropolitan Transmission network which includes supply from Rozelle and Lane Cove STSS

includes 33kV supply to City East 33/11kV zone sourced from Surry Hills STS

is an underground network, and

at the 11kV level, is predominantly of an underground triplex2 construction and provides an N-1 distribution
supply.
Figure 25: Sydney CBD load area
Table 23 – Identified system limitations in Sydney CBD load area
Location
1.
Dalley St ZS
Identified
Limitation
Refer to
DAPR section
Asset Condition
5.3.10
2
The triplex design used on much of the distribution network in the CBD means distribution substations generally comprise three
distribution transformers supplied radially by three 11kV feeders.
Distribution and Transmission Annual Planning Report December 2013
89
3.22.2 Sub-transmission feeder load forecast
Sydney CBD Area - Feeder Load Forecast
Feeder name
(Surry Hills STS to City
East ZS TxA)
(Surry Hills STS to City
East ZS TxB)
(Surry Hills STS to City
East ZS TxD)
(Surry Hills STS to City
East ZS TxF)
(Surry Hills STS to City
East ZS TxC)
(Surry Hills STS to City
East ZS TxE)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
33
33
33
33
33
33
Load
Rating
Load
Rating
Load
Rating
Load
Rating
Load
Rating
Load
Rating
12.0
17.7
11.9
17.7
11.4
16.8
12.0
16.8
12.1
13.8
11.3
17.7
12.0
17.7
11.9
17.7
11.4
16.8
12.0
16.8
12.1
13.8
11.4
17.7
12.1
17.7
12.0
17.7
11.5
16.8
12.1
16.8
12.3
13.8
11.5
17.7
12.1
17.7
12.0
17.7
11.5
16.8
12.1
16.8
12.3
13.8
11.5
17.7
12.2
17.7
12.1
17.7
11.6
16.8
12.3
16.8
12.4
13.8
11.5
17.7
12.3
17.7
12.2
17.7
11.6
16.8
12.3
16.8
12.4
13.8
11.6
17.7
2013
9.6
19.2
9.5
19.2
9.1
18.3
9.6
18.3
9.7
15.6
9.1
19.2
Winter (MVA)
2015
2016
9.8
9.7
19.2
19.2
9.7
9.6
19.2
19.2
9.3
9.4
18.3
18.3
9.8
9.9
18.3
18.3
9.9
9.8
15.6
15.6
9.2
9.4
19.2
19.2
2014
9.6
19.2
9.6
19.2
9.1
18.3
9.7
18.3
9.7
15.6
9.1
19.2
2017
9.9
19.2
9.9
19.2
9.4
18.3
10.0
18.3
10.0
15.6
9.4
19.2
2018
10.0
19.2
10.0
19.2
9.5
18.3
10.1
18.3
10.1
15.6
9.5
19.2
3.22.3 STS and ZS load forecast
Sydney CBD Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Belmore Park 132/11kV ZS
City Central 132/11kV ZS
City East 33/11kV ZS
City North 132/11kV ZS
City South 132/11kV ZS
Dalley St 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
0.0
254.4
105.2
213.7
242.4
243.2
0.0
254.4
108.9
213.7
242.4
258.0
0.0
192.0
71.6
167.9
195.0
185.4
0.0
195.0
75.5
167.9
195.0
195.0
128.0
192.0
71.6
167.9
195.0
185.4
130.0
195.0
75.5
167.9
195.0
195.0
13.8
13.8
13.8
13.8
13.8
13.8
19.1
22.2
22.2
19.1
19.1
19.1
0.02
0.05
0.04
1.54
0.37
1.20
4.37
1.20
Identified
Limitation
in next 5
years
No
Yes
No
No
Yes
No
SUMMER - Sydney CBD Area STS and ZS Load Forecast
Substation
MVA
Belmore Park 132/11kV ZS PF
MVA
PF
City Central 132/11kV ZS
MVA
City East 33/11kV ZS
PF
MVA
PF
City North 132/11kV ZS
MVA
PF
City North 33/11kV ZS
MVA
PF
City South 132/11kV ZS
MVA
Dalley St 132/11kV ZS
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
6.9
41.6
63.0
62.6
0.95
1.00
1.00
1.00
140.4
134.7
135.2
133.4
136.8
140.7
133.8
132.1
115.9
116.1
115.8
0.99
0.99
0.98
0.96
0.96
1.00
1.00
1.00
1.00
1.00
1.00
43.4
47.2
42.7
45.5
42.6
44.4
44.4
44.9
44.5
44.4
44.2
0.92
1.00
0.95
0.96
0.96
0.96
0.96
0.96
0.96
0.96
0.96
20.0
31.5
55.9
59.4
86.4
85.7
85.1
85.2
84.9
0.98
0.97
0.97
1.00
1.00
1.00
1.00
1.00
1.00
36.0
37.7
32.2
18.9
0.98
1.00
1.00
0.95
162.5
155.2
160.1
138.3
136.0
154.4
155.1
144.5
124.1
104.0
103.5
0.96
0.96
0.98
0.98
0.95
0.99
0.99
1.00
1.00
1.00
1.00
154.8
151.3
158.4
138.0
118.6
125.8
101.7
99.2
98.4
98.4
97.9
0.99
0.99
0.98
0.97
0.96
1.00
1.00
1.00
1.00
1.00
1.00
WINTER - Sydney CBD Area STS and ZS Load Forecast
Substation
MVA
Belmore Park 132/11kV ZS PF
MVA
PF
City Central 132/11kV ZS
MVA
PF
City East 33/11kV ZS
MVA
PF
City North 132/11kV ZS
MVA
City North 33/11kV ZS
PF
MVA
PF
City South 132/11kV ZS
MVA
Dalley St 132/11kV ZS
PF
2008
121.7
0.96
35.1
0.95
29.1
0.94
126.6
0.97
126.5
0.99
Actual Load
2009
2010
2011
106.6
110.2
103.2
0.98
0.96
0.96
38.2
34.0
31.8
1.00
0.96
0.96
14.2
19.7
0.98
0.95
28.9
31.3
14.5
0.87
0.95
0.99
127.7
125.1
112.2
0.97
0.99
0.99
126.7
126.5
115.8
0.99
0.97
0.98
Distribution and Transmission Annual Planning Report December 2013
2012
108.8
0.96
36.1
0.94
36.5
0.98
109.6
0.99
112.4
0.98
2013
112.0
1.00
35.5
0.94
48.0
1.00
130.8
1.00
104.5
1.00
2014
5.8
0.95
106.6
1.00
35.6
0.94
69.9
1.00
126.0
1.00
84.6
1.00
Forecast Load
2015
2016
33.8
51.0
1.00
1.00
93.1
93.5
1.00
1.00
36.0
36.2
0.94
0.94
69.5
69.7
1.00
1.00
107.0
90.2
1.00
1.00
82.6
83.0
1.00
1.00
2017
51.7
1.00
94.7
1.00
36.6
0.94
70.6
1.00
91.3
1.00
84.0
1.00
2018
52.2
1.00
95.6
1.00
37.0
0.94
71.3
1.00
92.2
1.00
84.8
1.00
90
3.23
Upper Central Coast Load Area
3.23.1 Description of Upper Central Coast load area
The Upper Central Coast area covers the Wyong Shire and includes the area north of Tuggerah Bulk Supply Point
(BSP), extending to Vales Point in the north, east to the coast, and to the western boundary of Wyong shire. The
area includes Tuggerah Lakes and Lake Munmorah, which largely separate the inland areas from major industries
include coal mining and power generation.
The Regional Development Strategy for the Central Coast forecasts that there will be continuing population growth
in the Wyong shire, with an increase of 27,000 jobs and 36,500 additional dwellings by 2031. Approximately 16,000
of these dwellings will occur in new land release areas. A significant new town centre at Warnervale is proposed in
the short to medium term and the nearby Wyong development zone is targeted for industrial development.
The network in the Upper Central Coast area is comprised of a southern 132kV system and a northern 33kV
system. The 132kV southern system:

comprises of a 132kV line linking TransGrid’s 330/132kV Munmorah and Tuggerah bulk supply points

consists of three 132/11kV zone substations at Wyong, Charmhaven and Lake Munmorah

provides support to TransGrid’s Tuggerah 330/132kV substation which is currently supplied by two 330kV
feeders and transformers, and

includes a 132kV line running from Vales Point to Morisset zone substation (Westlakes area) and Ourimbah
sub-transmission substation. Although this line traverses the area, it does not supply the load within the area.
There are two 330/132kV transformers at Vales Point BSP. However, due to non-availability of 132kV busbar at
Vales Point BSP the 132kV feeder 957 connects to both 330/132kV transformers. Connection of any additional
132kV feeders to either Munmorah BSP or Vales Point BSP would require substantial work to establish a 132kV
busbar at both locations.
The 33kV northern system:

comprises of two radial feeders which are supplied from the 330/33kV auxiliary transformers at Munmorah
power station. The availability of 33kV supply depends on the continued operation of the Munmorah Power
station

supplies zone substations at Noraville and Vales Point.
Figure 26: Upper Central Coast load area
Distribution and Transmission Annual Planning Report December 2013
91
Table 24 – Identified system limitations in the Upper Central Coast load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Munmorah BSP
Asset Condition
5.3.11
2.
Vales Point ZS
Asset Condition
5.3.11
3.23.2 Sub-transmission feeder load forecast
Upper Central Coast Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder 743/1
(Munmorah BSP to
743tee)
33kV Rating
Feeder 743/2
(743tee to Vales Point
ZS)
33kV Rating
Feeder 743/3
(743tee to Noraville ZS)
Feeder 744/1
(Munmorah BSP to
744tee)
Feeder 744/2
(744tee to Vales Point
ZS)
Feeder 744/3
(744tee to Noraville ZS)
Load
Load
Load
33kV Rating
Load
33kV Rating
Load
33kV Rating
Load
33kV Rating
Feeder 95T
Load
(Vales Point ZS to Lake
132kV Rating
Munmorah ZS)
Feeder 97J
Load
(Munmorah BSP to Lake
132kV Rating
Munmorah ZS)
2013
2014
Winter (MVA)
2015
2016
2017
2018
32.4
32.8
33.3
34.4
35.6
36.7
36.6
36.6
36.6
37.7
39.0
40.2
48.6
48.6
48.6
48.6
48.6
48.6
53.0
53.0
53.0
53.0
53.0
53.0
10.0
10.0
10.0
10.0
10.2
10.0
10.7
10.7
10.7
10.5
10.7
10.7
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
22.4
22.9
23.3
24.4
25.5
26.7
26.3
26.4
26.4
27.5
28.7
29.9
46.7
46.7
46.7
46.7
46.7
46.7
54.5
54.5
54.5
54.5
54.5
54.5
33.9
34.2
34.7
36.3
37.3
38.5
38.2
38.6
38.3
39.9
41.4
42.8
49.6
49.6
49.6
49.6
49.6
49.6
52.1
52.1
52.1
52.1
52.1
52.1
12.8
12.8
13.1
13.6
13.6
14.2
14.7
15.1
14.7
15.2
15.6
15.8
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
20.9
21.1
21.2
22.3
23.2
24.0
23.4
23.4
23.5
24.5
25.5
26.6
30.7
30.7
30.7
30.7
30.7
30.7
42.5
42.5
42.5
42.5
42.5
42.5
16.9
21.1
21.0
21.5
21.9
22.4
25.0
27.7
26.8
27.1
27.4
27.6
240.0
240.0
240.0
240.0
240.0
240.0
257.0
257.0
257.0
257.0
257.0
257.0
17.0
21.1
21.0
21.5
21.9
22.5
25.0
27.7
26.8
27.1
27.4
27.6
250.7
250.7
250.7
250.7
250.7
250.7
306.4
306.4
306.4
306.4
306.4
306.4
3.23.3 STS and ZS load forecast
Upper Central Coast Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Munmorah 330/33kV STS
Charmhaven 132/11kV ZS
Lake Munmorah 132/11kV ZS
Noraville 33/11kV ZS
Vales Point 33/11kV ZS
Wyong 132/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
125.9
76.2
47.4
30.5
110.3
130.0
76.2
52.2
30.5
115.2
64.0
63.3
38.1
34.4
15.2
54.0
69.0
65.0
38.1
37.5
15.2
58.8
64.0
75.9
38.7
40.1
16.9
60.4
69.0
78.0
45.7
45.0
17.9
59.9
2.9
2.9
2.9
2.9
2.9
11.2
3.5
3.5
3.5
3.5
5.0
5.0
2.82
1.82
1.66
2.24
2.20
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
No
92
SUMMER - Upper Central Coast Area STS and ZS Load Forecast
Substation
Munmorah 330/33kV STS
Charmhaven 132/11kV ZS
Lake Munmorah 132/11kV ZS
Lake Munmorah 33/11kV ZS
Noraville 33/11kV ZS
Vales Point 33/11kV ZS
Wyong 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
39.7
48.6
39.6
40.5
20.2
17.8
18.1
18.3
19.0
19.6
20.2
0.90
0.90
0.90
0.90
0.90
0.86
0.86
0.86
0.86
0.86
0.86
43.5
42.3
46.9
37.0
47.8
41.1
36.9
36.8
37.6
38.2
39.0
0.92
0.92
0.93
0.93
0.94
0.94
0.94
0.94
0.94
0.94
0.94
20.2
16.5
20.5
20.4
20.9
21.3
21.7
0.95
0.95
0.95
0.95
0.95
0.95
0.95
19.9
19.5
20.3
14.7
0.90
0.90
0.89
0.89
25.5
23.7
24.4
18.4
24.4
21.0
21.4
21.7
22.7
23.6
24.6
0.90
0.90
0.94
0.93
0.94
0.94
0.94
0.94
0.94
0.94
0.94
10.0
10.1
9.4
10.1
9.3
9.6
9.6
9.6
9.6
9.6
9.6
0.90
0.90
0.83
0.79
0.84
0.84
0.84
0.84
0.84
0.84
0.84
40.1
40.4
43.9
33.6
35.8
35.7
34.5
34.5
34.3
33.9
33.5
0.91
0.91
0.92
0.93
0.95
0.95
0.95
0.95
0.95
0.95
0.95
WINTER - Upper Central Coast Area STS and ZS Load Forecast
Substation
Munmorah 330/33kV STS
Charmhaven 132/11kV ZS
Lake Munmorah 132/11kV ZS
Lake Munmorah 33/11kV ZS
Noraville 33/11kV ZS
Vales Point 33/11kV ZS
Wyong 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
59.2
0.90
42.1
0.95
20.5
0.90
26.6
0.90
10.9
0.90
33.0
0.95
2009
50.9
0.90
36.6
0.95
17.4
0.90
23.0
0.90
10.7
0.90
33.1
0.95
Actual Load
2010
2011
53.0
48.5
0.90
0.90
36.6
36.7
0.96
0.98
17.4
17.0
0.90
0.95
24.1
23.0
0.98
0.98
9.9
9.5
0.63
0.80
34.4
32.0
0.97
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
48.1
0.90
34.4
0.98
15.9
0.95
23.7
0.98
10.3
-0.80
30.8
0.97
2013
30.3
0.92
34.1
0.98
24.2
0.96
24.8
0.98
10.2
0.80
34.1
0.97
2014
30.4
0.92
30.0
0.98
26.7
0.96
24.8
0.98
10.2
0.80
33.0
0.97
Forecast Load
2015
2016
30.4
31.3
0.92
0.92
29.2
29.6
0.98
0.98
25.9
26.2
0.96
0.96
24.8
25.8
0.98
0.98
10.2
10.2
0.80
0.80
32.0
32.3
0.97
0.97
2017
32.3
0.92
30.0
0.98
26.4
0.96
26.9
0.98
10.2
0.80
32.6
0.97
2018
33.3
0.92
30.4
0.98
26.6
0.96
27.9
0.98
10.2
0.80
32.8
0.97
93
3.24
Upper Hunter Load Area
3.24.1 Description of Upper Hunter load area
The Upper Hunter area is a large area extending to Wingen in the north, Liddell to the south-east and Kars Springs
to the north-west. The main townships in the area are Muswellbrook, Aberdeen, Scone, Denman and Merriwa.
Around these towns are many smaller rural communities including Moonan, Rouchel, Ellerston, Wingen, Parkville,
Glenbawn, Dartbrook, Baerami and Sandy Hollow. Most of the area is either rural or sparsely developed, and
includes many isolated and remote communities. Other than some residential developments occurring around
Muswellbrook and on the eastern side of Scone, there is limited urban expansion taking place in the area.
The area includes urban residential, light to heavy industrial development - particularly coal mining, as well as
extensive vineyards, wineries, dairy and beef industries and horse studs. Predominant economic activities are
power generation and coal mining.
The network in the Upper Hunter area:

is supplied from both Mitchell Line 132/66kV sub-transmission substations (STS) and Muswellbrook 132/33kV
STS which are supplied via 132kV feeders from TransGrid’s transmission system at Sandy Creek near
Muswellbrook

includes nine Ausgrid zone substations, with three supplied at 66kV and the rest at 33kV

includes four mining customers; with one supplied at 33kV and the others at 66kV

includes a 33kV connection point for the Glenbawn Hydro-generator near Rouchel

includes more than 200km of overhead 33kV & 66kV feeder network; and

consists of a predominantly radial sub-transmission system with either limited or non existent 11kV
interconnections.
Figure 27: Upper Hunter load area
Table 25 – Identified system limitations in Upper Hunter load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Denman 66/11kV ZS
Asset Condition
5.3.21
2.
Mitchell Line 66/11kV ZS
Asset Condition
5.3.21
Distribution and Transmission Annual Planning Report December 2013
94
3.24.2 Sub-transmission feeder load forecast
Upper Hunter Area - Feeder Load Forecast
Feeder name
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Feeder 32038(4)
(Rouchel ZS to Moonan
ZS)
33 Rating
Feeder 32038(6)
(Rouchel ZS to Moonan
ZS)
33 Rating
Feeder 32038(7) (tee to
MS5)
33 Rating
Feeder 32038(8)
(Rouchel to Moonan ZS)
33 Rating
Feeder 6023(1)
(Mitchell Line STS to
Bayswater Coal)
66 Rating
Feeder 6023(2)
(Mitchell Line STS to
Bayswater)
66 Rating
Load
Load
Load
Load
Load
Load
Feeder 6025(1)
(Mitchell Line STS to
Denman ZS)
66 Rating
Feeder 6025(3)
(Mitchell Line STS to
Denman ZS)
66 Rating
Feeder 6027(1)
(Mitchell Line STS to
Denman ZS)
66 Rating
Feeder 6027(2)
(Mitchell Line STS to
Denman ZS)
Load
Load
Load
Load
66 Rating
Feeder 6028(1)
(Mitchell Line STS to
Scone ZS)
66 Rating
Feeder 6028(3)
(Mitchell Line STS to
Scone ZS)
66 Rating
Feeder 6028(4)
(tee to Bengalla Mine)
Load
Load
Load
66 Rating
Feeder 6028(5)
(Mitchell Line STS to
Scone ZS)
66 Rating
Feeder 6028(6)
(Mitchell Line STS to
Scone ZS)
66 Rating
Feeder 6028(7)
(tee to Dartbrook Mine)
66 Rating
Feeder 60334(1)
(Denman ZS to Baerami
and Merriwa)
33 Rating
Feeder 60334(3)
(Denman ZS to Baerami
and Merriwa)
33 Rating
Feeder 60334(4)
(tee to Baerami ZS)
33 Rating
Feeder 60334(5) (tee to
Merriwa ZS)
33 Rating
Feeder 6022
(Mitchell Line STS to
Aberdeen ZS)
Feeder 82257(Aberdeen
ZS to Scone ZS)
Feeder 89136
(Denman to Mangoola
Mine)
Feeder MS1
(Muswellbrook STS to
Muswellbrook ZS)
Load
Load
Load
Load
Load
Load
Load
Load
66 Rating
Load
66 Rating
Load
66 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
1.2
1.2
1.2
1.2
1.2
1.2
1.0
0.9
0.9
0.9
0.9
0.9
21.0
21.0
21.0
21.0
21.0
21.0
27.5
27.5
27.5
27.5
27.5
27.5
0.9
0.9
0.9
0.9
0.9
1.0
0.8
0.4
0.4
0.4
0.4
0.4
21.0
21.0
21.0
21.0
21.0
21.0
27.5
27.5
27.5
27.5
27.5
27.5
1.7
1.7
1.7
1.7
1.8
1.8
-
1.1
1.1
1.1
1.1
1.1
36.0
36.0
36.0
36.0
36.0
36.0
-
38.9
38.9
38.9
38.9
38.9
1.1
1.1
1.1
1.1
1.1
1.1
1.0
1.0
1.0
1.0
0.9
0.9
4.9
4.9
4.9
4.9
4.9
4.9
10.8
10.8
10.8
10.8
10.8
10.8
18.6
18.6
18.6
18.6
18.6
18.6
19.5
19.5
19.5
19.5
19.5
19.5
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
18.6
18.6
18.6
18.6
18.6
18.6
19.5
19.5
19.5
19.5
19.5
19.5
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
20.5
20.4
20.3
20.2
20.5
20.4
16.2
16.2
16.2
7.8
7.8
7.8
63.9
63.9
63.9
63.9
63.9
63.9
85.7
85.7
85.7
85.7
85.7
85.7
20.4
20.4
20.3
20.2
20.5
20.4
16.2
16.2
16.2
7.8
7.8
7.8
29.6
29.6
29.6
29.6
29.6
29.6
38.4
38.4
38.4
38.4
38.4
38.4
20.4
20.3
20.1
20.3
20.2
20.4
16.3
16.2
16.1
16.2
16.2
16.2
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
20.4
20.3
20.1
20.3
20.2
20.4
16.3
16.2
16.1
16.2
16.2
16.2
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
31.9
31.5
31.1
30.8
30.8
30.7
24.2
26.7
26.5
26.3
26.2
26.3
63.9
63.9
63.9
63.9
63.9
63.9
85.7
85.7
85.7
85.7
85.7
85.7
31.9
31.5
31.1
30.8
30.8
30.7
24.2
26.7
26.5
26.3
26.2
26.3
63.9
63.9
63.9
63.9
63.9
63.9
85.7
85.7
85.7
85.7
85.7
85.7
13.1
13.1
13.1
13.1
13.1
13.1
14.0
14.0
14.0
14.0
14.0
14.0
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
22.0
21.6
21.2
20.9
20.9
20.8
12.6
15.1
14.9
14.8
14.7
14.8
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
62.3
62.3
62.3
62.3
62.3
62.3
-
14.3
14.1
14.0
13.9
14.0
120.0
120.0
120.0
120.0
120.0
120.0
-
82.9
82.9
82.9
82.9
82.9
1.6
1.6
1.6
1.6
1.6
1.6
1.8
1.8
1.8
1.8
1.8
1.8
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
4.5
4.5
4.4
4.4
4.4
4.4
3.0
2.9
2.9
2.8
2.8
2.9
27.1
27.1
27.1
27.1
27.1
27.1
29.4
29.4
29.4
29.4
29.4
29.4
4.5
4.5
4.4
4.3
4.4
4.4
3.0
2.9
2.9
2.8
2.8
2.9
7.4
7.4
7.4
7.4
7.4
7.4
12.1
12.1
12.1
12.1
12.1
12.1
4.4
4.3
4.3
4.2
4.2
4.2
2.9
2.9
2.8
2.8
2.8
2.8
7.4
7.4
7.4
7.4
7.4
7.4
12.1
12.1
12.1
12.1
12.1
12.1
4.0
3.9
3.8
3.8
3.8
3.8
3.2
3.1
3.1
3.0
3.0
3.0
5.1
5.1
5.1
5.1
5.1
5.1
10.8
10.8
10.8
10.8
10.8
10.8
22.6
22.9
22.0
21.8
21.7
21.6
-
15.0
14.7
14.6
14.5
14.6
62.0
62.0
62.0
62.0
62.0
62.0
-
83.0
83.0
83.0
83.0
83.0
17.3
17.4
17.0
16.9
16.8
16.8
-
12.1
12.0
11.9
11.9
12.0
62.0
62.0
62.0
62.0
62.0
62.0
-
83.0
83.0
83.0
83.0
83.0
11.3
11.3
11.3
11.3
11.3
11.3
11.0
11.0
11.0
11.0
11.0
11.0
62.3
62.3
62.3
62.3
62.3
62.3
82.9
82.9
82.9
82.9
82.9
82.9
14.9
14.5
14.4
-
-
-
11.0
10.6
10.3
-
-
-
32.0
32.0
32.0
-
-
-
42.9
42.9
42.9
-
-
-
Distribution and Transmission Annual Planning Report December 2013
95
Upper Hunter Area - Feeder Load Forecast
Feeder name
Feeder MS10(1)
(Musewellbrook STS to
Musweelbrook ZS)
Feeder MS10(2)
(Muswellbrook STS to
Muswellbrook ZS)
Feeder MS4
(Muswellbrook STS to
Muswelbrook Coal)
Feeder MS4
(Muswellbrook 132 ZS to
Muswellbrook Coal)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
14.9
14.5
14.4
-
-
-
11.0
10.6
10.3
-
-
-
31.2
31.2
31.2
-
-
-
41.4
41.4
41.4
-
-
-
14.9
14.4
14.4
-
-
-
11.0
10.6
10.3
-
-
-
32.0
32.0
32.0
-
-
-
42.9
42.9
42.9
-
-
-
1.4
1.4
1.4
-
-
-
2.4
2.4
2.4
2.4
-
-
6.1
6.1
6.1
-
-
-
14.3
14.3
14.3
14.3
-
-
-
-
-
1.4
1.4
1.4
-
-
-
-
2.4
2.4
-
-
-
8.2
8.2
8.2
-
-
-
-
20.5
20.5
Load
33 Rating
Load
33 Rating
3.24.3 STS and ZS load forecast
Upper Hunter Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Mitchell Line 132/66kV STS
Muswellbrook 132/33kV STS
Aberdeen 33/11kV ZS
Aberdeen 66/11kV ZS
Baerami 33/11kV ZS
Denman 66/11kV ZS
Merriwa 33/11kV ZS
Mitchell Line 66/11kV ZS
Moonan 33/11kV ZS
Muswellbrook 132/11kV ZS
Muswellbrook 33/11kV ZS
Rouchel 33/11kV ZS
Scone 66/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
277.3
69.3
14.6
38.0
2.4
32.4
6.9
29.0
6.9
66.0
47.6
5.8
66.0
299.3
76.3
16.0
38.0
2.7
35.6
7.6
30.5
7.6
66.0
47.6
6.3
66.0
141.3
47.1
8.0
19.0
0.0
16.9
0.0
0.0
2.9
37.5
23.8
0.0
38.0
149.6
50.9
8.5
19.0
0.0
18.2
0.0
0.0
3.1
37.5
23.8
0.0
38.0
141.3
47.1
9.0
21.3
2.1
18.9
6.0
25.2
2.9
37.5
28.6
5.0
45.6
149.6
50.9
10.2
22.8
2.3
21.9
6.6
26.5
3.1
37.5
25.8
5.5
39.5
8.6
2.9
11.2
11.2
11.2
11.2
11.2
13.8
2.9
2.9
2.9
11.2
2.9
4.8
5.0
5.0
5.0
5.0
5.0
5.0
19.1
3.5
3.5
3.5
3.5
5.0
0.24
0.08
0.01
0.36
0.22
0.37
0.04
0.66
0.04
0.67
5.80
-
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
No
No
No
No
No
No
SUMMER - Upper Hunter Area STS and ZS Load Forecast
Substation
Mitchell Line 132/66kV STS
Muswellbrook 132/33kV STS
Aberdeen 33/11kV ZS
Aberdeen 66/11kV ZS
Baerami 33/11kV ZS
Denman 66/11kV ZS
Merriwa 33/11kV ZS
Mitchell Line 66/11kV ZS
Moonan 33/11kV ZS
Muswellbrook 132/11kV ZS
Muswellbrook 33/11kV ZS
Rouchel 33/11kV ZS
Scone 33/11kV ZS
Scone 66/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
Actual Load
Forecast Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
48.6
51.1
67.3
65.4
80.0
86.8
88.0
88.0
88.4
89.2
90.0
0.92
0.95
0.95
0.92
0.92
0.93
0.93
0.93
0.93
0.93
0.93
39.7
42.6
23.1
18.6
22.8
20.4
19.9
19.9
0.97
0.99
0.99
0.97
0.97
0.98
0.98
0.98
7.3
7.6
7.1
5.4
2.8
0.97
0.99
0.99
0.95
0.99
1.0
3.7
3.6
3.5
3.4
3.4
3.3
0.90
0.93
0.93
0.93
0.93
0.93
0.93
1.1
1.5
0.9
0.7
1.0
1.0
1.0
1.0
1.0
1.0
1.0
0.92
0.95
0.95
0.97
0.95
0.99
0.99
0.99
0.99
0.99
0.99
8.0
7.0
6.6
5.6
6.8
6.0
6.0
6.0
6.0
6.1
6.1
0.94
0.94
0.93
0.94
0.93
1.00
1.00
1.00
1.00
1.00
1.00
3.8
3.7
3.8
2.8
3.7
3.6
3.6
3.5
3.5
3.5
3.4
0.92
0.95
0.96
0.98
0.96
1.00
1.00
1.00
1.00
1.00
1.00
13.8
13.2
13.4
9.2
13.0
14.7
16.4
16.9
17.4
18.2
18.9
0.92
0.95
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
1.2
1.1
1.2
0.8
1.0
1.0
1.0
1.0
1.0
1.0
1.1
0.97
0.99
0.91
0.93
0.93
0.93
0.93
0.93
0.93
0.93
0.93
14.9
14.7
14.5
0.94
0.94
0.94
15.8
15.9
16.5
11.6
14.3
14.7
14.2
14.2
0.97
0.99
0.98
0.98
0.99
0.99
0.99
0.99
1.5
1.0
1.3
1.1
0.9
1.2
1.2
1.2
1.2
1.2
1.2
0.97
0.99
0.91
0.91
0.92
0.92
0.92
0.92
0.92
0.92
0.92
16.2
17.0
0.97
0.95
17.4
12.3
16.2
16.2
16.0
15.7
15.5
15.5
15.5
0.98
0.96
0.98
0.99
0.99
0.99
1.00
1.00
1.00
Distribution and Transmission Annual Planning Report December 2013
96
WINTER - Upper Hunter Area STS and ZS Load Forecast
Substation
Mitchell Line 132/66kV STS
Muswellbrook 132/33kV STS
Aberdeen 33/11kV ZS
Aberdeen 66/11kV ZS
Baerami 33/11kV ZS
Denman 66/11kV ZS
Merriwa 33/11kV ZS
Mitchell Line 66/11kV ZS
Moonan 33/11kV ZS
Muswellbrook 132/11kV ZS
Muswellbrook 33/11kV ZS
Rouchel 33/11kV ZS
Scone 33/11kV ZS
Scone 66/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
38.2
0.94
40.3
0.98
5.0
0.98
0.9
0.94
5.0
0.94
3.1
0.94
5.4
0.94
1.2
0.98
18.3
0.98
1.0
0.98
13.6
0.98
-
2009
40.3
0.95
32.3
0.99
5.0
0.99
0.7
0.95
4.9
0.95
3.4
0.95
8.9
0.95
1.1
0.99
12.4
0.99
1.0
0.99
12.5
0.99
-
Actual Load
2010
2011
54.0
65.6
0.98
0.94
23.6
19.3
1.00
0.96
4.7
5.1
1.00
0.98
0.6
0.7
0.98
0.93
5.1
4.3
0.98
0.98
3.1
3.1
0.99
0.99
9.6
9.2
0.96
0.96
1.2
1.0
0.98
0.98
16.7
12.1
0.99
0.99
1.1
1.0
0.93
0.92
14.5
12.7
0.99
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
65.5
0.93
18.6
0.96
2.4
0.94
0.7
0.97
4.2
0.97
3.1
1.00
9.2
0.97
1.0
0.99
11.9
0.97
0.9
0.90
12.4
0.98
2013
65.8
0.93
16.7
0.96
2.6
0.96
0.8
0.85
0.6
1.00
4.1
0.97
3.0
1.00
9.9
0.97
1.0
0.99
10.8
0.98
0.8
0.90
12.5
1.00
2014
69.4
0.93
13.2
0.96
2.6
0.87
0.6
1.00
4.1
0.97
2.9
1.00
10.8
0.97
1.0
0.99
10.4
0.98
0.8
0.90
12.3
1.00
Forecast Load
2015
2016
69.7
69.9
0.93
0.93
12.8
0.96
2.6
2.5
0.87
0.87
0.6
0.6
1.00
1.00
4.1
4.1
0.97
0.97
2.9
2.8
1.00
1.00
11.5
11.8
0.97
0.97
0.9
0.9
0.99
0.99
12.7
0.78
10.1
0.98
0.8
0.8
0.90
0.90
12.2
12.1
1.00
1.00
2017
70.3
0.93
2.5
0.87
0.6
0.99
4.1
0.97
2.8
1.00
12.3
0.97
0.9
0.99
12.4
0.78
0.9
0.90
12.1
1.00
2018
71.0
0.93
2.4
0.87
0.7
0.99
4.2
0.97
2.8
1.00
12.8
0.97
0.9
0.99
12.3
0.78
0.9
0.90
12.2
1.00
97
3.25
Upper North Shore Load Area
3.25.1 Description of Upper North Shore load area
The Upper North Shore network area extends from St Ives in the north, west to Turramurra, through Pymble and
south to Lindfield. The Pacific Highway and the North Shore and Western railway lines run through the area. The
Upper North Shore is a predominantly urban area that includes residential and commercial load.
The network in the Upper North Shore area:

is supplied via Kuring-gai sub-transmission substation (STS) via a radial 33kV underground network. Kuringgai STS is supplied from TransGrid’s transmission system at Sydney East bulk supply point (BSP) via two
132kV feeders, 9E1 and 9E2, which predominantly comprise a single double circuit tower line

provides standby supplies to Sydney Trains at 33kV from a busbar at Gordon, teed off a feeder from Kuring-gai
STS to Lindfield zone substation, and

supplies both residential and commercial load.
Figure 28: Upper North Shore load area
Table 26 – Identified system limitations in Upper North Shore load area
Location
1.
Nil
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
Refer to
DAPR section
Nil
-
98
3.25.2 Sub-transmission feeder load forecast
Upper North Shore Area - Feeder Load Forecast
Feeder name
Feeder 9E1
(Sydney East BSP to
Kuringai STS)
Feeder 9E2
(Sydney East BSP to
Kuringai STS)
Feeder 530
(Kuringai STS to Pymble
ZS T4)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Volt
age
Load
132 Rating
Load
132 Rating
Load
33 Rating
Feeder 532
(Kuringai STS to Pymble
ZS T2)
33 Rating
Feeder 533
(Kuringai STS to Pymble
ZS T1)
33 Rating
Feeder 534
(Kuringai STS to
Lindfield ZS T2)
Feeder 535
(Kuringai STS to
Lindfield ZS T3)
Feeder 536/1
(Kuringai STS to Gordon
SRA)
Feeder 536/2
(Gordon SRA to Lindfield
ZS T4)
Feeder 537
(Kuringai STS to
Turramurra ZS T1)
Feeder 538
(Kuringai STS to
Turramurra ZS T2)
Feeder 539
(Kuringai STS to
Turramurra ZS T3)
Feeder 540
(Kuringai STS to St Ives
ZS T3)
Feeder 541
(Kuringai STS to St Ives
ZS T2)
Feeder 542
(Kuringai STS to St Ives
ZS T1)
Load
Load
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Winter (MVA)
2013
2014
2015
2016
2017
2018
154.8
155.1
152.2
154.0
156.5
157.9
160.9
162.5
157.7
160.3
162.8
165.5
229.8
229.8
229.8
229.8
229.8
229.8
277.8
277.8
277.8
277.8
277.8
277.8
154.8
154.8
152.1
154.0
156.5
157.9
160.7
162.4
157.7
160.3
162.8
165.7
229.8
229.8
229.8
229.8
229.8
229.8
277.8
277.8
277.8
277.8
277.8
277.8
18.4
18.0
17.6
17.9
18.1
18.2
18.0
17.7
17.5
17.9
18.7
19.2
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
18.3
18.0
17.5
17.9
18.1
18.2
17.9
17.7
17.5
17.9
18.7
19.2
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
18.7
18.2
17.8
18.1
18.3
18.5
18.2
18.0
17.8
18.2
19.0
19.5
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
15.2
15.0
14.8
14.9
15.0
15.0
17.0
16.7
16.4
16.5
16.7
16.8
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
15.4
15.2
15.1
15.1
15.2
14.9
17.2
16.6
16.3
16.5
16.6
16.7
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
15.2
15.0
14.8
14.9
15.0
15.0
17.0
16.7
16.4
16.6
16.7
16.8
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
15.2
15.0
14.9
14.9
15.0
15.1
17.0
16.7
16.5
16.6
16.7
16.9
31.4
31.4
31.4
31.4
31.4
31.4
31.4
31.4
31.4
31.4
31.4
31.4
18.0
18.8
18.4
18.7
19.0
19.2
18.4
20.5
20.0
20.3
20.5
20.9
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
17.9
18.8
18.5
18.7
19.0
19.2
18.4
20.4
19.9
20.1
20.4
20.7
25.4
25.4
25.4
25.4
25.4
25.4
28.6
28.6
28.6
28.6
28.6
28.6
17.9
18.8
18.5
18.7
19.0
19.2
18.4
20.4
19.9
20.1
20.4
20.7
23.6
23.6
23.6
23.6
23.6
23.6
28.6
28.6
28.6
28.6
28.6
28.6
25.3
25.0
24.6
24.9
25.4
25.8
25.9
25.1
24.2
24.4
24.3
24.6
31.3
31.3
31.3
31.3
31.3
31.3
32.8
32.8
32.8
32.8
32.8
32.8
25.5
25.2
24.8
25.4
25.6
26.0
26.0
25.2
24.4
24.5
24.4
25.0
28.9
28.9
28.9
28.9
28.9
28.9
31.4
31.4
31.4
31.4
31.4
31.4
25.4
25.1
24.7
24.9
25.5
25.9
26.0
25.1
24.3
24.5
24.4
24.6
28.9
28.9
28.9
28.9
28.9
28.9
31.4
31.4
31.4
31.4
31.4
31.4
3.25.3 STS and ZS load forecast
Upper North Shore Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Kuring-gai 132/33kV STS
Lindfield 33/11kV ZS
Pymble 33/11kV ZS
St Ives 33/11kV ZS
Turramurra 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
349.8
53.2
67.7
91.5
66.1
349.8
56.4
67.7
91.6
72.3
261.0
35.2
38.9
58.4
43.3
272.1
37.1
40.9
61.1
44.8
261.0
35.2
44.5
58.4
43.3
272.1
37.1
47.7
61.1
44.8
2.9
2.9
2.9
2.9
2.9
5.0
3.5
5.0
3.5
3.5
0.99
0.78
1.51
0.96
-
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
99
SUMMER - Upper North Shore Area STS and ZS Load Forecast
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Substation
MVA
Kuring-gai 132/33kV STS PF
Lindfield 33/11kV ZS
Pymble 33/11kV ZS
St Ives 33/11kV ZS
Turramurra 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
141.6
0.88
31.2
0.88
37.7
0.88
51.3
0.88
32.3
0.88
150.4
0.90
32.6
0.90
37.8
0.90
50.9
0.90
32.6
0.90
179.6
0.88
34.6
0.94
41.6
0.92
56.9
0.89
36.8
0.96
122.8
0.97
27.3
0.94
31.2
0.92
39.0
0.90
26.0
0.97
146.7
0.91
30.8
0.93
33.8
0.92
47.4
0.89
34.1
0.98
148.7
0.91
29.2
0.93
34.8
0.92
46.9
0.90
34.6
0.98
148.6
0.91
28.8
0.93
34.1
0.92
46.4
0.90
36.3
0.98
146.3
0.91
28.6
0.93
33.4
0.92
45.8
0.90
35.7
0.98
147.1
0.92
28.6
0.93
34.0
0.91
46.2
0.90
36.1
0.98
149.2
0.92
28.8
0.93
34.3
0.91
47.1
0.90
36.6
0.98
150.8
0.92
28.9
0.93
34.6
0.91
47.8
0.90
37.0
0.98
2012
2013
2014
Forecast Load
2015
2016
2017
2018
143.5
0.95
31.8
0.97
32.8
0.92
46.2
0.94
31.6
0.97
154.9
0.95
32.8
0.97
34.1
0.92
48.5
0.94
35.5
0.97
155.9
0.95
32.2
0.97
33.7
0.92
47.0
0.94
39.1
0.97
152.4
0.95
31.8
0.97
33.3
0.92
45.6
0.94
38.1
0.97
155.7
0.95
32.2
0.97
35.4
0.92
45.7
0.94
39.1
0.97
158.1
0.95
32.6
0.97
36.4
0.92
46.1
0.94
39.7
0.97
WINTER - Upper North Shore Area STS and ZS Load Forecast
Substation
Kuring-gai 132/33kV STS
Lindfield 33/11kV ZS
Pymble 33/11kV ZS
St Ives 33/11kV ZS
Turramurra 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
2009
179.0
0.87
40.2
0.87
38.4
0.87
58.6
0.87
40.0
0.87
157.9
0.93
36.0
0.93
35.5
0.93
52.0
0.93
35.0
0.93
Actual Load
2010
2011
161.2
0.93
35.9
0.96
35.9
0.91
53.5
0.94
35.1
0.95
155.4
0.91
33.6
0.96
35.2
0.91
51.8
0.94
34.1
0.95
Distribution and Transmission Annual Planning Report December 2013
154.3
0.95
32.0
0.97
34.1
0.92
45.9
0.94
38.6
0.97
100
3.26
West Lake Macquarie Load Area
3.26.1 Description of West lake Macquarie load area
The West Lake Macquarie network area lies along the western edge of Lake Macquarie, located south-west of
Newcastle. The area extends from Teralba in the north to Wyee in the south, and west to Wakefield, Cooranbong
and Mandalong. The area includes Toronto town centres and emerging Morisset regional centre, as well as a mix of
urban residential and light industrial areas.
Most of the existing urban development is concentrated in the vicinity of the Lake Macquarie shore-line. The
surrounding areas contain a mix of industrial, power generation, coal-mining and semi-rural areas. The F3 freeway
and the main northern rail-line pass through the area. There is opportunity for continued urban development in the
area as there are large tracts of vacant land. Cooranbong has been identified in the Department of Planning’s
Lower Hunter regional strategy as a priority land release area, with 3,000 new lots expected to be released.
The network in the West Lake Macquarie area:

is supplied from both Awaba STS and Eraring STS via 132kV feeders from TransGrid’s transmission system at
Killingworth and Vales Point

includes six zone substations. Three of the six zone substations are supplied from the 33kV network originating
at Eraring STS (of which two are dedicated to mining customers), one zone substation is supplied from the
33kV network originating at Awaba STS and the remaining two zone substations are supplied from the 132kV
network

provides dedicated 11kV supply to underground coal-mining operations at Myuna and Cooranbong via two of
the zone substations

includes three 33kV-connected mining customers (Mandalong, Awaba and Newstan) and a 33kV connection
for railway supplies at Awaba

consists of approximately 105km of predominantly overhead 33kV feeder network, and

serves most of the area’s 11kV supply needs from Avondale ZS, Toronto ZS and Morisset ZS.
Figure 29: West Lake Macquarie load area
Distribution and Transmission Annual Planning Report December 2013
101
Table 27 – Identified system limitations in West Lake Macquarie load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Cooranbong 33/11kV ZS (dedicated customer)
Asset Condition
5.3.22
2.
Myuna 33/11kV ZS (dedicated customer)
Asset Condition
5.3.22
3.26.2 Sub-transmission feeder load forecast
West Lake Macquarie Area - Feeder Load Forecast
Feeder name
Feeder H730
(Awaba STS To Awaba
Mine)
Feeder H733
(Awaba STS To Toronto
ZS)
Feeder H734
(Awaba STS To Newstan
ZS)
Feeder H735
(Awaba STS To Newstan
ZS)
Feeder H736
(Awaba STS To Toronto
ZS)
Feeder H738
(Awaba STS To Awaba
Mine)
Feeder 752
(Awaba STS to SRA
Awaba)
Feeder H783(1)
(Eraring STS to
Avondale ZS)
Feeder H783(2)
(Eraring STS to
Avondale ZS)
Feeder H784
(Eraring STS To
Cooranbong ZS)
Feeder H785
(Eraring STS To Myuna
ZS)
Feeder H786
(Eraring STS To Myuna
ZS)
Feeder 3710(1)
(Cooranbong ZS To
Avondale ZS)
Feeder 3710(2)
(Cooranbong ZS To
Avondale ZS)
Feeder 3710(3)
(Cooranbong ZS To
Avondale ZS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
Load
33 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
1.3
1.3
1.3
1.3
1.3
1.3
0.7
0.7
0.7
0.7
0.7
0.7
19.4
19.4
19.4
19.4
19.4
19.4
25.1
25.1
25.1
25.1
25.1
25.1
18.7
18.1
-
-
-
-
14.4
14.3
14.2
-
-
-
24.5
24.5
-
-
-
-
28.6
28.6
28.6
-
-
-
7.9
7.9
7.9
7.9
7.9
7.9
8.3
8.3
8.3
8.3
8.3
8.3
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
45.7
7.9
7.9
7.9
7.9
7.9
7.9
8.6
8.3
8.3
8.3
8.3
8.3
27.2
27.2
27.2
27.2
27.2
27.2
30.3
30.3
30.3
30.3
30.3
30.3
18.7
18.1
-
-
-
-
14.4
14.3
14.2
-
-
-
29.4
29.4
-
-
-
-
32.7
32.7
32.7
-
-
-
1.3
1.3
1.3
1.3
1.3
1.3
0.7
0.7
0.7
0.7
0.7
0.7
18.9
18.9
18.9
18.9
18.9
18.9
21.1
21.1
21.1
21.1
21.1
21.1
4.8
4.8
4.8
4.8
4.8
4.8
4.8
4.8
4.8
4.8
4.8
4.8
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
23.7
23.4
23.2
23.1
23.0
22.9
21.1
20.9
20.8
20.9
21.1
21.2
46.8
46.8
46.8
46.8
46.8
46.8
52.5
52.5
52.5
52.5
52.5
52.5
23.3
23.1
22.9
22.8
22.7
22.6
20.8
20.7
20.6
20.7
20.8
21.0
42.3
42.3
42.3
42.3
42.3
42.3
42.3
42.3
42.3
42.3
42.3
42.3
23.7
23.5
23.2
23.1
23.0
22.9
21.1
21.0
20.9
21.0
21.2
21.3
46.8
46.8
46.8
46.8
46.8
46.8
52.5
52.5
52.5
52.5
52.5
52.5
8.0
8.0
8.0
8.0
8.0
8.0
7.0
7.0
7.0
7.0
7.0
7.0
31.2
31.2
31.2
31.2
31.2
31.2
34.5
34.5
34.5
34.5
34.5
34.5
8.0
8.0
8.0
8.0
8.0
8.0
7.0
7.0
7.0
7.0
7.0
7.0
31.2
31.2
31.2
31.2
31.2
31.2
41.4
41.4
41.4
41.4
41.4
41.4
14.3
14.3
14.3
14.4
14.3
14.3
12.7
12.6
12.6
12.6
12.6
12.6
18.2
18.2
18.2
18.2
18.2
18.2
21.6
21.6
21.6
21.6
21.6
21.6
21.4
21.1
20.9
20.8
20.7
20.6
19.8
19.7
19.6
19.7
19.8
20.0
22.9
22.9
22.9
22.9
22.9
22.9
28.6
28.6
28.6
28.6
28.6
28.6
14.8
14.8
14.8
14.8
14.8
14.8
14.6
14.6
14.6
14.6
14.6
14.6
17.2
17.2
17.2
17.2
17.2
17.2
31.2
31.2
31.2
31.2
31.2
31.2
3.26.3 STS and ZS load forecast
West Lake Macquarie Area - STS and ZS details
Summer
Winter
Summer
Winter
Solar
PV
Other
Embedded
Generation
(MVA)
Winter
95% Peak Load
Exceeded
(hrs/yr)
Summer
Licence
Capacity (MVA)
Winter
Substation
Eraring 132/33kV STS
Avondale 33/11kV ZS
Morisset 132/11kV ZS
Rathmines 132/11kV ZS
Rathmin. 132/11kV Temp
Toronto 132/11kV ZS
Toronto 33/11kV ZS
Firm Capacity
(MVA)
Summer
Total Capacity
(MVA)
134.3
45.7
76.2
76.0
34.3
76.0
57.7
134.3
45.7
76.2
76.0
34.3
76.0
57.7
69.5
22.9
38.1
38.0
0.0
38.0
30.5
73.5
22.9
38.1
38.0
0.0
38.0
30.5
69.5
25.2
42.6
42.5
10.0
42.5
34.1
73.5
25.7
45.7
39.1
10.0
38.4
36.6
8.6
11.2
11.2
11.2
11.2
11.2
11.2
4.8
5.0
3.5
3.5
3.5
3.5
3.5
0.97
1.64
1.64
0.75
1.12
-
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
in next 5
years
No
No
No
No
No
No
No
102
SUMMER - West Lake Macquarie Area STS and ZS Load Forecast
Forecast Load
Actual Load
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Substation
MVA
PF
MVA
Avondale 33/11kV ZS
PF
MVA
Morisset 132/11kV ZS
PF
MVA
Rathmines 132/11kV ZS PF
MVA
Rathmin. 132/11kV Temp PF
MVA
Toronto 132/11kV ZS
PF
MVA
Toronto 33/11kV ZS
PF
Eraring 132/33kV STS
33.5
0.90
15.1
0.90
20.8
0.95
12.9
0.92
19.7
0.95
30.6
0.92
13.5
0.92
25.1
0.94
16.5
0.92
18.2
0.95
33.2
0.89
16.3
0.93
23.4
0.92
16.6
0.91
19.7
0.94
31.2
0.90
12.4
0.94
16.3
0.91
11.6
0.92
14.6
0.95
29.6
0.90
15.1
0.95
21.5
0.94
16.6
0.94
18.6
0.95
27.6
0.91
9.7
0.95
22.7
0.94
14.5
0.94
18.2
0.95
27.4
0.91
9.5
0.95
22.7
0.94
14.6
0.94
17.7
0.95
27.2
0.91
9.2
0.95
22.7
0.94
14.6
0.94
17.7
0.95
-
27.1
0.91
9.1
0.95
23.0
0.94
14.8
0.94
17.3
0.95
-
27.0
0.91
9.0
0.95
23.4
0.94
15.1
0.94
17.1
0.95
-
26.9
0.91
8.9
0.95
23.8
0.94
15.5
0.94
17.0
0.95
-
WINTER - West Lake Macquarie Area STS and ZS Load Forecast
Substation
Eraring 132/33kV STS
Avondale 33/11kV ZS
Morisset 132/11kV ZS
Rathmines 132/11kV ZS
Rathmines 132/11kV ZS
Toronto 132/11kV ZS
Toronto 33/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2008
2009
38.8
0.94
21.7
0.94
16.0
0.94
13.9
0.95
18.7
0.96
30.8
0.92
12.8
0.92
18.0
0.94
13.2
0.95
19.9
0.98
Actual Load
2010
2011
29.3
0.93
12.7
0.96
18.5
0.94
12.6
0.95
14.8
0.96
30.8
0.92
12.2
0.96
18.7
0.97
12.5
0.95
14.1
0.97
Distribution and Transmission Annual Planning Report December 2013
2012
2013
2014
Forecast Load
2015
2016
2017
2018
28.1
0.73
11.9
0.97
16.4
0.97
12.3
0.95
13.1
0.97
25.6
0.72
8.6
0.97
20.0
0.97
13.1
0.95
14.1
0.97
25.5
0.72
8.5
0.97
19.7
0.97
13.0
0.95
14.1
0.97
25.4
0.72
8.4
0.97
19.4
0.97
13.0
0.95
14.0
0.97
25.6
0.72
8.7
0.97
20.0
0.97
13.7
0.95
14.3
0.97
-
25.8
0.72
8.9
0.97
20.4
0.97
14.1
0.95
14.7
0.97
-
25.5
0.72
8.5
0.97
19.7
0.97
13.3
0.95
14.0
0.97
-
103
3.27
Transmission Load Area - Central Coast
3.27.1 Description of Central Coast Transmission load area
Ausgrid prepares a Central Coast Transmission Load Area plan that covers all Ausgrid 132kV sub-transmission
assets and dual function assets which operate in parallel and support the main TransGrid transmission network in
the Lower Central Coast and Upper Central Coast sub-transmission load areas. It forms the basis for TransGrid –
Ausgrid joint planning and the sharing of network models and data in the Central Coast area.
The Central Coast transmission load area includes all of the Gosford and Wyong local government areas. The area
extends south from Lake Macquarie to Broken Bay/Brisbane Water. Most of the development in the area has
occurred in a coastal strip to the east of the Sydney to Newcastle expressway. Development is bounded by
bushland to the West of the region, and water to the north, south and east.
The coastal area of the Lower Central Coast is a popular holiday destination and is a dormitory suburb for Sydney.
The area is currently a mix of rural, residential, commercial and industrial land use. The major industries in the area
are coal mining and power generation, both of which are in the northern part of the area.
The Department of Planning’s Regional Strategy for the Central Coast predicts continued population growth in the
area over the next 25 years. 36,000 additional dwellings are expected in the area in the period to 2031, mostly as a
result of in-fill development. As the population grows, industries in the region are likely to generate an increase in
the number of jobs in wholesaling, retailing, property and business services, tourism, health services, cultural and
recreational services and personal services. Although manufacturing jobs will increase in total numbers, the
proportion of manufacturing jobs will decline.
Development in the area is currently constrained by water supply issues, which prevent development of extensive
areas of land west of the Sydney to Newcastle freeway. Greater population growth may be possible if the water
supply issues are resolved.
Ausgrid’s Central Coast transmission system comprises a network of 132kV lines running from north to south along
the length of the Central Coast. The system interconnects TransGrid’s 330/132kV supply points at Vales Point and
Munmorah in the north of the area with TransGrid’s centrally located Tuggerah 330/132kV supply point in the south.
The network extends south from Tuggerah Bulk Supply Point (BSP) through the lower Central Coast, and connects
to the inner metropolitan network at Mt Colah STSS.
The Central Coast 132kV network:

provides 132kV supply to four zone substations and two STSs in the area

supports the TransGrid owned 330/132kV substations at Tuggerah and Munmorah, with Munmorah BSP
currently provide only non-firm supply

operates in parallel with TransGrid’s 330kV system, linking major power stations on the upper Central Coast
area with the Sydney metropolitan area. This means that power flows in the 132kV system are influenced by
the configuration of the 330kV system

has no 132kV busbar at Vales Point bulk supply point although there are two 330/132kV transformers, and
Ausgrid’s single outgoing feeder 957 connects to both 330/132kV transformers. Following the proposed
commissioning of Lake Munmorah 132/11kV zone substation in 2013, the feeder 957 will be connected to
Vales Point BSP transformer No. 2 and the proposed Lake Munmorah zone substation feeder will be
connected to Vales Point BSP transformer No. 1

has no 132kV busbar at Munmorah 330/132kV BSP, and

would require substantial work to establish a 132kV busbar if any additional 132kV feeders were to be
connected to either Munmorah or Vales Point BSP.
Distribution and Transmission Annual Planning Report December 2013
104
Figure 30: Identified system limitations in Central Coast 132kV load area
Table 28 – Identified transmission support limitations in Central Coast Transmission load area
Location
1.
Nil
Distribution and Transmission Annual Planning Report December 2013
Identified
Limitation
Refer to
DAPR section
-
-
105
3.27.2 Sub-transmission feeder load forecast
Central Coast Subtransmission - Feeder Load Forecast
Summer (MVA)
Feeder name
Feeder 268
(Ourimbah STS to
Wamberal ZS)
Feeder 92Z
(Mt Colah STSS to
Sydney East BSP)
Feeder 94L
(Tuggerah BSP to
Brekeley Vale ZS)
Feeder 95C
(Tuggerah BSP to
Ourimbah STS STS)
Feeder 95E
(Gosford STS to
Somersby ZS)
Feeder 95T
(Vales Point BSP to
Lake Munmorah ZS)
Feeder 95Z
(Mt Colah STSS to
Somersby ZS)
Feeder 951
(Ourimbah STS to West
Gosford ZS)
Feeder 954
(Tuggerah BSP to
Berkeley Vale ZS)
Feeder 956
(Gosford STS to West
Gosford ZS)
Feeder 957/1
(Tee Ourimbah STS/
Morisset ZS to
Ourimbah STS)
Feeder 957/3
(Vales Pt BSP to Tee
Ourimbah STS/Morisset
ZS)
Feeder 958
(Tuggerah BSP to
Gosford STS)
Feeder 97E
(Munmorah Power
Station to 97ETee)
(kV)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
Feeder 97E (97ETee to
Charmhaven ZS)
Feeder 97E
(97ETee to Lake
Munmorah ZS)
Feeder 98B
(Charmhaven ZS to
Wyong ZS)
Feeder99C
(Tuggerah BSP to
Wyong ZS)
Winter (MVA)
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
2013
2014
2015
2016
2017
2018
12.1
12.1
12.2
12.5
12.9
13.3
7.3
7.3
7.2
7.5
7.7
8.0
124.0
124.0
124.0
124.0
124.0
124.0
130.0
130.0
130.0
130.0
130.0
130.0
67.7
70.2
70.4
68.5
66.2
68.1
71.6
66.0
63.6
62.7
60.7
59.5
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
46.0
45.5
46.4
46.5
46.2
45.9
37.0
35.8
35.3
35.7
36.1
36.3
275.0
275.0
275.0
275.0
275.0
275.0
338.1
338.1
338.1
338.1
338.1
338.1
206.7
208.3
201.7
208.3
215.2
222.0
212.4
201.7
198.4
201.5
209.0
211.9
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
79.5
81.8
79.0
78.6
77.5
80.9
84.9
77.5
74.6
73.8
73.8
72.7
141.8
141.8
141.8
141.8
141.8
141.8
162.3
162.3
162.3
162.3
162.3
162.3
15.2
19.0
18.9
19.3
19.7
20.2
23.4
25.9
25.1
25.4
25.6
25.8
240.0
240.0
240.0
240.0
240.0
240.0
257.0
257.0
257.0
257.0
257.0
257.0
67.7
70.1
70.3
68.5
66.2
68.4
71.7
66.0
63.6
62.7
60.9
59.7
170.6
170.6
170.6
170.6
170.6
170.6
221.8
221.8
221.8
221.8
221.8
221.8
206.4
207.3
199.2
205.2
210.6
218.5
205.6
194.2
189.3
191.3
196.7
198.7
238.2
238.2
238.2
238.2
238.2
238.2
248.3
248.3
248.3
248.3
248.3
248.3
46.0
45.6
46.5
46.6
46.2
45.9
37.1
35.8
35.4
35.7
36.1
36.3
275.0
275.0
275.0
275.0
275.0
275.0
340.4
340.4
340.4
340.4
340.4
340.4
153.9
156.0
151.2
156.5
160.8
167.9
164.3
152.8
149.4
151.1
155.3
156.9
275.0
275.0
275.0
275.0
275.0
275.0
334.0
334.0
334.0
334.0
334.0
334.0
86.2
88.1
84.8
86.4
86.6
90.3
87.0
87.5
84.1
84.8
85.5
86.3
160.0
160.0
160.0
160.0
160.0
160.0
179.5
179.5
179.5
179.5
179.5
179.5
106.7
108.7
105.3
107.0
107.3
111.1
107.4
108.2
104.6
105.3
105.9
106.9
155.2
155.2
155.2
155.2
155.2
155.2
182.9
182.9
182.9
182.9
182.9
182.9
212.1
213.2
204.7
211.1
217.0
225.4
210.9
199.2
194.2
196.4
202.3
204.6
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
174.4
173.4
167.9
170.6
172.6
178.0
170.7
168.7
163.8
164.9
166.2
167.6
206.0
206.0
206.0
206.0
206.0
206.0
206.0
206.0
206.0
206.0
206.0
206.0
174.4
173.4
168.0
170.6
172.7
178.1
170.7
168.7
163.8
164.9
166.3
167.6
275.0
275.0
275.0
275.0
275.0
275.0
340.0
340.0
340.0
340.0
340.0
340.0
15.2
19.0
18.9
19.3
19.8
20.2
23.4
25.9
25.1
25.3
25.6
25.8
250.7
250.7
250.7
250.7
250.7
250.7
306.4
306.4
306.4
306.4
306.4
306.4
137.6
140.6
135.6
137.3
138.1
142.3
137.8
139.4
135.4
136.0
137.2
137.8
260.0
260.0
260.0
260.0
260.0
260.0
283.7
283.7
283.7
283.7
283.7
283.7
106.5
110.7
106.4
107.9
108.1
112.0
106.5
108.4
105.6
105.6
107.2
106.9
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
243.0
Distribution and Transmission Annual Planning Report December 2013
106
3.27.3 STS and ZS load forecast
The forecast loads for the STS and Zone sub-transmission substations in the Central Coast Transmission Area are
shown in the following load areas, identified by DAPR section below:
Lower Central Coast Load Area

3.8 Lower Central Coast Load Area, and

3.23 Upper Central Coast Load Area.
Distribution and Transmission Annual Planning Report December 2013
107
3.28
Transmission Load Area – Lower Hunter
3.28.1 Description of Lower Hunter 132kV Transmission load area
Ausgrid prepares a Lower Hunter Transmission Load Area plan that covers all Ausgrid 132kV sub-transmission
assets and dual function assets which operate in parallel and support the main TransGrid transmission network in
the Lower Hunter sub-transmission load areas. It forms the basis for TransGrid – Ausgrid joint planning and the
sharing of network models and data in the Lower Hunter transmission area.
The Lower Hunter region supplied by Ausgrid’s 132kV network extends from the Tomaree Peninsula and Karuah in
the north, to Wyee and Swansea in the south. It is bordered on the east by the coastline and extends north-west to
Pokolbin and south-west to Mandalong.
The Lower Hunter 132kV network provides supply to the Ausgrid network serving Cessnock, Lake Macquarie,
Maitland, Newcastle and Port Stephens local government areas; and connection between TransGrid’s 330/132kV
bulk supply points in the Lower Hunter and TransGrid feeders supplying Essential Energy’s Lower North network.
The Lower Hunter 132kV transmission network provides 132kV supply to the following Ausgrid network areas:

Newcastle Inner City

Newcastle Ports

Newcastle Western Corridor

North-East Lake Macquarie

West Lake Macquarie

Port Stephens

Maitland

Greater Cessnock.
Ausgrid has prepared separate area strategy documents for each of these network areas; these documents set out
the supply strategies for each area.
The Lower Hunter 132kV Transmission network:

comprises around 300km of predominantly overhead 132kV feeders

is supplied from the TransGrid transmission network Bulk Supply Points (BSP) at Killingworth (named
Newcastle BSP), Waratah West and Tomago

provides 132kV transmission connections from Tomago BSP to TransGrid feeders supplying the Essential
Energy network at Taree and Stroud

includes 132kV network interconnections to the Upper Hunter 132kV network at Rothbury and the Central
Coast 132kV network via Morisset and Eraring substations

provides 132kV supply connections for the OneSteel manufacturing facilities at Mayfield North and the Hydro
Aluminium Smelter near Kurri Kurri, and

includes nine 132/33kV sub-transmission substations and seven 132/11kV zone substations.
Distribution and Transmission Annual Planning Report December 2013
108
Figure 31: Identified system limitations in Lower Hunter Transmission area
Table 29 – Identified transmission support limitations in Lower Hunter Transmission load area
Location
1.
Awaba 132/33kV
sub-transmission
substation
Identified Limitation
Refer to DAPR
section
Asset Condition
5.3.13
Distribution and Transmission Annual Planning Report December 2013
109
3.28.2 Sub-transmission feeder load forecast
Lower Hunter Transmission Area - Feeder Load Forecast
Feeder name
Feeder 95U
(Muswellbrook BSP to
Singleton STS)
Feeder 95M
(Muswellbrook BSP to
Mitchell Line STS)
Feeder 95H
(Muswellbrook BSP to
Muswellbrook STS)
Feeder 95H
(Muswellbrook BSP to
Muswellbrook ZS)
Feeder 95F
(Mitchell Line STS to
Muswellbrook STS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Feeder 95F
(Mitchell Line STS to
Muswellbrook ZS)
132 Rating
Feeder 955
(Redbank PS to
Singleton STS)
132 Rating
Load
2014
Winter (MVA)
2015
2016
2017
2018
127.2
142.3
162.9
163.6
164.7
166.0
137.6
141.5
175.3
175.6
176.0
176.9
238.0
238.0
238.0
238.0
238.0
238.0
238.0
238.0
238.0
238.0
238.0
238.0
139.4
150.1
164.9
165.0
166.3
167.7
129.8
133.4
157.1
162.2
158.4
159.1
238.0
238.0
238.0
238.0
238.0
238.0
253.0
253.0
253.0
253.0
253.0
253.0
124.9
130.8
138.2
-
-
-
107.4
108.4
120.3
-
-
-
290.0
290.0
290.0
-
-
-
306.0
306.0
306.0
-
-
-
-
-
-
135.8
136.6
137.5
-
-
-
130.7
120.3
120.9
-
-
-
290.0
290.0
290.0
-
-
-
306.0
306.0
306.0
104.9
111.1
118.3
-
-
-
90.6
94.8
106.7
-
-
-
171.0
171.0
171.0
-
-
-
181.0
181.0
181.0
-
-
-
-
-
-
119.0
120.0
121.1
-
-
-
119.0
120.0
121.1
-
-
-
181.0
181.0
181.0
-
-
-
181.0
181.0
181.0
18.8
19.0
19.1
19.4
19.7
19.9
10.4
12.2
12.4
12.6
12.8
13.0
200.3
200.3
200.3
200.3
200.3
200.3
223.6
223.6
223.6
223.6
223.6
223.6
129.0
143.9
166.1
167.2
168.7
170.1
139.0
143.1
178.5
179.1
179.6
180.3
290.0
290.0
290.0
290.0
290.0
290.0
306.0
306.0
306.0
306.0
306.0
306.0
101.9
109.3
93.4
78.5
70.2
88.2
87.1
68.9
66.1
67.6
48.2
50.2
166.0
166.0
166.0
166.0
166.0
166.0
186.0
186.0
186.0
186.0
186.0
186.0
109.9
117.7
100.7
84.9
75.9
95.3
93.8
74.4
71.3
72.9
52.1
54.3
132 Rating
128.0
128.0
128.0
128.0
128.0
128.0
143.0
143.0
143.0
143.0
143.0
143.0
Feeder 98A
Load
(Tomago STS to Tomago
BSP)
132 Rating
111.1
118.1
119.3
120.9
123.9
126.9
82.7
83.7
79.7
80.0
80.3
80.8
166.0
166.0
166.0
166.0
166.0
166.0
186.0
186.0
186.0
186.0
186.0
186.0
Feeder 9F4
Load
(Tomago STS to Tomago
BSP)
132 Rating
111.1
117.9
119.2
120.9
123.8
126.9
82.6
83.6
79.6
80.0
80.2
80.8
290.0
290.0
290.0
290.0
290.0
290.0
308.0
308.0
308.0
308.0
308.0
308.0
0.9
6.6
6.6
6.7
6.9
7.1
-
3.1
6.5
6.7
6.8
6.9
166.0
166.0
166.0
166.0
166.0
166.0
-
224.2
224.2
224.2
224.2
224.2
0.9
6.7
6.7
6.8
7.0
7.1
-
3.1
6.6
6.7
6.8
7.0
213.2
213.2
213.2
213.2
213.2
213.2
-
293.4
293.4
293.4
293.4
293.4
64.2
64.0
63.7
63.4
64.5
65.1
52.4
51.9
50.8
51.7
52.1
52.8
154.0
154.0
154.0
154.0
154.0
154.0
172.0
172.0
172.0
172.0
172.0
172.0
23.1
22.5
21.8
21.5
21.2
21.0
11.7
11.3
11.0
10.9
10.9
11.0
154.0
154.0
154.0
154.0
154.0
154.0
172.0
172.0
172.0
172.0
172.0
172.0
45.7
44.7
44.4
44.5
45.0
45.6
33.8
33.3
32.7
33.2
33.7
34.4
154.0
154.0
154.0
154.0
154.0
154.0
172.0
172.0
172.0
172.0
172.0
172.0
Feeder 95X
(Singleton STS to
Mitchell Line STS)
Feeder 98N
(Beresfield STS to
Tomago BSP)
Feeder 98R
(Beresfield STS to
Tomago STS)
Feeder 9C5
(Brandy Hill ZS to
Tomago BSP)
Feeder 96F
(Tomago BSP to Stroud
STS)
Feeder 950
(Newcastle BSP to
Jesmond ZS)
Feeder 96Z
(Newcastle BSP to
Maryland ZS)
Load
2013
Load
132 Rating
Load
132 Rating
Load
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Feeder 9F5
Load
(Jesmond ZS to Waratah
STS)
132 Rating
Feeder 96J
(Maryland ZS to
Waratah STS)
Feeder 960/1
(Newcastle BSP to tee
Argenton STS and
Charlestown)
Load
132 Rating
Load
132 Rating
23.1
22.5
21.8
21.5
21.2
21.0
11.7
11.3
11.0
10.9
10.9
11.0
137.0
138.0
139.0
140.0
141.0
142.0
137.0
138.0
139.0
140.0
141.0
142.0
356.4
373.1
372.7
376.3
383.6
391.1
245.0
269.2
265.6
269.9
274.2
279.6
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
Distribution and Transmission Annual Planning Report December 2013
110
Lower Hunter Transmission Area - Feeder Load Forecast
Feeder name
Feeder 9F9/2A
(Glebe SS to
Merewether STS)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Feeder 9F9/2B
Load
(Glebe SS to
Merewether STS)
132 Rating
Feeder 961/1
(Newcastle BSP to tee
Load
Argenton STS and Glebe
SS)
132 Rating
Load
Feeder 961/2
(tee to Glebe SS)
132 Rating
Feeder 961/3
(tee to Argenton STS)
132 Rating
Load
Feeder 961/2A
(Glebe SS to
Merewether STS)
Feeder 961/2B
(Glebe SS to
Merewether STS)
Feeder 9F9
(Charlestown ZS to
Glebe SS)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
Feeder 9N9/3
(tee to Waratah STS)
Feeder 9N9/2
(Waratah West BSP to
Waratah STS and
Broadmeadow)
Feeder 9F8
(Merewether STS to
Broadmeadow ZS)
Feeder 95A
(Newcastle BSP to
Awaba STS)
Feeder 95G
(Awaba STS to
Rathmines ZS)
Feeder 9F3
(Eraring STS to
Rathmines ZS)
Feeder 952
(Newcastle BSP to
Rathmines ZS)
Feeder 95Y/1
(Eraring STS to tee
Morisset & Rathmines )
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
Feeder 95Y/2
(tee to Morisset)
132 Rating
Load
Feeder 95Y/3
(tee to Rathmines)
Feeder 96W
(Newcastle BSP to
Hydro Aluminium
Smelter)
132 Rating
Load
132 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
93.4
100.7
100.1
100.7
102.3
104.0
62.9
74.7
73.4
74.2
75.0
76.1
164.5
164.5
164.5
164.5
164.5
164.5
174.0
174.0
174.0
174.0
174.0
174.0
93.4
100.7
100.1
100.7
102.3
104.0
62.9
74.7
73.4
74.2
75.0
76.1
164.5
164.5
164.5
164.5
164.5
164.5
174.0
174.0
174.0
174.0
174.0
174.0
356.9
372.9
373.1
376.7
383.9
391.3
244.9
269.5
265.9
270.2
274.1
279.8
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
549.0
128.3
130.2
132.3
135.2
139.1
143.4
85.3
85.5
85.9
88.4
90.8
93.9
282.0
282.0
282.0
282.0
282.0
282.0
282.0
282.0
282.0
282.0
282.0
282.0
223.7
237.2
235.3
235.8
238.9
241.7
158.0
181.9
178.0
179.7
181.2
183.7
274.0
274.0
274.0
274.0
274.0
274.0
274.0
274.0
274.0
274.0
274.0
274.0
64.1
65.1
66.2
67.6
69.5
71.7
42.7
42.8
42.9
44.2
45.4
46.9
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
64.1
65.1
66.2
67.6
69.5
71.7
42.7
42.8
42.9
44.2
45.4
46.9
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
141.0
186.8
201.4
200.2
201.5
204.7
208.1
125.8
149.5
146.7
148.4
150.1
152.3
329.0
329.0
329.0
329.0
329.0
329.0
348.0
348.0
348.0
348.0
348.0
348.0
70.2
69.8
70.2
63.5
64.1
64.7
52.2
51.7
51.1
51.6
52.1
52.8
264.0
264.0
264.0
264.0
264.0
264.0
264.0
264.0
264.0
264.0
264.0
264.0
70.2
69.8
70.2
63.6
64.2
64.8
52.2
51.7
51.2
51.6
52.1
52.8
273.0
273.0
273.0
273.0
273.0
273.0
292.0
292.0
292.0
292.0
292.0
292.0
14.9
29.9
29.3
29.1
29.2
29.3
-
23.5
23.0
23.1
23.3
23.6
274.0
274.0
274.0
274.0
274.0
274.0
-
286.5
286.5
286.5
286.5
286.5
64.5
64.0
43.3
51.6
51.3
55.1
59.2
73.4
64.5
41.5
50.4
52.9
154.0
154.0
154.0
154.0
154.0
154.0
171.0
171.0
171.0
171.0
171.0
171.0
39.0
38.7
43.3
51.6
51.3
55.1
41.0
55.5
46.4
41.5
50.4
52.9
154.0
154.0
154.0
154.0
154.0
154.0
171.0
171.0
171.0
171.0
171.0
171.0
23.4
23.2
23.1
22.9
22.9
22.8
22.8
22.7
23.0
23.1
22.5
23.0
59.0
59.0
59.0
59.0
59.0
59.0
64.0
64.0
64.0
64.0
64.0
64.0
63.7
63.3
65.0
77.1
76.8
80.6
58.9
73.3
64.2
60.1
71.8
74.5
166.9
166.9
166.9
166.9
166.9
166.9
186.3
186.3
186.3
186.3
186.3
186.3
23.7
23.2
23.1
23.2
22.9
22.8
22.8
23.1
23.0
22.7
23.2
23.0
59.4
59.4
59.4
59.4
59.4
59.4
64.0
64.0
64.0
64.0
64.0
64.0
14.8
14.5
26.4
31.9
31.6
35.6
22.4
31.5
22.2
20.2
32.9
34.5
134.0
134.0
134.0
134.0
134.0
134.0
148.0
148.0
148.0
148.0
148.0
148.0
32.9
32.2
41.7
51.4
50.9
54.9
35.5
51.8
41.4
39.0
50.2
52.7
134.0
134.0
134.0
134.0
134.0
134.0
148.0
148.0
148.0
148.0
148.0
148.0
35.7
36.0
36.1
40.7
41.4
44.1
26.2
26.1
26.2
26.6
30.3
30.8
249.0
249.0
249.0
249.0
249.0
249.0
271.0
271.0
271.0
271.0
271.0
271.0
Distribution and Transmission Annual Planning Report December 2013
111
Lower Hunter Transmission Area - Feeder Load Forecast
Feeder name
Feeder 96B
(Newcastle BSP to
Hydro Aluminium
Smelter)
Feeder 95L
(Hydro Aluminium
Smelter to Kurri STS)
Feeder 96U
(Kurri ZS to Newcastle
BSP)
Summer (MVA)
2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
Feeder 96E
(Kurri STS to Kurri ZS)
Feeder 95R
(Rothbury ZS to Kurri
STS)
Feeder 953
(Rothbury ZS to
Redbank)
Feeder 96A
(Kurri STS to Newcastle
BSP)
Feeder 9NA
(Beresfield STS to
Newcastle BSP)
Feeder 99Y
(Beresfield STS to Kurri
STS)
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
2013
2014
Winter (MVA)
2015
2016
2017
2018
37.1
37.4
37.5
42.2
42.9
45.8
27.2
27.1
27.2
27.6
31.4
32.0
290.0
290.0
290.0
290.0
290.0
290.0
308.0
308.0
308.0
308.0
308.0
308.0
68.4
69.1
69.2
78.6
79.8
85.4
49.5
49.1
49.5
50.2
57.7
58.8
290.0
290.0
290.0
290.0
290.0
290.0
308.0
308.0
308.0
308.0
308.0
308.0
50.8
51.1
51.4
57.7
58.8
62.7
36.6
36.5
36.7
37.3
42.4
43.3
249.0
249.0
249.0
249.0
249.0
249.0
271.0
271.0
271.0
271.0
271.0
271.0
27.4
27.7
28.0
32.7
31.8
35.0
21.5
19.8
20.3
20.3
24.8
25.1
249.0
249.0
249.0
249.0
249.0
249.0
271.0
271.0
271.0
271.0
271.0
271.0
12.9
12.9
12.9
13.0
13.2
13.5
6.2
6.9
6.8
7.0
7.2
7.4
166.0
166.0
166.0
166.0
166.0
166.0
186.0
186.0
186.0
186.0
186.0
186.0
12.5
12.5
12.5
12.6
12.8
13.1
6.4
7.0
7.0
7.1
7.3
7.6
167.0
167.0
167.0
167.0
167.0
167.0
167.0
167.0
167.0
167.0
167.0
167.0
67.3
67.8
68.0
77.0
78.2
83.6
48.9
48.6
48.9
49.7
56.8
57.9
290.0
290.0
290.0
290.0
290.0
290.0
308.0
308.0
308.0
308.0
308.0
308.0
26.9
43.4
25.6
45.6
40.1
48.2
53.6
18.0
20.3
18.8
28.0
28.4
223.0
223.0
223.0
223.0
223.0
223.0
237.0
237.0
237.0
237.0
237.0
237.0
45.3
46.5
45.4
32.3
32.6
32.7
59.1
38.2
37.5
37.9
28.4
29.4
166.0
166.0
166.0
166.0
166.0
166.0
186.0
186.0
186.0
186.0
186.0
186.0
3.28.3 STS and ZS load forecast
The forecast loads for the STS and Zone sub-transmission substations in the Lower Hunter Transmission area are
shown in the following load areas, identified by DAPR section below:

3.6 Greater Cessnock Load Area

3.10 Maitland Load Area

3.12 Newcastle Inner City Load Area

3.13 Newcastle Ports Load Area

3.14 Newcastle Western Corridor Load Area

3.15 North-East Lake Macquarie Load Area

3.18 Port Stephens

3.26 West Lake Macquarie Load Area.
Distribution and Transmission Annual Planning Report December 2013
112
3.29
Sydney Inner Metropolitan Transmission Load Area
3.29.1 Description of Sydney Inner Metropolitan Transmission load area
Ausgrid prepares a Sydney Inner Metropolitan Transmission Load Area plan that covers all Ausgrid 132kV subtransmission assets and dual function assets which operate in parallel and support the main TransGrid
transmission network in the Sydney Metropolitan sub-transmission load areas. It forms the basis for TransGrid –
Ausgrid joint planning and the sharing of network models and data for the Sydney Metropolitan transmission area.
The Sydney Inner Metropolitan 132kV transmission network provides 132kV supply to the following Ausgrid
network load areas:

Camperdown and Blackwattle Bay Load Area

Canterbury Bankstown Load Area

Carlingford Load Area

Eastern Suburbs Load Area

Inner West Load Area 
Lower North Shore Load Area 
Manly Warringah Load Area 
North West Sydney Load Area 
Pittwater and Terrey Hills Load Area 
St George Load Area 
Sutherland Load Area 
Sydney CBD Load Area 
Upper North Shore Load Area. The Sydney Inner Metropolitan transmission network supplies most of the eastern part of the Sydney metropolitan
area. The load area extends from the Pacific Ocean, west to Ryde and Auburn, and is bounded to the south by the
Royal National Park and to the north by the Hawkesbury River, but excludes the area east of the Lane Cove River
valley.
The Inner Metropolitan transmission system is defined as TransGrid’s 330kV cables 41 and 42, and the 330/132kV
substations at Beaconsfield, Haymarket, Rookwood Road (commissioning due in 2014), Sydney North and Sydney
South, together with Ausgrid’s 132kV dual function network that links those supply points. Total demand within the
area amounts to more than 4,000MW.
Sydney North and Sydney South Bulk Supply Point substations are strongly connected to the main NSW 330kV
transmission network, and TransGrid makes firm 132kV capacity available at both locations. Beaconsfield and
Haymarket substations are supplied by a single 330kV cable each, and Ausgrid’s interconnected 132kV dual
function network provides the necessary connections to provide supply redundancy from these substations.
This integrated supply arrangement has been in place since the mid-1970s and has been progressively developed
through joint planning between TransGrid and Ausgrid. It represents the least cost solution to meet existing
capacity requirements while providing the greatest potential to maximise the utilisation of all network assets.
Following commissioning of Rookwood Road BSP in 2014, the Sydney North 132kV network will be completely
separated via open points from the remaining 132kV system due to fault level limitations. However, to support the
remaining meshed 330kV and 132kV network, there remains the opportunity to transfer some load back to the
Sydney North network via these open points.
Distribution and Transmission Annual Planning Report December 2013
113
Figure 32: Identified limitations in Sydney Inner Metropolitan transmission load area
Distribution and Transmission Annual Planning Report December 2013
114
Table 30 – Identified system limitations in Sydney Inner Metropolitan Transmission load area
Location
Identified
Limitation
Refer to
DAPR section
1.
Feeder 9SA - Beaconsfield BSP to Campbell St ZS
Capacity
5.2.13
2.
Feeder 92P - Beaconsfield BSP - Belmore Park Zn
Capacity
5.2.13
3.
Feeder 91X - Chullora STSS to Beaconsfield BSP
Capacity
5.2.13
4.
Feeder 91Y - Chullora STSS to Beaconsfield BSP
Capacity
5.2.13
5.
Feeder 92C - Chullora STSS to Beaconsfield BSP (formerly
91A/2)
Capacity
5.2.13
6.
Feeder 92X - Chullora STSS to Beaconsfield BSP (formerly
91B/2)
Capacity
5.2.13
7.
Feeder 9S6/1 - Haymarket BSP to Pyrmont STS
Capacity
5.2.13
8.
Feeders 92FA and 92FB - Mason Park STSS to Top Ryde
ZS
Asset Condition
5.2.13
9.
Feeder 91A/2 - Chullora STSS to Beaconsfield BSP
Asset Condition
5.2.13
10.
Feeders 928/3 and 929/1 - Lane Cove STS to Dalley St ZS
Asset Condition
5.2.13
11.
Feeders 92GA and 92GB - Lane Cove STSS to Top Ryde
ZS
Asset Condition
5.2.13
12.
Feeders 92JA and 92JB - Lane Cove STSS to
Meadowbank ZS
Asset Condition
5.2.13
13.
Feeders 90XA and 90XB - Mason Park STSS to
Meadowbank ZS
Asset Condition
5.2.13
Distribution and Transmission Annual Planning Report December 2013
115
3.29.2 Sub-transmission feeder load forecast
Inner Metropolitan Area - Feeder Load Forecast
Feeder name
Feeder 202
(Drummoyne - Rozelle
STS)
Feeder 203
(Mason Park STSS Drummoyne)
Feeder 204
(Mason Park STSS Drummoyne)
Feeder 91F
(Sydney South BSP Peakhurst STS)
Feeder 91J: (Sydney
South BSP - Peakhurst
STS)
Feeder 91C
(Peakhurst STS Kogarah)
Feeder 91C
(Peakhurst STS Hurstville North)
Feeder 91H
(Peakhurst STS Kogarah)
Feeder 91R:
(Peakhurst STS Hurstville North)
Feeder 91W:
(Hurstville North Kogarah)
Feeder 91H/1
(Kogarah - Hurstville
North)
Feeder 91H/2(1)
(Kogarah - Rockdale
132kV)
Feeder 91H/2(2)
(Beaconsfield West BSP
- Rockdale 132kV)
Feeder 91H/2(2)
(Marrickville - Rockdale
132kV)
Feeder 914
(Sydney South BSP Bankstown STS)
Feeder 915
(Sydney South BSP Bankstown STS)
Feeder 916 (1)
(Sydney South BSP Cronulla)
Feeder 917(1)
(Sydney South BSP Gwawley Bay)
Feeder 917 (3) (Gwawley
Bay - Gwawley Bay)
Feeder 917(2)
(Kurnell STS - Gwawley
Bay)
Feeder 906
(Beaconsfield West BSP
- Canterbury STS)
Feeder 906
(Marrickville - Canterbury
STS)
Feeder 907
(Canterbury STS Kogarah)
Feeder 910(3)
(Sydney South BSP Chullora STSS)
Feeder 910 (1)
(Sydney South BSP Sydney South BSP)
Feeder 910 (2)
(Sydney South BSP Canterbury STS)
Feeder 911(3)
(Sydney South BSP Chullora STSS)
2017/18
2018/19
2013
2014
Winter (MVA)
2015
2016
2017
107.6
108.6
109.8
107.4
102.1
85.4
73.9
74.5
75.0
155.5
155.5
155.5
155.5
164.6
164.6
164.6
164.6
164.6
164.6
139.3
104.8
108.3
111.1
114.5
112.9
108.4
86.1
89.4
90.1
91.1
217.2
217.2
217.2
217.2
217.2
228.6
228.6
228.6
228.6
228.6
228.6
144.0
139.8
105.3
108.9
111.7
115.1
113.3
108.7
86.6
89.9
90.6
91.6
217.2
217.2
217.2
217.2
217.2
217.2
228.6
228.6
228.6
228.6
228.6
228.6
376.8
370.9
337.4
346.0
357.0
368.3
341.4
328.5
348.6
303.9
310.7
319.2
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
376.8
370.9
337.4
346.0
357.0
368.3
341.4
328.5
348.6
303.9
310.7
319.2
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
-
-
-
-
-
-
34.5
-
-
-
-
-
-
-
-
-
-
-
254.9
-
-
-
-
-
184.0
187.1
223.9
229.7
235.5
241.2
-
158.3
177.9
202.5
208.4
215.3
296.0
296.0
296.0
296.0
296.0
296.0
-
296.0
296.0
296.0
296.0
296.0
-
-
-
-
-
-
68.9
-
-
-
-
-
-
-
-
-
-
-
254.9
-
-
-
-
-
184.0
187.0
223.9
229.6
235.5
241.2
-
158.3
177.8
202.4
208.4
215.2
296.0
296.0
296.0
296.0
296.0
296.0
-
296.0
296.0
296.0
296.0
296.0
113.7
110.9
121.1
124.3
128.3
133.2
-
97.4
100.6
110.9
114.5
119.1
197.0
197.0
197.0
197.0
197.0
197.0
-
208.0
208.0
208.0
208.0
208.0
113.4
104.0
145.8
149.9
152.7
155.8
-
86.9
100.9
127.5
131.2
134.7
197.0
197.0
197.0
197.0
197.0
197.0
-
208.0
208.0
208.0
208.0
208.0
113.5
103.7
146.3
150.4
153.0
156.6
-
86.8
100.4
127.1
130.8
134.4
200.0
200.0
200.0
200.0
200.0
200.0
-
200.0
200.0
200.0
200.0
200.0
114.1
-
-
-
-
-
-
87.8
-
-
-
-
272.0
-
-
-
-
-
-
280.0
-
-
-
-
-
103.7
146.7
150.8
153.0
157.3
-
-
100.2
126.9
130.5
134.3
-
200.0
200.0
200.0
200.0
200.0
-
-
200.0
200.0
200.0
200.0
229.1
96.1
94.6
95.9
98.5
101.1
195.2
89.6
88.1
88.5
89.0
90.1
300.6
300.6
300.6
300.6
300.6
300.6
302.0
302.0
302.0
302.0
302.0
302.0
(kV)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Summer (MVA)
2015/16 2016/17
2013/14
2014/15
154.2
147.8
123.1
155.5
155.5
143.6
217.2
2018
229.1
96.1
94.6
95.9
98.5
101.1
195.2
89.6
88.1
88.5
89.0
90.1
300.6
300.6
300.6
300.6
300.6
300.6
302.0
302.0
302.0
302.0
302.0
302.0
228.1
225.7
264.7
270.9
276.5
284.4
236.1
220.3
236.7
258.5
263.5
269.9
457.0
457.0
457.0
457.0
457.0
457.0
457.0
457.0
457.0
457.0
457.0
457.0
212.5
209.0
247.3
252.5
257.1
263.5
208.2
191.9
209.0
230.7
235.5
241.3
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
32.7
33.4
33.3
34.1
35.3
36.5
27.2
26.3
25.4
25.2
25.3
25.5
272.0
272.0
272.0
272.0
272.0
272.0
280.0
280.0
280.0
280.0
280.0
280.0
186.9
183.3
220.8
225.4
229.5
233.6
185.1
168.7
186.8
208.8
213.5
218.9
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
439.0
132.3
-
-
-
-
-
-
96.1
-
-
-
-
200.0
-
-
-
-
-
-
200.0
-
-
-
-
-
119.7
170.1
174.9
177.8
162.8
-
-
114.5
144.7
149.5
154.0
-
200.0
200.0
200.0
200.0
200.0
-
-
200.0
200.0
200.0
200.0
80.4
82.0
81.3
83.4
87.1
91.2
-
71.2
71.2
74.0
76.7
80.5
200.0
200.0
200.0
200.0
200.0
200.0
-
200.0
200.0
200.0
200.0
200.0
48.8
42.5
59.7
61.4
62.5
64.5
48.3
33.3
40.4
50.7
52.3
53.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
156.6
151.8
177.9
182.6
187.3
192.7
160.1
137.2
147.6
162.9
167.0
172.0
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
123.1
122.0
142.0
145.7
149.4
150.5
124.4
113.3
119.3
130.7
133.7
137.2
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
48.8
42.5
59.7
61.4
62.5
64.5
48.3
33.3
40.4
50.7
52.3
53.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
182.9
Distribution and Transmission Annual Planning Report December 2013
116
Inner Metropolitan Area - Feeder Load Forecast
Feeder name
(kV)
Feeder 911 (1) (Sydney
South BSP - Sydney
South BSP)
Feeder 911 (2) (Sydney
South BSP - Canterbury
STS)
Load
132 Rating
Load
2013/14
2014/15
156.6
151.8
Summer (MVA)
2015/16 2016/17
177.9
182.6
2017/18
2018/19
2013
2014
Winter (MVA)
2015
2016
2017
2018
187.3
192.7
160.1
137.2
147.6
167.0
172.0
162.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
246.9
123.1
122.0
142.0
145.7
149.4
150.5
124.4
113.3
119.3
130.7
133.7
137.2
132 Rating
260.0
260.0
260.0
260.0
260.0
260.0
274.4
274.4
274.4
274.4
274.4
274.4
Feeder 245 (Bunnerong
Load
STSS - Bunnerong North
132 Rating
STS)
136.4
131.7
166.1
170.1
173.3
176.2
121.5
104.2
120.5
140.4
144.1
147.6
219.0
219.0
219.0
219.0
219.0
219.0
228.6
228.6
228.6
228.6
228.6
228.6
136.7
132.0
166.5
170.5
173.7
176.6
121.8
104.5
120.8
140.7
144.4
148.0
220.0
220.0
220.0
220.0
220.0
220.0
230.0
230.0
230.0
230.0
230.0
230.0
103.8
126.5
91.9
91.2
98.1
106.7
93.7
120.9
115.8
104.5
105.2
107.0
251.0
251.0
251.0
251.0
251.0
251.0
265.7
265.7
265.7
265.7
265.7
265.7
Load
Feeder 246 (Bunnerong
STSS - Canterbury STS) 132 Rating
Feeder 264
Load
(Beaconsfield West BSP
132 Rating
- Kingsford)
69.9
92.6
58.4
57.0
63.0
70.7
50.9
81.8
74.4
61.3
60.2
59.5
250.4
250.4
250.4
250.4
250.4
250.4
265.2
265.2
265.2
265.2
265.2
265.2
-
-
-
-
-
-
117.2
-
-
-
-
-
-
-
-
-
-
-
248.3
-
-
-
-
-
Feeder 91M/1
Load
(Beaconsfield West BSP
132 Rating
- Peakhurst STS)
128.6
119.4
-
-
-
-
118.2
109.2
114.9
-
-
-
198.9
198.9
-
-
-
-
201.6
201.6
201.6
-
-
-
Feeder 91M/3:
Load
(Beaconsfield West BSP
132 Rating
- Bunnerong STSS)
111.4
154.5
129.6
128.3
130.6
134.9
104.5
155.2
152.4
147.5
146.0
146.8
198.9
198.9
198.9
198.9
198.9
198.9
201.6
201.6
201.6
201.6
201.6
201.6
Feeder 90F
(Mason Park STSS Chullora STSS)
135.4
-
-
-
-
-
135.0
-
-
-
-
-
571.6
-
-
-
-
-
571.6
-
-
-
-
-
136.8
-
-
-
-
-
135.1
-
-
-
-
-
571.6
-
-
-
-
-
571.6
-
-
-
-
-
47.9
63.9
63.9
65.4
63.3
69.6
82.0
31.7
64.0
68.3
63.0
60.5
102.0
102.0
102.0
102.0
102.0
102.0
109.0
109.0
109.0
109.0
109.0
109.0
73.7
82.6
98.9
99.6
100.2
108.1
49.1
65.0
84.1
91.8
90.8
93.2
132 Rating
104.0
104.0
104.0
104.0
104.0
104.0
113.0
113.0
113.0
113.0
113.0
113.0
Feeder 91B
Load
(Beaconsfield West BSP
- St. Peters)
132 Rating
48.0
64.0
64.2
65.5
63.8
70.1
82.4
32.1
64.2
68.5
63.1
60.8
102.0
102.0
102.0
102.0
102.0
102.0
109.0
109.0
109.0
109.0
109.0
109.0
Feeder 92X
(St. Peters - Chullora
STSS)
74.1
83.0
99.3
100.0
100.6
108.5
49.3
65.0
84.3
92.1
91.2
93.5
104.0
104.0
104.0
104.0
104.0
104.0
113.0
113.0
113.0
113.0
113.0
113.0
Feeder 270
- Kingsford)
(Maroubra
Feeder 91L
(Peakhurst STS Bunnerong STSS)
Feeder 90J
(Mason Park STSS Chullora STSS)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Feeder 91A
Load
(Beaconsfield West BSP
- St. Peters)
132 Rating
Feeder 92C
(Chullora STSS - St.
Peters)
Load
Load
132 Rating
Feeder 9F6
Load
(Beaconsfield West BSP
- Marrickville)
132 Rating
97.2
100.1
150.4
155.4
158.6
142.8
76.2
40.4
93.4
123.7
128.3
132.4
99.0
200.0
200.0
200.0
200.0
200.0
106.0
106.0
200.0
200.0
200.0
200.0
Feeder 91X/2
(Chullora STSS Marrickville)
73.6
-
-
-
-
-
47.3
70.8
-
-
-
-
100.0
-
-
-
-
-
110.0
110.0
-
-
-
-
Load
132 Rating
Feeder 91U
Load
(Beaconsfield West BSP
132 Rating
- Marrickville)
97.2
83.5
126.6
130.7
133.4
136.4
76.2
40.3
78.3
105.2
108.7
112.1
99.0
200.0
200.0
200.0
200.0
200.0
106.0
106.0
200.0
200.0
200.0
200.0
Feeder 91Y/2
(Marrickville - Chullora
STSS)
73.7
-
-
-
-
-
47.4
70.8
-
-
-
-
106.0
-
-
-
-
-
110.0
110.0
-
-
-
-
Feeder 91X
Load
(Beaconsfield West BSP
132 Rating
- Chullora STSS)
-
84.0
100.4
101.0
101.4
109.6
-
-
85.7
93.5
92.3
94.6
-
99.0
99.0
99.0
99.0
99.0
-
-
106.0
106.0
106.0
106.0
Feeder 91Y
Load
(Beaconsfield West BSP
132 Rating
- Chullora STSS)
-
84.0
100.4
101.0
101.4
109.6
-
-
85.7
93.5
92.3
94.6
-
99.0
99.0
99.0
99.0
99.0
-
-
106.0
106.0
106.0
106.0
Feeder 240 (1)
(Chullora STSS Rookwood Tee)
-
134.4
180.1
181.3
184.6
196.1
-
105.1
157.2
172.1
170.6
173.2
-
250.0
250.0
250.0
250.0
250.0
-
264.0
264.0
264.0
264.0
264.0
-
229.2
268.7
269.7
273.9
288.5
-
145.8
229.3
242.5
241.3
245.4
-
500.0
500.0
500.0
500.0
500.0
-
500.0
500.0
500.0
500.0
500.0
-
103.1
98.5
98.3
100.0
101.3
-
49.2
77.8
77.8
78.6
80.4
-
205.0
205.0
205.0
205.0
205.0
-
235.0
235.0
235.0
235.0
235.0
Feeder 240 (2)
(Rookwood BSP Rookwood Tee)
Load
132 Rating
Load
132 Rating
Load
132 Rating
Feeder 240 (3)
(Potts Hill - Rookwood
Tee)
132 Rating
Feeder 295
(Sefton - Potts Hill)
132 Rating
Feeder 296(2)
(Sefton - Sefton)
42.4
42.7
42.8
43.0
43.8
45.9
58.7
28.3
33.2
34.4
34.3
34.9
132 Rating
243.0
243.0
243.0
243.0
243.0
243.0
284.0
284.0
284.0
284.0
284.0
284.0
Load
Feeder 291/1 (Greenacre
132 Rating
Park - Potts Hill)
68.0
20.0
19.5
19.5
19.6
19.6
38.6
15.0
14.6
14.7
14.8
15.0
156.0
156.0
156.0
156.0
156.0
156.0
165.0
165.0
165.0
165.0
165.0
165.0
Feeder 240/3
(Bankstown STS Greenacre Park)
91.0
-
-
-
-
-
69.7
-
-
-
-
-
233.2
-
-
-
-
-
245.8
-
-
-
-
-
Load
Load
Load
Load
132 Rating
21.5
42.7
42.0
42.5
43.4
44.4
29.4
14.2
27.3
27.4
27.5
27.8
275.0
275.0
275.0
275.0
275.0
275.0
294.0
294.0
294.0
294.0
294.0
294.0
Distribution and Transmission Annual Planning Report December 2013
117
Inner Metropolitan Area - Feeder Load Forecast
Feeder name
(kV)
Feeder 291/2
(Bankstown STS Greenacre Park)
132 Rating
Feeder 241(1)
(Chullora STSS Rookwood Tee)
132 Rating
Feeder 241(2)
(Rookwood BSP Rookwood Tee)
Load
Load
Load
132 Rating
Feeder 241(3)
(Potts Hill - Rookwood
Tee)
132 Rating
Feeder 292
(Greenacre Park - Potts
Hill)
132 Rating
Feeder 296 (1)
(Sefton - Potts Hill)
132 Rating
Feeder 296(2)
(Rookwood BSP Sefton)
132 Rating
Feeder 296(3)
(Bankstown STS Sefton)
132 Rating
Feeder 900
(Mason Park STSS Rozelle STS)
132 Rating
Feeder 9P2
(Mason Park STSS Croydon Road)
132 Rating
Feeder 9P8
(Croydon Road Leichhardt 132kV)
132 Rating
Feeder 9P9
(Rozelle STS Leichhardt 132kV)
132 Rating
Feeder 90V/1:
(Haymarket BSP - City
South)
132 Rating
Feeder 90V/2
(City Central - City
South)
132 Rating
Feeder 90V/3
(Rozelle STS - City
Central)
132 Rating
Feeder 90W/1
(Haymarket BSP - City
South)
132 Rating
Feeder 90W/2
(City Central - City
South)
132 Rating
Feeder 90W/3
(Pyrmont STS - City
Central)
132 Rating
Feeder 90W/4
(Rozelle STS - Pyrmont
STS)
132 Rating
Feeder 90P/1
(Haymarket BSP - City
South)
132 Rating
Feeder 90P/2
(City Central - City
South)
132 Rating
Feeder 9S6/1:
(Haymarket BSP Pyrmont STS)
132 Rating
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Load
Summer (MVA)
2015/16 2016/17
2013/14
2014/15
91.0
-
-
233.2
-
-
Winter (MVA)
2015
2016
2017/18
2018/19
2013
2014
-
-
-
69.7
-
-
-
2017
-
2018
-
-
-
-
-
245.8
-
-
-
-
-
134.2
179.8
181.0
184.3
195.7
-
102.6
157.0
171.8
170.3
172.9
280.0
280.0
280.0
280.0
280.0
-
294.0
294.0
294.0
294.0
294.0
-
229.1
268.4
269.5
273.6
288.2
-
145.8
229.1
242.2
241.0
245.2
-
500.0
500.0
500.0
500.0
500.0
-
500.0
500.0
500.0
500.0
500.0
-
103.1
98.6
98.3
100.0
101.3
-
49.6
77.9
77.8
78.6
80.4
-
205.0
205.0
205.0
205.0
205.0
-
235.0
235.0
235.0
235.0
235.0
53.8
39.2
38.1
37.9
19.6
19.6
27.5
28.9
28.0
28.3
28.4
15.0
156.0
156.0
156.0
156.0
156.0
156.0
165.0
165.0
165.0
165.0
165.0
165.0
37.0
-
-
-
-
-
16.9
-
-
-
-
-
243.0
-
-
-
-
-
284.0
-
-
-
-
-
-
42.7
42.7
43.0
43.8
45.8
-
28.2
33.2
34.3
34.2
34.8
-
206.0
206.0
206.0
206.0
206.0
-
284.0
284.0
284.0
284.0
284.0
61.7
-
-
-
-
-
50.8
-
-
-
-
-
225.0
-
-
-
-
-
246.0
-
-
-
-
-
57.5
55.5
-
-
-
-
43.0
41.4
-
-
-
-
98.3
98.3
-
-
-
-
104.0
104.0
-
-
-
-
-
-
92.2
107.4
110.1
113.4
-
-
74.6
89.0
89.6
90.6
-
-
270.0
270.0
270.0
270.0
-
-
270.0
270.0
270.0
270.0
-
-
76.4
73.0
74.1
75.5
-
-
60.2
59.2
59.8
60.4
-
-
200.0
200.0
200.0
200.0
-
-
200.0
200.0
200.0
200.0
-
-
63.8
61.9
64.0
66.2
-
-
45.0
62.4
62.7
63.4
-
-
270.0
270.0
270.0
270.0
-
-
270.0
270.0
270.0
270.0
98.2
95.6
79.8
73.2
73.9
74.6
65.0
62.2
53.4
48.9
49.5
50.0
240.1
240.1
240.1
240.1
240.1
240.1
251.5
251.5
251.5
251.5
251.5
251.5
45.8
44.5
38.5
37.8
38.3
39.0
31.9
29.3
27.2
24.4
24.6
24.8
147.5
147.5
147.5
147.5
147.5
147.5
156.6
156.6
156.6
156.6
156.6
156.6
79.9
76.2
67.1
61.9
61.6
62.5
53.7
50.3
45.7
42.0
42.4
42.9
108.1
108.1
108.1
108.1
108.1
108.1
114.5
114.5
114.5
114.5
114.5
114.5
95.2
93.1
77.8
70.3
71.6
72.3
62.4
59.7
50.9
46.8
47.3
47.8
240.1
240.1
240.1
240.1
240.1
240.1
251.5
251.5
251.5
251.5
251.5
251.5
45.8
44.5
38.2
37.8
38.3
39.0
30.4
28.4
25.3
24.3
24.5
24.8
147.5
147.5
147.5
147.5
147.5
147.5
156.6
156.6
156.6
156.6
156.6
156.6
78.6
75.2
66.1
59.4
60.5
61.2
51.5
48.4
43.9
40.2
40.6
41.0
108.1
108.1
108.1
108.1
108.1
108.1
114.5
114.5
114.5
114.5
114.5
114.5
78.1
74.6
65.7
59.1
60.1
60.9
51.3
48.1
43.7
40.0
40.4
40.8
149.5
149.5
149.5
149.5
149.5
149.5
157.5
157.5
157.5
157.5
157.5
157.5
99.6
97.7
82.0
74.5
75.2
76.4
66.2
64.7
54.4
50.2
50.2
50.8
240.1
240.1
240.1
240.1
240.1
240.1
251.5
251.5
251.5
251.5
251.5
251.5
47.2
46.5
39.8
39.4
39.9
40.5
31.1
29.6
25.8
25.4
25.6
25.8
147.5
147.5
147.5
147.5
147.5
147.5
156.6
156.6
156.6
156.6
156.6
156.6
198.8
207.4
196.7
205.2
220.2
228.8
119.1
111.9
111.5
112.8
118.1
124.1
213.8
213.8
213.8
213.8
213.8
213.8
229.0
229.0
229.0
229.0
229.0
229.0
83.8
82.1
74.6
74.9
76.7
70.6
68.1
57.5
52.4
51.2
52.2
53.7
320.1
320.1
320.1
320.1
320.1
213.8
340.7
340.7
340.7
340.7
340.7
340.7
Feeder 9S6/2
Pyrmont STS - Darling
Harbour)
132 Rating
Feeder 9S6/3
(City Central - Darling
Harbour)
62.2
60.2
46.7
47.0
47.6
30.0
25.2
38.8
30.6
29.2
29.6
29.9
132 Rating
108.1
108.1
108.1
108.1
108.1
77.3
114.5
114.5
114.5
114.5
114.5
114.5
Feeder 9S6/4
Load
(City Central - City North
132 Rating
(132kV))
2.2
2.2
2.2
2.2
2.2
2.2
2.5
2.2
2.2
2.2
2.2
2.2
225.0
225.0
225.0
225.0
225.0
225.0
260.0
260.0
260.0
260.0
260.0
260.0
Feeder 90Z/2
(City North (132kV) City South)
28.8
43.8
43.6
43.3
44.0
44.4
18.8
27.7
27.2
27.4
27.8
27.9
132 Rating
155.0
155.0
155.0
155.0
155.0
155.0
179.9
179.9
179.9
179.9
179.9
179.9
Feeder 90Z/1
(Haymarket BSP - City
South)
132 Rating
Feeder 93H
(Haymarket BSP Belmore Park)
132 Rating
Feeder 9S9/1
(Haymarket BSP Pyrmont STS)
Load
Load
Load
Load
Load
Load
132 Rating
73.7
81.9
74.9
69.3
70.2
70.8
48.0
53.2
48.8
45.6
46.1
46.4
240.1
240.1
240.1
240.1
240.1
240.1
251.5
251.5
251.5
251.5
251.5
251.5
91.5
89.9
184.4
204.8
208.8
211.3
101.9
97.6
175.8
183.7
184.7
187.1
272.0
272.0
272.0
272.0
272.0
272.0
280.0
280.0
280.0
280.0
280.0
280.0
148.4
171.3
178.6
192.2
203.5
111.3
96.8
140.4
137.9
140.4
150.0
159.7
228.6
228.6
228.6
228.6
228.6
228.6
242.0
242.0
242.0
242.0
242.0
242.0
Distribution and Transmission Annual Planning Report December 2013
118
Inner Metropolitan Area - Feeder Load Forecast
Feeder name
(kV)
Summer (MVA)
2015/16 2016/17
2013/14
2014/15
83.8
82.1
74.5
320.1
320.1
320.1
2017/18
2018/19
2013
2014
Winter (MVA)
2015
2016
2017
72.8
74.4
77.0
44.3
57.5
52.4
51.0
52.2
53.7
320.1
320.1
320.1
340.7
340.7
340.7
340.7
340.7
340.7
2018
Feeder 9S9/2
(Pyrmont STS - Darling
Harbour)
132 Rating
Feeder 91G
(Haymarket BSP - City
North (132kV))
132 Rating
Feeder 93C
(Haymarket BSP - City
North (132kV))
132 Rating
Feeder 92E
(Haymarket BSP - City
North (132kV))
40.3
49.9
44.0
43.3
44.0
44.4
25.6
32.1
28.8
27.4
27.8
27.9
132 Rating
225.0
225.0
225.0
225.0
225.0
225.0
260.0
260.0
260.0
260.0
260.0
260.0
Feeder 9S2
Load
(Haymarket BSP Beaconsfield West BSP) 132 Rating
119.0
138.8
153.0
158.3
163.3
167.9
92.4
106.3
126.2
125.1
128.8
132.8
225.0
225.0
225.0
225.0
225.0
225.0
240.0
240.0
240.0
240.0
240.0
240.0
Feeder 9S4: (Haymarket
Load
BSP - Beaconsfield
132 Rating
West BSP)
147.1
171.0
192.4
198.5
204.4
210.1
113.5
134.3
161.9
161.6
166.0
170.9
280.0
280.0
280.0
280.0
280.0
272.0
280.0
280.0
280.0
280.0
280.0
280.0
Feeder 90T(1)
(Haymarket BSP Green Square)
136.1
158.3
179.0
184.6
190.0
195.1
106.2
125.1
151.3
150.4
154.5
159.1
132 Rating
221.0
221.0
221.0
221.0
221.0
221.0
235.0
235.0
235.0
235.0
235.0
235.0
Feeder 90T (2)
Load
(Beaconsfield West BSP
- Green Square)
132 Rating
115.0
131.3
150.9
156.7
162.7
168.6
84.2
105.7
123.0
123.7
127.3
131.6
259.0
259.0
259.0
259.0
259.0
259.0
273.2
273.2
273.2
273.2
273.2
273.2
Load
Load
Load
Load
Load
Feeder 9SE
Load
(Beaconsfield West BSP
132 Rating
- Green Square)
Feeder 9SA
Load
(Campbell St Beaconsfield West BSP) 132 Rating
Feeder 9SB/1
Load
(Beaconsfield West BSP
132 Rating
- Surry Hills Annexe)
Feeder 9SB/1
(Surry Hills Annexe Belmore Park)
132 Rating
Feeder 9SB/2
(Surry Hills Annexe Double Bay)
132 Rating
Feeder 9SC
(Campbell St Haymarket BSP)
132 Rating
Load
Load
Load
28.7
43.8
43.5
43.3
44.0
44.3
18.8
27.6
27.4
27.4
27.8
27.9
225.0
225.0
225.0
225.0
225.0
225.0
260.0
260.0
260.0
260.0
260.0
260.0
28.7
43.8
43.5
43.3
44.0
44.3
18.8
27.6
27.4
27.4
27.8
27.9
225.0
225.0
225.0
225.0
225.0
225.0
260.0
260.0
260.0
260.0
260.0
260.0
80.2
93.7
100.1
103.7
107.5
111.3
58.8
71.0
83.0
83.2
85.6
88.4
227.0
227.0
227.0
227.0
227.0
227.0
242.0
242.0
242.0
242.0
242.0
242.0
119.7
138.8
156.9
161.8
166.6
171.2
96.7
111.7
133.8
134.0
137.5
141.5
129.0
129.0
129.0
129.0
129.0
129.0
140.0
140.0
140.0
140.0
140.0
140.0
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
54.5
46.1
146.9
148.9
151.8
26.1
29.3
56.6
129.5
121.1
122.9
124.8
180.0
180.0
180.0
180.0
180.0
129.0
129.0
200.0
200.0
200.0
200.0
200.0
54.9
47.3
36.4
36.0
37.5
38.9
66.7
56.7
44.0
45.2
45.6
46.3
132.0
132.0
132.0
132.0
132.0
132.0
140.0
140.0
140.0
140.0
140.0
140.0
111.1
102.4
161.7
169.0
172.6
173.9
129.0
114.7
164.3
170.4
171.5
173.6
298.4
298.4
298.4
298.4
298.4
298.4
317.8
317.8
317.8
317.8
317.8
317.8
85.4
85.5
83.4
83.7
85.2
86.5
101.2
97.5
94.5
94.8
95.1
96.0
139.5
139.5
139.5
139.5
139.5
139.5
148.6
148.6
148.6
148.6
148.6
148.6
Feeder 90R
(Campbell St - Double
Bay)
132 Rating
Feeder 9SL
(Belmore Park Waverley)
132 Rating
Feeder 9R8
(Rose Bay New Waverley)
-
20.3
43.1
47.7
47.6
47.1
-
31.7
42.8
41.7
41.8
42.2
132 Rating
-
200.0
200.0
200.0
200.0
272.0
-
200.0
200.0
200.0
200.0
200.0
Feeder 91T
Load
(Campbell St - Rose Bay
New)
132 Rating
-
29.1
66.5
72.3
73.5
73.6
-
25.9
62.2
72.4
72.9
73.8
-
200.0
200.0
200.0
200.0
272.0
-
200.0
200.0
200.0
200.0
200.0
Load
Load
Load
-
38.3
47.9
48.8
50.2
51.6
-
45.2
51.8
67.5
67.7
68.4
-
200.0
200.0
200.0
200.0
272.0
-
200.0
200.0
200.0
200.0
200.0
Feeder 260/1
Load
(Beaconsfield West BSP
132 Rating
- Zetland)
83.4
83.8
87.5
89.1
90.8
92.9
86.5
77.5
81.3
81.7
82.8
84.4
100.6
100.6
100.6
100.6
100.6
100.6
108.6
108.6
108.6
108.6
108.6
108.6
Feeder 261/1
Load
(Beaconsfield West BSP
- Zetland)
132 Rating
83.4
83.8
87.5
89.1
90.8
92.9
96.3
88.9
86.3
86.8
86.9
88.1
100.6
100.6
100.6
100.6
100.6
100.6
108.6
108.6
108.6
108.6
108.6
108.6
Load
87.4
91.7
105.3
108.3
110.9
113.4
92.1
97.6
106.8
106.1
107.6
109.8
130.3
130.3
130.3
130.3
130.3
130.3
138.3
138.3
138.3
138.3
138.3
138.3
Feeder 261/2
(Clovelly - Zetland)
132 Rating
Feeder 262
(Double Bay - Clovelly)
57.4
58.4
71.9
74.5
76.4
78.3
72.9
69.0
67.0
67.2
67.4
68.0
132 Rating
179.5
179.5
179.5
179.5
179.5
179.5
182.9
182.9
182.9
182.9
182.9
182.9
Feeder 92P
Load
(Beaconsfield West BSP
132 Rating
- Belmore Park)
118.2
139.8
167.2
180.5
184.6
185.8
92.4
110.9
141.3
149.5
151.5
154.2
129.0
129.0
129.0
129.0
129.0
129.0
140.0
140.0
140.0
140.0
140.0
140.0
Feeder 926(1)
(Sydney North BSP Sydney North BSP)
422.3
402.6
337.1
339.4
347.1
358.4
322.8
308.7
265.3
261.3
263.5
267.5
548.7
548.7
548.7
548.7
548.7
548.7
548.7
548.7
548.7
548.7
548.7
548.7
365.5
402.5
337.1
339.5
347.2
358.6
322.8
308.6
265.3
261.2
263.4
267.5
407.0
407.0
407.0
407.0
407.0
407.0
434.4
434.4
434.4
434.4
434.4
434.4
397.5
379.7
321.0
323.4
330.6
341.8
307.7
294.1
252.4
248.6
250.8
254.7
538.7
538.7
538.7
538.7
538.7
538.7
548.7
548.7
548.7
548.7
548.7
548.7
397.4
379.7
321.0
323.4
330.7
342.0
307.7
294.1
252.4
248.6
250.9
254.8
407.0
407.0
407.0
407.0
407.0
407.0
434.4
434.4
434.4
434.4
434.4
434.4
347.2
330.2
270.4
273.4
280.0
289.7
266.2
253.1
212.5
209.2
210.9
214.0
607.7
607.7
607.7
607.7
607.7
607.7
639.9
639.9
639.9
639.9
639.9
639.9
347.2
330.2
273.7
276.5
283.0
293.0
268.3
255.2
215.2
211.9
213.7
216.9
512.1
512.1
512.1
512.1
512.1
512.1
512.1
512.1
512.1
512.1
512.1
512.1
Feeder 926(3)
(Sydney North BSP Mason Park STSS)
Feeder 927(1)
(Sydney North BSP Sydney North BSP)
Feeder 927(3)
(Sydney North BSP Homebush Bay)
Feeder 92A
(Sydney North BSP Macquarie Park)
Feeder 92B
(Sydney North BSP Macquarie Park)
Load
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Load
132 Rating
Distribution and Transmission Annual Planning Report December 2013
119
Inner Metropolitan Area - Feeder Load Forecast
Feeder name
Feeder 935 (Homebush
Bay - Mason Park
STSS)
Feeder 92F
(Mason Park STSS Meadowbank)
(kV)
Load
132 Rating
Load
2013/14
2014/15
355.5
338.6
Summer (MVA)
2015/16 2016/17
284.5
286.3
2017/18
2018/19
2013
2014
Winter (MVA)
2015
2016
2017
2018
293.0
303.0
281.2
262.9
225.8
223.8
227.1
221.9
407.0
407.0
407.0
407.0
407.0
407.0
434.4
434.4
434.4
434.4
434.4
434.4
194.8
114.0
102.8
102.0
104.5
105.4
173.9
142.3
110.7
116.7
117.5
117.8
132 Rating
209.2
209.2
209.2
209.2
209.2
209.2
222.9
222.9
222.9
222.9
222.9
222.9
Feeder 92G
Load
(Lane Cove STSS - East
Ryde)
132 Rating
142.2
138.8
155.0
155.7
160.4
163.9
125.9
111.3
123.2
127.9
129.0
130.1
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
Feeder 92FA
(Meadowbank - Top
Ryde)
96.1
55.7
50.6
50.1
51.3
51.8
85.0
68.5
53.3
56.3
56.7
56.8
132 Rating
165.8
165.8
165.8
165.8
165.8
165.8
176.1
176.1
176.1
176.1
176.1
176.1
Feeder 92FB
(Meadowbank - Top
Ryde)
132 Rating
Feeder 92GA
(East Ryde - Top Ryde)
132 Rating
Feeder 92GB
(East Ryde - Top Ryde)
76.1
71.9
79.0
79.5
82.0
83.8
69.6
63.9
66.6
69.3
69.9
70.4
132 Rating
165.8
165.8
165.8
165.8
165.8
165.8
176.1
176.1
176.1
176.1
176.1
176.1
Feeder 92J
Load
(Lane Cove STSS - East
Ryde)
132 Rating
135.5
140.1
156.2
157.1
161.8
165.5
126.1
117.1
124.2
125.3
126.5
128.1
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
571.6
Feeder 90X
(Mason Park STSS Meadowbank)
196.4
122.3
93.0
91.5
93.4
93.7
174.7
142.1
105.9
112.5
113.0
112.8
132 Rating
199.8
199.8
199.8
199.8
199.8
199.8
212.2
212.2
212.2
212.2
212.2
212.2
Feeder 92JA
(East Ryde Meadowbank)
132 Rating
Feeder 92JB
(East Ryde Meadowbank)
132 Rating
Feeder 90XA
(Meadowbank Meadowbank)
132 Rating
Feeder 90XB
(Meadowbank Meadowbank)
96.9
60.1
45.8
45.0
45.9
46.1
85.3
68.4
50.3
53.6
53.9
53.8
132 Rating
100.0
100.0
100.0
100.0
100.0
100.0
106.0
106.0
106.0
106.0
106.0
106.0
Feeder 928/1
Load
(Surry Hills STS - Dalley
132 Rating
St)
94.4
83.0
70.8
71.8
67.0
60.6
74.0
80.5
89.1
55.6
64.3
64.4
128.0
128.0
128.0
128.0
128.0
128.0
128.0
128.0
128.0
128.0
128.0
128.0
120.0
110.3
102.2
102.1
96.0
96.7
110.0
114.1
114.5
90.1
99.2
99.5
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
105.9
86.2
86.0
92.2
89.9
104.5
100.8
116.3
105.7
109.9
105.3
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
121.2
Load
Load
Load
Load
Load
Load
Load
Load
Load
96.1
55.7
50.6
50.1
51.3
51.8
85.0
68.6
53.3
56.3
56.7
56.8
165.8
165.8
165.8
165.8
165.8
165.8
176.1
176.1
176.1
176.1
176.1
176.1
76.1
71.9
79.0
79.5
82.0
83.8
69.6
62.5
65.8
68.4
68.9
69.5
165.8
165.8
165.8
165.8
165.8
165.8
176.1
176.1
176.1
176.1
176.1
176.1
77.3
74.4
80.6
81.4
84.1
86.0
75.6
72.5
67.1
69.8
70.3
70.5
129.0
129.0
129.0
129.0
129.0
129.0
136.0
136.0
136.0
136.0
136.0
136.0
77.3
74.4
80.6
81.4
84.1
86.0
75.6
72.5
67.1
69.8
70.3
70.5
129.0
129.0
129.0
129.0
129.0
129.0
136.0
136.0
136.0
136.0
136.0
136.0
96.9
60.1
45.8
45.0
45.9
46.1
85.3
68.4
50.3
53.6
53.9
53.8
100.0
100.0
100.0
100.0
100.0
100.0
106.0
106.0
106.0
106.0
106.0
106.0
Feeder 928/3
(Lane Cove STSS Dalley St)
132 Rating
Feeder 929/1
(Lane Cove STSS Dalley St)
132 Rating
Feeder 929/2
(Dalley St - Surry Hills
STS)
90.9
77.1
55.2
54.5
60.6
51.2
72.7
71.5
85.8
68.6
73.0
68.5
132 Rating
130.6
130.6
130.6
130.6
130.6
130.6
130.6
130.6
130.6
130.6
130.6
130.6
Feeder 92L/1
Load
(Surry Hills STS - Dalley
132 Rating
St)
69.7
61.7
37.3
37.8
38.5
37.5
68.8
58.7
25.9
25.3
25.7
26.1
129.2
129.2
129.2
129.2
129.2
129.2
129.2
129.2
129.2
129.2
129.2
129.2
Load
Load
Load
41.0
33.1
37.3
37.8
38.4
37.5
27.4
22.2
25.6
25.1
25.6
25.9
132 Rating
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
274.4
Load
Feeder 92L/3
(Lane
Cove STSS - Dalley St) 132 Rating
116.1
101.8
-
-
-
-
101.7
89.1
-
-
-
-
128.0
128.0
-
-
-
-
128.0
128.0
-
-
-
-
Feeder 92M/1
(Lane Cove STSS Dalley St)
119.6
105.1
-
-
-
-
104.2
90.9
-
-
-
-
132 Rating
128.0
128.0
-
-
-
-
128.0
128.0
-
-
-
-
Feeder 92M/2
(Dalley St - Surry Hills
STS)
132 Rating
Feeder 92M/3
(Campbell St - Surry
Hills STS)
132 Rating
Feeder 92L/2
(Dalley St - Dalley St)
Load
Load
Load
Load
72.3
64.0
36.9
37.7
38.2
37.0
71.8
61.0
32.5
25.5
25.8
26.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
144.0
-
-
114.4
117.3
119.3
120.8
-
-
82.2
86.6
87.8
89.4
-
-
240.1
240.1
240.1
240.1
-
-
240.1
240.1
240.1
240.1
Distribution and Transmission Annual Planning Report December 2013
120
3.29.3 STS and ZS load forecast
The forecast loads for the STS and Zone sub-transmission substations in the Inner Metropolitan Transmission area
are shown in the following load areas, identified by DAPR section below:
3.30

3.2 Camperdown Load Area

3.3 Canterbury Bankstown Load Area

3.4 Carlingford Load Area

3.5 Eastern Suburbs Load Area

3.7 Inner West Load Area 
3.9 Lower North Shore Load Area 
3.11 Manly Warringah Load Area 
3.16 North West Sydney Load Area 
3.17 Pittwater and Terrey Hills Load Area 
3.20 St George Load Area 
3.21 Sutherland Load Area 
3.22 Sydney CBD Load Area 
3.25 Upper North Shore Load Area. Transmission - Distribution Connection Point load forecast
Ausgrid prepares an annual transmission distribution connection point forecast which is provided to TransGrid in
May each year as part of the annual planning review and load forecast information provisions of the NER. A
forecast of future loads over a ten year forward planning period is prepared for each dual function sub-transmission
substation connected to the TransGrid transmission network. These load forecasts are presented in 12.2.2 Dual
Function Substation Demand Forecasts.
As part of the annual load forecast development Ausgrid provides TransGrid with the “132kV TransGrid Report”
which provides an input for their power system load flow modelling of the Ausgrid network. It contains MW, MVAr
and uncompensated power factor data per year for the most recent actual year and 10 forecast years for each:

132kV connection point (sub-transmission substations, 132/11kV zone substations and 132kV customers); and

Zone substation supplied from other Distribution Network Service Providers (DNSPs), such as Epping,
Leightonfield, and Hunters Hill, irrespective of supply voltage.
Distribution and Transmission Annual Planning Report December 2013
121
3.31
Other factors having a material impact on the network
3.31.1 Fault levels
Fault levels at TransGrid’s Beaconsfield BSP exceed 40kA. TransGrid is installing new 50kA rated switchgear at
Beaconsfield BSP (condition-driven replacement) and Ausgrid is now considering equipment rated at this level for
potential future Ausgrid developments in the area. Nearby existing substations with 40kA rated switchgear are
operating very close to their limits and this restricts some operating arrangements. There are numerous open points
on the 132kV meshed transmission system due to these fault level limitations. These open points create more
complicated switching arrangements and limit network flexibility.
132kV series reactors are being installed by TransGrid at the new Rookwood Rd BSP in part to limit fault level
contribution (along with power flow control). In addition to these reactors new open points are being created on the
132kV network to restrict fault levels to below equipment ratings following the energisation of this BSP.
For a number of 132/33kV sub-transmission substations (STS) refurbishments changes have been made in the
standard arrangement for neutral earthing due to the limitations uncovered in past Ausgrid network standards. This
results in individual transformer neutral earthing reactors being installed in place of a common neutral earthing
resistor.
There are restrictions on future embedded generation at a number of inner city locations due to fault levels
approaching equipment ratings. These include the CBD triplex network and Pyrmont STS.
3.31.2 Voltage levels
The meshed inner-metropolitan network is supplied by two large radial 330kV cables with very high charging
capacitance. This means capacitor banks are required during cable outages to replace this lost reactive support,
however during low load conditions shunt reactors are required to reduce voltages. These cables also have series
reactors for power flow and fault level control, which exacerbate voltage issues at some times.
As a result capacitor banks have been installed during the current 2009 -14 regulatory period at Beaconsfield BSP
and Peakhurst STS. Additional capacitors and shunt reactors are committed to be installed at Bunnerong STS and
Rookwood Rd BSP to help manage voltage on the 132kV meshed network.
Voltage control to manage 11kV network voltages is done at zone substations using tap changing transformers and
where necessary capacitor banks.
3.31.3 Other power system security requirements
There is a project underway to install additional under-frequency load shedding capability across the network to
meet NER requirements.
3.31.4 Quality of Supply
Supply Voltage
Measurements on the LV network indicate that a number of sites exceed the V99% value when measured to AS
61000.3.100. Ausgrid is currently in the process of lowering of the zone substation 11kV float voltages and
distribution transformer 415V tap settings to deliver network functional compliance.
Harmonics
Measurements on the LV network indicate that a number of sites exceed limit for the 15th harmonic. Ausgrid is
currently investigating the existing standards and limits applied for the 15th harmonic to see if the limit can be
relaxed to a more realistic level (noting that the IEEE 519 and New Zealand set higher limits apply for some
th).
harmonics including the 15
Flicker
Measurements on the LV network indicate that a number of sites exceed the limit for Plt (Long Term flicker). In the
next 12 months Ausgrid will carry out an investigation to quantify the main source of the flicker and to determine
mitigation means to lower the levels. Ausgrid will also carry out a review of the relative standards limits between
Short Term and Long Term flicker with a view to determining if the limit for Long Term flicker is unreasonably low.
3.31.5 Ageing and potentially unreliable assets
In considering the age profile, reliability analysis, and the consequences of cable leakage / failures experienced
over the 6 year period to 2012, Ausgrid has developed the following asset replacement strategy for subtransmission underground cables:

All self contained fluid filled (SCFF) cables crossing major waterways are to be prioritised for replacement by
the end of the 2015-2019 Regulatory period. The operational, customer reliability and environmental risks
associated with SCFF cable systems traversing Sydney’s major waterways are no longer considered
acceptable

All SCFF other cables are to be replaced or retired by the end of the 2025-2029 regulatory period. These cable
systems will have reached/exceeded the asset standard design life, and combined with the problems
associated with this technology in terms of environmental impact of SCFF leakages, long repair times, the
Distribution and Transmission Annual Planning Report December 2013
122
resulting impacts on system reliability and availability. Ausgrid’s and the industry’s reducing ability to support
this infrastructure beyond 2029 means that this asset technology must be considered no longer viable as long
term asset solutions

All 33kV gas pressure cables are to be replaced or retired by the end of the 2015-2019 regulatory period.
These cable systems will have reached/exceeded the asset design life, as evidenced by increasing monthly
leakage volumes on a decreasing asset base in service, as well as the number of multiple cable failures
impacting zone substations. The risks when one of the cables is out of service having the potential for multiple
failures of long repair duration are no longer considered acceptable.
Over the years there have been a considerable number of significant failures of 11kV switchgear installed in zone
substations that have resulted in a range of consequences from simple equipment outages, to expulsion of hot oil
from the circuit breaker, to small fires confined to the switchroom, to large fires that have burnt down the entire
switchroom. A range of measures have been undertaken to attempt to mitigate against these consequences,
however, much of this type of equipment installed in Ausgrid is now considered beyond its design life, and
continued service will result in further deterioration in condition and an increasing number of failures that are
random in nature.
Ausgrid has developed a compound switchboard replacement strategy for the complete removal of this technology
from the network by 2024. High risk switchboards are planned to be replaced in the 2010-2014 regulatory period.
Medium risk switchboards are planned to be replaced in the 2015-2019 regulatory period and lower risk
switchboards be replaced in the 2020-2024 regulatory period.
The insulation condition and design features of the 11kV air insulated switchgear and associated circuit breakers
are a key issue for the ongoing management of the Ausgrid supply system. The analysis of test results revealed
that all air insulated busbar is in a serviceable condition for its age, however the condition of the associated oil
circuit breakers (OCBs) varies from serviceable to poor condition and after in service failures of similar types of
OCBs it has been decided to replace the OCB with current technology VCBs wherever feasible.
Despite generally being of a younger age than other 11kV switchgear on the Ausgrid network, the deterioration of
11kV outdoor switchgear is markedly pronounced due to its environmental conditions. These circuit breakers have
become more unreliable and expensive to maintain; and this type of switchgear is now largely considered obsolete.
Ausgrid ‘s asset management strategy for outdoor 11kV switchgear recommends that all outdoor 11kV circuit
breakers are replaced within the regulatory period 2010-2014.
Distribution and Transmission Annual Planning Report December 2013
123
4
Planning proposals for future needs
4.1
Proposed future transmission-distribution connection points
There are no proposed future transmission-distribution connection points which are not committed projects within
the 5 year forward planning period 2014 to 2018.
4.2
Proposed future sub-transmission lines
The following table presents forecasts of proposed future sub-transmission feeders which are not yet committed
projects. The proposed future solutions to the identified capacity limitations have not yet completed the NER
economic evaluation and consultation process where required by the relevant NER cost thresholds.
Planning proposal for future Sub-transmission Feeders
Location
Canterbury Bankstown
Eastern Suburbs
Inner West
St George
Sydney CBD
Feeder Name
Looping in Strathfield South ZS in to existing feeder
911
New Airport feeders 1, 2 & 3 from Alexandria STS
New International Terminal feeder 1, 2 & 3 from
Alexandria STS
New Kingsford to Clovelly ZS feeder
90F/3 (90Ftee to Auburn South ZS)
90J/3 (90Jtee to Auburn South ZS)
Looping in Rockdale ZS in to proposed committed
feeder 907
Feeders 9RC, 9RW and 9RP from City North to Bligh
St ZS
Inner Metro
Feeder 90Y: Beaconsfield BSP to Belmore Park ZS
Feeders 92F and 90X: Mason Park STSS to Top Ryde
ZS and Meadowbank ZS
West Lake Macquarie
4.3
TransGrid feeders 45 and 46: Beaconsfield BSP to
Haymarket BSP and Rookwood Rd BSP to
Beaconsfield BSP
Feeders 92G and 92J: Lane Cove STSS to Top Ryde
ZS and Meadowbank ZS
80251 Argenton STS to Newstan
33305(1) Newstan to tee SRA and Awaba State Mine
33305(2) tee to SRA Awaba
33305(3) tee to Awaba State Mine
3976 Stockton Borehole to Awaba State Mine
Voltage
(kV)
Identified Need
Proposed
Commissioning Date
132
132
Asset condition
Asset condition
Dec-19
Sep-16
132
132
132
132
Asset
Asset
Asset
Asset
condition
condition
condition
condition
Dec-16
Sep-17
Sep-15
Sep-15
132
Asset condition
Sep-15
132
Asset condition
Capacity constraint on 9SA and
9SB/1
Condition of feeders 92FA, 92FB,
90XA and 90XB
Condition of feeders 928/3, 929/1,
91A/2
Capacity constraints on 91X, 91Y,
92C, 92X and TransGrid Feeder 41
Condition of feeders
92GA,92GB,92JA,92JB
Asset condition
Asset condition
Asset condition
Asset condition
Asset condition
Dec-19
132
132
330
132
33
33
33
33
33
Sep-15
Sep-16
Sep-18
Sep-19
Jul-16
Jul-16
Jul-16
Jul-16
Jul-16
Proposed future Sub-transmission STS and Zone substations
The following table presents forecasts of proposed future sub-transmission substations which are not yet committed
projects. The proposed future solutions to the identified capacity limitations have not yet completed the NER
economic evaluation and consultation process where required by the relevant NER cost thresholds.
Planning proposal for future STS and ZS Substations
Location
Canterbury Bankstown
Eastern Suburbs
Inner West
St George
Sydney CBD
Sub-transmission Substation or Zone Substation
New Starthfield South ZS
Alexandria STS
Auburn South ZS
Rockdale 132/11kV ZS
Bligh St ZS
Upper Central Coast
Munmorah STS
Paxton ZS
Cessnock ZS
Telarah West ZS
Greater Cessnock
Maitland
Distribution and Transmission Annual Planning Report December 2013
Voltage
(kV)
132/11
132/33
132/11
132/11
132/11
Identified Need
Asset
Asset
Asset
Asset
Asset
Unavailability of 33kV supply from
132/33 Delta Electricity
33/11 Asset
33/11 Asset
33/11 Asset
Proposed
Commissioning Date
Sep-16
Sep-16
Sep-15
Sep-15
Dec-19
Jun-15
Jul-14
Jul-16
Dec-16
124
4.4
Future Sub-transmission and Zone substations loading levels
The following substation forecasts are based on Ausgrid development forecast which is used in the
identification of future needs and the development of our preferred long term Area Plan strategies for
potential solutions to these needs. The forecast loads in the table below differ from those presented
in DAPR section 3 Forecasts for the Forward Planning Period, which are Ausgrid’s base forecasts
inclusive of committed projects and the associated committed load transfers.
4.4.1
Sydney and Central Coast Load Areas
Proposed future STS and ZS summer forecast loads based on Ausgrid’s development forecast for the forward
planning period.
Proposed Future Sub-transmission Substations - Forecast Summer Loads
Planning Proposal - Future Sub-transmission Substations
MVA
Canterbury
Strathfield South ZS
PF
Bankstown
MVA
New Greenacre Park ZS
PF
MVA
Eastern Suburbs
Alexandria STS
PF
MVA
Inner West
Auburn South ZS
PF
MVA
St George
Rockdale 132/11kV ZS
PF
MVA
Upper Central Coast
Munmorah STS
PF
2013/14
-
2014/15
-
Forecast Summer Load
2015/16
2016/17
2017/18
24.3
24.8
0.9
0.9
40.1
0.9
78.6
90.9
0.9
0.9
48.5
48.5
0.9
0.9
56.8
57.2
0.9
0.9
18.3
19
19.6
0.95
0.9
0.9
2018/19
24.8
0.9
40.1
0.9
90.9
0.9
48.5
0.9
57.2
0.9
19.6
0.9
Proposed future STS and ZS winter forecast loads based on Ausgrid’s development forecast for the forward
planning period.
Proposed Future Sub-transmission Substations - Forecast Winter Loads
Substation
Canterbury
Bankatown
Strathfield South ZS
New Greenacre Park ZS
Eastern Suburbs
Inner West
St George
4.4.2
Alexandria STS
Auburn South ZS
Rockdale 132/11kV ZS
MVA
PF
MVA
PF
MVA
PF
MVA
PF
MVA
PF
2013
-
2014
-
Forecast Winter Load
2015
2016
31.3
0.0
2017
21.9
0.9
71.2
0.95
43.2
0.9
32.3
0.9
2018
22.3
0.9
30.5
0.9
83.4
0.95
44.5
0.9
33.3
0.9
Hunter Load Areas
Proposed future STS and ZS summer forecast loads based on Ausgrid’s development forecast for the
forward planning period.
Proposed Future Sub-transmission and Zone Substations - Forecast Summer Loads
Planning Proposal - Future Sub-transmission Substations
MVA
Maitland
Telarah West
PF
MVA
Cessnock (New)
Greater Cessnock
PF
2013/14
2014/15
-
-
Forecast Summer Load
2015/16
2016/17
2017/18
-
17.4
0.95
19.6
0.98
18.1
0.95
19.4
0.98
2018/19
19.0
0.95
19.1
0.98
Proposed future STS and ZS winter forecast loads based on Ausgrid’s development forecast for the forward
planning period.
Proposed Future Sub-transmission and Zone Substations - Forecast Winter Loads
Planning Proposal - Future Sub-transmission Substations
MVA
Maitland
Telarah West
PF
MVA
Cessnock (New)
Greater Cessnock
PF
2013
2014
-
-
Distribution and Transmission Annual Planning Report December 2013
Forecast Winter Load
2015
2016
-
13.7
0.98
2017
2018
8.5
0.97
13.7
0.98
8.8
0.97
13.7
0.98
125
5
Identified System Limitations
5.1
Notes on identified system limitations
Remedial action is required when sub-transmission substations and underground feeders exceed secure capacity
and when zone substations and overhead feeders do not comply with licence conditions. Identified limitations are
and indicative solutions are listed in Area Plan regional groupings, with the following information:

Substation – The name of the location, usually a zone or sub-transmission substation

Feeder – The name of the feeder, indicating the location of the feeder

Timing – the identified need date by which a solution is planned to be implemented.
System limitation – an identified network need. “Capacity” indicates there is a projected network capacity shortfall
that must be addressed. “Asset condition” refers to either a need to refurbish an asset due its condition or
approaching the end of service life.
Investment Process Status – An indication of the current development status of a solution. These definitions are:

‘Completed’ projects are those that had been commissioned at the time of this report

‘Committed’ projects are those that are underway but have not yet been commissioned

‘In Development’ projects are those where feasible options have been identified, and included in the program,
and detailed development, planning and regulatory approvals and completion of demand management
investigations are underway.
Distribution and Transmission Annual Planning Report December 2013
126
5.2
Sub-transmission Feeder Limitations
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.1
5.2.2
Camperdown
Blackwattle
Bay
Canterbury
Bankstown
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
Feeder Name
Timing
Driver
Feeders 527 & 559
- Pyrmont STS to
Blackwattle Bay ZS
2015-19
Asset
Condition
NA
None
Potential credible solutions include:
1. decommission Blackwattle Bay ZS by transferring load to
Camperdown ZS which requires installation of an additional
transformer and 33kV feeder at Camperdown ZS (preferred)
2. refurbishment of Blackwattle Bay ZS
3. new Blackwattle Bay ZS
4. demand management.
Feeder 490 & 491 Pyrmont STS to
Global Switch
Sep-14
Capacity
3.6
None
There is a customer funded committed project to install a new 3rd
33kV feeder from Pyrmont STS to Global Switch.
Feeders 643, 644 &
645 - Canterbury
STS to Dulwich Hill
ZS
Dec-17
Asset
Condition
NA
None
Potential credible solutions include:
1. new Dulwich Hill ZS
2. refurbish Dulwich Hill ZS
3. decommission Dulwich Hill ZS via 11kV load transfer.
Feeders 639, 640 &
641 - Canterbury
STS to Enfield ZS
Sep-16
Asset
Condition
NA
None
Potential credible solutions include:
1. South Strathfield ZS (preferred)
2. refurbish Enfield ZS
3. decommission Enfield ZS via 11kV load transfer.
Feeder 291/1 Greenacre Park to
Potts Hill ZS
Sep-15
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like replacement (preferred)
2. decommissioning of the feeder
3. or replacement of feeder with new feeder from Rookwood Rd
BSP to Greenacre Park ZS.
Distribution and Transmission Annual Planning Report December 2013
Discussion of Potential Credible Solutions
127
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.3
Eastern
Suburbs
Timing
Driver
Load reduction
required for
1 year deferral
(MW)
Feeder 396(1) Surry Hills STS to
Paddington ZS
Mar-13
Capacity
1.7
Feeder 396(2) Surry Hills STS to
Waverley ZS
Mar-13
Capacity
3.4
Feeder 387 - Surry
Hills STS to
Darlinghurst ZS
Dec-15
Asset
Condition
Feeders 386, 388 &
389 - Surry Hills
STS to Darlinghurst
ZS
Dec-18
Feeders 377 & 378
- Surry Hills STS to
Graving Dock ZS
Feeder Name
Impact on
TransmissionDistribution
Connection
Points
Discussion of Potential Credible Solutions
None
There is a committed project to convert existing Waverley ZS to
132/11kV operation and subsequently retire feeder 396.
NA
None
Potential credible solutions include:
1. decommissioning of feeder via 11kV load transfer (preferred)
or
2. like for like placement of the feeder.
Asset
Condition
NA
None
Potential credible solutions include:
1. decommission Darlinghurst ZS via an 11kV load transfer to
Campbell Street ZS / Padington ZS which requires installation
of an additional transformer and 11kV switchgear at Campbell
St ZS (preferred)
2. like for like feeder replacement at Darlinghurst ZS.
Dec-17
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like feeder replacement (preferred) or
2. decommissioning of feeders which implies decommissioning of
zone.
Feeders 313, 318,
324 & 340 Bunnerong North
STS to Matraville
ZS
Sep-17
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like feeder replacement (preferred) or
2. decommissioning of the feeders.
Feeders 380, 381 &
382 - Surry Hills
STS to Paddington
ZS
Dec-16
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like feeder replacement (preferred) or
2. decommissioning of feeders which implies decommissioning of
the zone substation.
Distribution and Transmission Annual Planning Report December 2013
128
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.3
Eastern
Suburbs
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
Feeder Name
Timing
Driver
Feeder 376 - Surry
Hills STS to Surry
Hills ZS
Dec-17
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like feeder replacement (preferred) or
2. decommissioning of feeders which implies decommissioning of
zone.
Feeders 383, 384 &
385 - Surry Hills
STS to Surry Hills
ZS
Dec-18
Asset
Condition
NA
None
Potential credible solutions include:
1. like for like feeder replacement (preferred) or
2. decommissioning of the feeders which implies
decommissioning of the zone substation. Could be done in
Dec-17 along with feeder 376.
Feeders 331, 352 &
356 - Bunnerong
STS to Sydney
Airport ZS
Dec-16
Asset
Condition
NA
None
Potential credible solutions include:
1. reconfigure Sydney Airport ZS and replace 33kV feeders from
a new Alexandria STS (preferred)
2. retire Sydney Airport via a new 132/11kV zone
3. retire Sydney Airport ZS via load transfer reconfigure Sydney
Airport zone and replace 33kV feeders from Bunnerong STS.
Feeders 260/2 and
261/2 - Zetland to
Clovelly ZS
Dec-17
Asset
Condition
NA
None
Potential credible solutions include:
1. replace feeders 260/2 and 261/2 with new 132kV feeder from
Kingford to Clovelly ZS (preferred)
2. like for like replacement or
3. retire feeders by decommissioning Clovelly ZS via 11kV load
transfer.
Feeders 328, 331,
337 & 341 Bunnerong STS to
Mascot ZS
Dec-18
Asset
Condition
NA
None
Potential credible solutions include:
1. Alexandria STS to Mascot ZS (preferred) or
2. decommissioning of feeders which implies decommissioning of
Mascot ZS.
Distribution and Transmission Annual Planning Report December 2013
Discussion of Potential Credible Solutions
129
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.4
5.2.5
Inner West
Lower Central
Coast
Feeder Name
Timing
Driver
Load reduction
required for
1 year deferral
(MW)
Feeder 607 Homebush STS to
Concord ZS
Nov-17
Capacity
0.5
Feeder 614 Homebush STS to
Auburn ZS
Sep-16
Feeder 615 Homebush STS to
Auburn ZS
Sep-17
Feeders 602 & 604
- Homebush STS to
Lidcombe ZS
Sep-16
Feeder 605 Homebush STS to
Lidcombe ZS
Sep-18
Feeders 794 Ourimbah STS STS
to Peats Ridge ZS
Sep-14
Feeders 720 Gosford STS to
Peats Ridge ZS
Sep-18
Impact on
TransmissionDistribution
Connection
Points
Discussion of Potential Credible Solutions
Committed 11kV load transfer from Concord to Meadowbank ZS
None
Asset
Asset
Condition
NA
None
Asset
Condition
NA
None
Asset
Condition
NA
None
Asset
Condition
NA
None
Capacity
0.2
Capacity
Distribution and Transmission Annual Planning Report December 2013
Potential credible solutions include:
1. replacement of Auburn and Lidcombe ZS with a new 132/11kV
zone substation adjacent to Lidcombe ZS (preferred)
2. replacement of 33kV feeders from Homebush STS to Auburn
and Lidcombe ZS and refurbish Lidcombe ZS
3. replacement of 33kV feeders from Homebush STS to Auburn
and Lidcombe ZS and reconfigure Lidcombe ZS or
4. retirement of Lidcombe ZS and uprate Auburn ZS.
Note: From the strategic solution point of view Auburn & Lidcombe
zone substation identified needs are addressed together.
None
Feeder limited by 33kV circuit breaker Current Transformer and there
is a committed project to replace the 33kV circuit breakers at Peats
Ridge ZS under a replacement subprogram.
None
Feeder limited by 33kV circuit breaker CT and there is a committed
project to replace the 33kV circuit breakers at Peats Ridge ZS under
replacement subprogram.
0.2
130
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.6
5.2.7
Manly
Warringah
Pittwater &
Terrey Hills
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
Feeder Name
Timing
Driver
Feeder S08(3) S08TEE to Harbord
ZS
Jul-16
Asset
Condition
NA
None
Potential credible solutions include:
1. replace underground HSL section of 33kV feeder S08(3) with
XLPE cables(0.29km) (preferred) or
2. retire the feeder which implies changes to Harboard zone
configuration.
Feeder S08(2) S08TEE to Manly
ZS
Jul-16
Asset
Condition
NA
None
Potential credible solutions include:
1. replace underground HSL section of 33kV feeder S08(2) with
XLPE cables (1.4km) (preferred) or
2. retire the feeder which implies changes to Manly zone
configuration.
Feeder S10 S10TEE to
Kangaroo Park to
Manly ZS
Jul-16
Asset
Condition
NA
None
Potential credible solutions include:
1. replace underground HSL section of 33kV feeder S10 with
XLPE cables (2.7km) (preferred) or
2. retire the feeder which implies changes to Manly zone
configuration.
Feeder S10(4) Kangaroo Park
Terminal to North
Head ZS
Sep-16
Asset
Condition
NA
None
Potential credible solutions include:
1. replace underground HSL section of 33kV feeder S10(4) with
XLPE cables (3.1km) (Preferred)
2. retire the feeder which implies changes to North Head zone
configuration.
Feeder S20 Sydney East STS
to Warriewood
STSS
Jul-17
Asset
Condition
NA
None
Potential credible solutions include:
1. replace underground HSL section of 33kV feeder S20 with
XLPE cables (4.4km) (preferred)
2. new feeder from Sydney East STS to Warriewood STSS.
Distribution and Transmission Annual Planning Report December 2013
Discussion of Potential Credible Solutions
131
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.8
St George
Feeder Name
Timing
Driver
Feeders 775 & 776
- Peakhurst STS to
Rockdale ZS
Sep-16
Asset
Condition
Load reduction
required for
1 year deferral
(MW)
NA
Impact on
TransmissionDistribution
Connection
Points
None
Discussion of Potential Credible Solutions
Potential credible solutions include:
1. Credible solutions include replacement of Rockdale zone with
a new 132/11kV ZS (preferred)
2. refurbishment of Rockdale ZS or retirement of Rockdale ZS via
11kV load transfers to adjacent zone
Note: All the issues including 33kV and 11kV switchgear related to
Rockdale zone are addressed together.
5.2.9
Newcastle
Inner City
Feeder 769
(Peakhurst STS to
Blakehurst ZS)
Sep-18
Asset
Capacity
1.1
None
Feeder 770
(Peakhurst STS to
Blakehurst ZS)
Sep-18
Asset
Capacity
1.2
None
Potential credible solutions include:
1. 11kV load transfer from Blakehurst ZS to adjacent zones via
switching and ultimately decommissioning of Blakehurst ZS
(preferred)
2. new Blakehurst ZS.
Feeder 773 Merewether to
Kotara
Dec-13
Asset
Condition
NA
None
Potential credible solutions include:
1. Replace oil-filled cable section (100% feeder length)
2. Augment 33kV network and re-use retired 33kV assets (to
Adamstown and Charlestown).
Feeder 775 Merewether to
Kotara
Dec-13
Asset
Condition
NA
None
Potential credible solutions include:
1. Replace oil-filled cable section (100% feeder length)
2. Augment 33kV network and re-use retired 33kV assets (to
Adamstown and Charlestown).
Feeder 775 Merewether to
Kotara
Dec-18
Asset
Condition
NA
None
Potential credible solutions include:
1. Replace oil-filled cable section (40% feeder length)
2. Build new feeder.
Distribution and Transmission Annual Planning Report December 2013
132
Identified Sub-transmission Feeder Limitations
Driver
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
System Limitation
Load Area
Feeder Name
Timing
Discussion of Potential Credible Solutions
5.2.10
Newcastle
Western
Corridor
Feeder 80258 Argenton STS to
Edgeworth ZS
Nov-15
Capacity
1.4
None
Potential credible solutions include:
1. 11kV load transfer
2. Demand Management
3. Upgrade feeder capacity
4. New Cameron Park ZS (and retire Edgeworth ZS)
5. Build new feeder to Edgeworth.
5.2.11
Northeast
Lake
Macquarie
Feeder 760 Merewether to
Jewells
Dec-14
Asset
Condition
NA
None
Potential credible solutions include:
1. Replace oil-filled cable section (8% feeder length)
2. Build new feeder.
Feeder 766 Merewether to
Gateshead
Dec-14
Asset
Condition
NA
None
Potential credible solutions include:
1. Replace oil-filled cable section (10% feeder length)
2. Build new feeder.
Nov-16
Capacity
0.5
None
Potential credible solutions include:
1. 11kV load transfer
2. Demand Management
3. Anna Bay STS and 33kV network re-arrangement
4. Upgrade feeder capacity.
5.2.12
Port Stephens Feeder TM4 Tomago STS to
Medowie ZS
Distribution and Transmission Annual Planning Report December 2013
133
Identified Sub-transmission Feeder Limitations
Driver
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
System Limitation
Load Area
5.2.13
Inner Metro
Feeder Name
Timing
Discussion of Potential Credible Solutions
Feeder 9SA Beaconsfield BSP
to Campbell St ZS
Nov-14
Capacity
30
None
Potential credible solutions include:
1. refurbishment of the limiting sections of feeder 9SA,.
2. demand management, and
3. construction of a new feeder from Beaconsfield BSP to
Belmore Park ZS.
Feeder 92P Beaconsfield BSP Belmore Park Zn
Nov-14
Capacity
30
None
Potential credible solutions include:
1. refurbishment of the limiting sections of feeder 92P
2. demand management, and
3. construction of a new feeder from Beaconsfield BSP to
Belmore Park ZS.
Feeder 91X Chullora STSS to
Beaconsfield BSP
Nov-15
Capacity
10
None
Feeder 91Y Chullora STSS to
Beaconsfield BSP
Nov-15
Capacity
10
None
Feeder 92C Chullora STSS to
Beaconsfield BSP
(formerly 91A/2)
Nov-18
Capacity
360
None
Potential credible interim solutions to resolve the constraints are
1. demand management and further maintenance and
refurbishment of feeder 91M/1 to prolong feeder life
expectancy until 2019.
Potential credible long term solutions include:
2. new 132kV circuits to the inner city area (Beaconsfield or
Haymarket BSPs)
3. new 330kV circuits to the inner city area (Beaconsfield or
Haymarket BSPs).
Feeder 92X Chullora STSS to
Beaconsfield BSP
(formerly 91B/2)
Nov-18
Capacity
360
None
Feeder 9S6/1 Haymarket BSP to
Pyrmont STS
Nov-18
Capacity
7
None
Note: These underground cables were recently de-rated following
detailed cable route soil and backfill investigations.
Distribution and Transmission Annual Planning Report December 2013
Potential credible solutions include:
1. demand management
2. installation of a 4th transformer at Pyrmont STS or
3. protection changes to allow reconfiguration of the busbar
operating arrangement at Darling Harbour ZS.
134
Identified Sub-transmission Feeder Limitations
System Limitation
Load Area
5.2.14
Inner Metro
Feeder Name
Timing
Driver
Load reduction
required for
1 year deferral
(MW)
Impact on
TransmissionDistribution
Connection
Points
Discussion of Potential Credible Solutions
Feeders 92FA and
92FB - Mason Park
STSS to Top Ryde
ZS
Nov-15
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement like-for-like
2. retirement and upgrade of other 132kV circuits, or
3. replacement with a single circuit.
Feeder 91A/2 Chullora STSS to
Beaconsfield BSP
Nov-17
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement like-for-like
2. replacement with new high capacity 132kV circuits, or
3. replacement with a 330kV circuit.
Feeders 928/3 and
929/1 - Lane Cove
STS to Dalley St ZS
Nov-16
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement with new 132kV circuits to Pyrmont STS
2. new 132kV circuits to the CBD or
3. upgrading of TransGrid's feeder 9S4 to 330kV operation.
Feeders 92GA and
92GB - Lane Cove
STSS to Top Ryde
ZS
Nov-19
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement like-for-like or
2. replacement with a single circuit.
Feeders 92JA and
92JB - Lane Cove
STSS to
Meadowbank ZS
Nov-19
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement like-for-like or
2. replacement with a single circuit.
Feeders 90XA and
90XB - Mason Park
STSS to
Meadowbank ZS
Nov-20
Asset
Condition
NA
None
Potential credible solutions include:
1. replacement like-for-like
2. retirement and upgrade of other 132kV circuits, or
3. replacement with a single circuit.
Distribution and Transmission Annual Planning Report December 2013
135
5.3
Sub-transmission STS and Zone Substation Limitations
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.1
5.3.2
Camperdown
Blackwattle
Bay
Canterbury
Bankstown
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Pyrmont STS
Sep-15
Capacity
4.0
-
Credible solutions include:
1. installation of additional transfomer at Pyrmont STS
(preferred), load transfer from Pyrmont to Surry Hills STS
2. installation of additional transformer at Darling Harbour ZS
and 11kV load transfer from Camperdown to Leichhardt ZS
or
3. demand management.
Blackwattle Bay ZS
Sep-18
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. decommission Blackwattle Bay ZS by transferring load to
Camperdown ZS which requires installation of additional
transformer and 33kV feeder at Camperdown ZS (preferred)
2. refurbishment of Balackwattle Bay ZS
3. new Blackwattle Bay ZS or
4. demand management.
Bass Hill ZS
Sep-15
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. refurbish Bass Hill ZS (preferred)
2. decommission Bass Hill ZS via 11kV load transfer or
3. new Bass Hill ZS.
Dulwich Hill ZS
Dec-17
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. new Dulwich Hill ZS
2. refurbish Dulwich Hill ZS or
3. decommission Dulwich Hill ZS via load transfer.
Distribution and Transmission Annual Planning Report December 2013
136
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.2
5.3.3
Canterbury
Bankstown
Carlingford
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Greenacre Park ZS
Dec-17
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. new Greenacre Park ZS (preferred)
2. refurbish Greenacre Park ZS or
3. decommission Greenacre Park ZS by transferring load to
Bankstown ZS by installing additional transformer and 11kV
switchgear at Bankstowm ZS.
Leightonfield ZS
Jun-14
Asset
Condition
NA
-
Panel 1 to 4 11kV switchgear condition issues.
Credible solution include:
1. decommission panel 1 to 4 by redistributing load within
Leightonfield ZS (preferred)
2. new Leightonfield ZS
3. refurbish Leightonfield ZS.
Potts Hill ZS
Dec-13
Capacity
1.7
-
Reduce the amount of committed load transfer (approx by 15MVA)
from Sefton to Potts Hill zone due to lower forecast load at Sefton zone.
Hunters Hill ZS
Dec-17
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV with new 11kV single bus switchgear
(Preferred)
2. decommission the old 11kV switchgear and permanently
transfer all the loads to neighbouring ZS
3. decommission existing Hunters Hill ZS and establish a new
ZS on adjacent site.
Macquarie Park ZS
Sep-18
Capacity
NA
-
Due to other non-committed spot loads in the area, the zone is
constrained in summer 2016/17 and a credible solution need to be
implemented by September 2016.
Credible solution include:
1. 11kV load transfer from Macquarie Park to Top Ryde ZS by
installing additional transformer and switchgear at Top Ryde
ZS (preferred) or
2. new zone substation in 2016.
Distribution and Transmission Annual Planning Report December 2013
137
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.3
Carlingford
Driver
Substation Name
Top Ryde ZS
Jun-16
Capacity
Load
reduction
required for 1
year deferral
(MW)
4.4
Impact on
Transmission
-Distribution
Connection
Points
-
Discussion of Potential Credible Solutions
Capacity constraint at Macquarie Park ZS.
1. Top Ryde ZS additional transformer and 11kV Switchgear
2. Demand management.
5.3.4
Eastern
Suburbs
Botany ZS
Dec-18
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. refurbish Botany ZS (preferred)
2. decommission Botany ZS via 11kV load transfer or
3. new Botany Bay ZS.
Darlinghurst ZS
Dec-18
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. decommission Darlinghurst ZS via load transfer to Campbell
St/Paddington ZS which requires installation of additional
transformer and 11kV switchgear at Campbell St ZS
(preferred)
2. refurbish Darlinghurst ZS or
3. new Darlinghurst ZS.
Matraville ZS
Dec-18
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. refurbish Matraville ZS (preferred)
2. retire Matraville via new zone substation or
3. retire Matraville ZS via load transfer.
Surry Hills ZS
Dec-15
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. refurbish Surry Hills ZS (preferred)
2. retire Surry Hills ZS via new zone substation or
3. retire Surry Hills ZS via load transfer.
Distribution and Transmission Annual Planning Report December 2013
138
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.4
Eastern
Suburbs
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Sydney Airport ZS
Dec-16
Asset
Condition
NA
-
33kV feeder condition issues.
Credible solutions include:
1. reconfigure Sydney Airport ZS and replace 33kV feeders
from a new Alexandria STS (preferred)
2. retire Sydney airport via a new 132/11kV zone
3. retire Sydney Airport ZS via load transfer or
4. reconfigure Sydney Airport zone and replace 33kV feeders
from Bunnerong STS.
Clovelly ZS
Sep-17
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. retire one group of 11kV switchgear via 11kV load transfer
(preferred)
2. refurbish Clovelly ZS or retire Covelly zone via new zone
substation.
Lidcombe ZS
Sep-16
Asset
Condition
NA
-
11kV switchgear condition issue;
Potential credible solutions include:
1.
replacement of Auburn and Lidcombe ZS with a new
132/11kV zone substation adjacent to Lidcombe ZS
(preferred)
2.
replacement of 33kV feeders from Homebush STS to Auburn
and Lidcombe ZS and refurbish Lidcombe ZS
3.
replacement of 33kV feeders from Homebush STS to Auburn
and Lidcombe ZS and reconfigure Lidcombe ZS or
4.
retirement of Lidcombe ZS and uprate Auburn ZS.
Note: From the strategic solution point of view Auburn & Lidcombe
zone substation identified needs are addressed together.
Dec-15
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV switchgear with new 11kV single bus
switchgear (Preferred)
2. decommission existing Lisarow zone and permanently
transfer all the loads to neighbouring zones or
decommission existing Lisarow ZS and establish a new
132/11kV ZS on adjacent site.
5.3.5
Inner West
5.3.6
Lower Central Lisarow ZS
Coast
Distribution and Transmission Annual Planning Report December 2013
139
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.6
5.3.7
Lower
Central
Coast
Pittwater &
Terrey Hills
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Lisarow ZS
Dec-13
Asset
Condition
NA
-
33kV circuit breakers condition issues.
Credible solutions include:
1. like-to-like replacement (Preferred)decommission existing
Lisarow zone and permanently transfer all the loads to
neighbouring zones or
2. decommission existing Lisarow ZS and establish a new
132/11kV ZS on adjacent site.
Umina ZS
Sep-16
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV switchgears with new 11kV single bus
switchgears(Preferred)
2. decommission the old 11kV switchgears and permanently
transfer all the loads to neighbouring zones or decommission
existing Umina ZS, and
3. establish a new ZS on adjacent site.
Careel Bay
33/11kV ZS
Jun-15
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV switchgears with new 11kV single bus
switchgears(Preferred)
2. decommission the old 11kV switchgears and permanently
transfer all the loads to neighbouring zones
3. decommission existing Careel Bay ZS and establish a new
ZS on adjacent site.
Mona Vale 33/11kV
ZS
Sep-16
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV switchgears with new 11kV single bus
switchgears(Preferred)
2. decommission the old 11kV switchgears and permanently
transfer all the loads to neighbouring zones or
3. decommission existing Mona Vale ZS and establish a new
ZS on adjacent site.
Distribution and Transmission Annual Planning Report December 2013
140
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.7
5.3.8
Pittwater &
Terrey Hills
St George
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Narrabeen 33/11kV
ZS
Sep-17
Asset
Condition
NA
-
33kV steel structure and 33kV oil circuit breakers.
Credible solutions include:
1. removal of 33kV busbar and replacement of feeder 33kV oil
circuit breakers (Preferred) or
2. 33kV steel structure like-to-like replacement.
Terrey Hills
33/11kV ZS
Sep-17
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV switchgears with new 11kV single bus
switchgears(Preferred)
2. decommission the old 11kV switchgears and permanently
transfer all the loads to neighbouring zones or
3. decommission existing Terrey Hills ZS and establish a new
ZS on adjacent site.
Arncliffe
Dec-16
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. retire Arncliffe ZS by transferring load to proposed new
Rockdale 132/11kV ZS (preferred)
2. refurbishment of Arncliffe ZS or
3. replacement of Arncliffe ZS with a new zone substation.
Rockdale
Sep-18
Asset
Condition
NA
-
11kV and 33kV switchgear condition issues. All the issues including
33kV feeders related to Rockdale zone substation are to be addressed
together.
Credible solutions include:
1. replacement of Rockdale zone with a new 132/11kV ZS
(preferred)
2. refurbishment of Rockdale ZS
3. retirement of Rockdale ZS via 11kV load transfers to adjacent
zone.
Distribution and Transmission Annual Planning Report December 2013
141
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Peakhurst STS
Sep-18
Asset
Condition
NA
-
33kV building and circuit breaker issues.
Credible solutions include:
1. replace or repair 33kV switchgear building and roof in situ
(preferred)
2. construct a new 33kV switchgear building retire the existing
building
3. retirement of 33kV portion at Peakhurst STS.
Sutherland
Kurnell STS
Dec-14
Asset
Condition
NA
-
33kV switchgear condition and busbar height non-compliance duty of
care issues.
Credible solutions include:
1. include retirement of 33kV portion of Kurnell STS (preferred)
2. refurbishment of 33kV switchgear and busbar at Kurnell STS.
Sydney CBD
Dalley St ZS
Sep-17
Asset
Condition
NA
-
132kV and 11kV switchgear condition issues.
Credible solutions include:
1. replacement of Dalley St ZS with a new Bligh St ZS
(preferred),
2. refurbish the existing Dalley St ZS or
3. retire the existing Dalley St ZS via 11kV load transfers to
adjacent zones.
The anticipated commissioning of the Bligh St ZS is December 2019.
Oct-15
Asset
Condition
NA
-
Unavailability of 33kV from Delta Electricity Munmorah BSP from March
2017.
Credible solutions include:
1. development of new Munmorah 132/33kV STS (preferred)
2. conversion of existing Noraville and Vales Point ZS to
132/11kV operation.
Dec-14
Asset
Condition
NA
-
11kV switchgear condition issues.
Credible solutions include:
1. replace old 11kV with new 11kV single bus switchgear
(preferred)
2. decommission the old 11kV switchgear and permanently
transfer all the loads to neighbouring zones or
3. decommission existing Vales Point ZS and establish new ZS.
5.3.8
St George
5.3.9
5.3.10
5.3.11
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Upper
Munmorah BSP
Central Coast
Vales Point ZS
Distribution and Transmission Annual Planning Report December 2013
142
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
Cessnock 33/11kV
zone substation
NA
None
Credible solutions include:
1. Refurbish substation
2. Build replacement zone substation.
Dec-14
Asset Conditon
(33kV
switchgear)
NA
None
Credible solutions include:
1. Retire substation and augment 33kV network (33kV load
transfers to Argenton STS)
2. Refurbish Awaba STS.
Tarro 33/11kV zone
substation
Nov-13
Capacity
1.2
None
Credible solutions include:
1. Demand Management
2. Tarro to Thornton 11kV load transfer
3. Build new Beresfield 132/11kV zone substation (and retire
Tarro)
4. Build replacement Tarro 33/11kV zone substation.
Telarah 33/11kV
zone substation
Nov-13
Capacity
1.1
None
Credible solutions include:
1. 11kV load transfer
2. Demand Management
3. Build new Telarah West 33/11kV zone substation (and retire
Telarah)
4. Refurbish Telarah 33/11kV zone substation.
Telarah 33/11kV
zone substation
Dec-16
Asset
Condition
NA
None
Credible solutions include:
1. Build new Telarah West 33/11kV zone substation (and retire
Telarah)
2. 33kV and 11kV network augmentation to retire Telarah (load
transfers to Rutherford and Maitland)
3. Refurbish Telarah zone substation.
Kotara 33/11kV
zone substation
Dec-14
Asset
Condition
(33kV
switchgear)
NA
None
Credible solutions include:
1. Retire 33kV switchgear and transformer-end 33kV feeders
2. Replace 33kV switchgear.
5.3.13
Hunter
Awaba 132/33kV
Transmission substransmission
substation
5.3.15
Newcastle
Inner City
Discussion of Potential Credible Solutions
Asset
Condition
(building)
Greater
Cessnock
Maitland
Impact on
Transmission
-Distribution
Connection
Points
Jun-14
5.3.12
5.3.14
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Distribution and Transmission Annual Planning Report December 2013
143
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
5.3.16
Newcastle
Ports
Waratah 132/33kV
sub-transmission
substation
Jun-14
Asset
Condition
(33kV
switchgear)
NA
None
Credible solutions include:
1. Refurbish substation to maintain supply to major customers
(Comsteel and SRA)
2. Build replacement substation to maintain supply to major
customers (Comsteel and SRA).
5.3.17
Newcastle
Western
Corridor
Edgeworth 33/11kV
zone substation
Nov-13
Capacity
0.2
None
Credible solutions include:
1. 11kV load transfer
2. Demand Management
3. Replace 11kV switchgear (upgrade substation capacity)
4. New Cameron Park ZS (and retire Edgeworth ZS).
Edgeworth 33/11kV
zone substation
Dec-18
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. 11kV network augmentation to retire Edgeworth (load
transfers to Cardiff and Argenton)
3. New Cameron Park ZS (and retire Edgeworth).
Swansea 33/11kV
zone substation
Dec-18
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
Jun-14
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
5.3.18
Northeast
Lake
Macquarie
5.3.19
Port Stephens Nelson Bay
33/11kV zone
substation
Distribution and Transmission Annual Planning Report December 2013
144
Sub-transmission STS Substation and Zone Substation Limitations
System Limitation
Timing
Load Area
5.3.20
5.3.21
5.3.22
Singleton
Upper Hunter
West Lake
Macquarie
Driver
Substation Name
Load
reduction
required for 1
year deferral
(MW)
Impact on
Transmission
-Distribution
Connection
Points
Discussion of Potential Credible Solutions
Branxton 66/11kV
zone substation
Jun-14
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
Singleton 66/11kV
zone substation
Jun-14
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
Denman 66/11kV
zone substation
Dec-18
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
Mitchell Line
66/11kV zone
substation
Dec-18
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Build replacement zone substation.
Cooranbong
33/11kV zone
substation
(dedicated
customer)
Dec-14
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Transfer customer POC to Rathmines 11kV network
3. Construct 33kV switching station (and transfer assets to
customer)
4. Build replacement zone substation.
Myuna 33/11kV
zone substation
(dedicated
customer)
Dec-14
Asset
Condition
(11kV
switchgear)
NA
None
Credible solutions include:
1. Replace 11kV switchgear
2. Transfer customer Point of Connection to Avondale 11kV
network
3. Construct 33kV switching station (and transfer assets to
customer)
4. Build replacement zone substation.
Distribution and Transmission Annual Planning Report December 2013
145
5.4
Primary Distribution Feeder Limitations
The table below shows four primary distribution feeder limitations that were present in Summer 2012/13. However, these limitations have been either already
addressed with a project already completed, or will be addressed prior to summer 2013/14 with a committed project.
Identified Primary Distribution Feeder Limitations
Zone Substation
Feeder
Name
Normal Cyclic Rating
(MVA)
Summer
Winter
Extent Load Exceeds Normal Cyclic Rating (MVA)
Current Year
Next Two Years
Summ er
Summer
Winter
Summer
Winter
Winter
2014/15
2012/13
2013
2013/14
2014
2015
Estimated Load Reduction to Defer
Limitation for 1 Year (MVA)
Load Area
Cessnock
Load
Timing
Location
Kurri ZS
80922
3.54
-
0.29
-
-
-
-
-
N/A
N/A
Kurri
Westlakes
Morisset ZS
80080
6.00
-
0.04
-
-
-
-
-
0.04
Nov-12
Morisset
Rathmines Temporary
ZS
33344
6.17
-
0.55
-
-
-
-
-
N/A
N/A
Rathmines
11kV upgrade works issued
Temporary
(SM-19816 & WBS3278) and
ZS
completed before S 13/14.
Limitation no longer exists.
81244
3.54
-
0.76
-
-
-
-
-
N/A
N/A
Raymond
11kV upgrade works issued
Terrace
(SM-20002) and completed
New ZS
before S 13/14. Limitation no
longer exists.
Port Stephens Raymond Terrace
New ZS
Distribution and Transmission Annual Planning Report December 2013
146
Potential Credible Solutions
11kV upgrade works issued
(SM-16245) and completed
before S 13/14. Limitation no
longer exists.
11kV upgrade works issued
(SM-06403) with completion
expected prior to S 13/14.
Limitation is forecast to be
addressed prior to S 13/14.
6
Network Investments
6.1
Regulatory Tests completed during the year
The RIT-D has a commencement date of 1 January, 2014 and there are provisions in the NER for a transition
to the RIT-D which permit all project assessments commenced under the Regulatory Test prior to 31
December, 2013 to be finalised under that process subject to approval from the AER.
Ausgrid finalised 18 Regulatory Tests in the preceding year as detailed below.
6.1.1
Final Report- Jannali Zone Substation 11kV development
There are existing supply capacity limitations on the Jannali Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options investigated to address the identified limitations affecting the supply network
include:

Demand Management

Option 1 – Establish new feeder from Jannali Zone Substation

Option 2 – Underbore from Jannali Panel 28 to Miranda Panel 2.
Consideration of demand management options for the Jannali ZS load area was carried out in February 2013.
The overall demand reduction required represented a significant proportion of the existing load (9%). Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $90,000 or $74/kVA, which is low. Based on this information it was concluded that demand
management is not a viable option in this instance.
Ausgrid’s preferred and recommended action was Option 1 – Establish new feeder from Jannali Zone
Substation. This option establishes the new feeder by a tee-connection to the Panel 28 endbox at Jannali ZS,
utilising out-of-service 500mm2 cable, transferring load from Jannali Panel 31 feeder, installing an intellirupter
and establishing a new overhead/underground feeder connection to the Panel 21 feeder.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC ($m)
Ranking
Option 1
Establish new feeder from Jannali Zone Substation
1.15
1
Option 2
Underbore from Jannali Panel 28 to Miranda Panel 2
1.85
2
The proposed works will be completed in conjunction with the replacement of switchgear at Jannali ZS and
associated feeder renumbering. The estimated capital cost for this option is $1.26 million (nominal) and is
planned to be completed by June 2014.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
147
6.1.2
Final Report- Raymond Terrace 11kV Feeders Upgrade
There are existing supply capacity limitations on the Raymond Terrace Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options investigated to address the identified limitations affecting the supply network
include:

Demand Management

Option 1 – Upgrade OH mains on feeders 81236L and 81244L, install a new UG interconnection from
feeder 81240L to 81244L

Option 2 – Upgrade OH mains on feeder 81236L, install new UG interconnections from feeder 81240L to
81244L and 81236L to 81241L.
A demand management screening test concluded that the potential savings derived from deferring this option
by one year would be $76,000 or $14/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s proposed and recommended action is to proceed with Option 1 – Upgrade OH mains on feeders
81236L and 81244L, install a new UG interconnection from feeder 81240L to 81244L, and install a new OH
interconnection on feeder 81244L. This option involves: reconductoring 1.6km of overhead mains on feeders
81236L and 81244L with Pluto 19/3.25 AAC conductor, installing an underground connection between feeders
81244L and 81240L, and installing a new 250m overhead interconnection with one ELBS on feeder 81244L.
The estimated capital cost for this option is $0.97 million (nominal) and is planned to be completed by
November 2014.
Summary of base case economic analysis (12/13 real dollars):
Options

NPC ($m)
Ranking
Option 1
Upgrade OH mains on feeders 81236L and 81244L,
install a new UG interconnection from feeder 81240L to
81244L
0.91
1
Option 2
Upgrade OH mains on feeder 81236L, install new UG
interconnections from feeder 81240L to 81244L and
81236L to 81241L
1.08
2
The estimated capital cost for this option is $0.97 million (nominal) and is planned to be completed by
November 2014.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
148
6.1.3
Final Report- Rathmines Zone Substation 11kV Feeders
There are existing supply capacity limitations on the Rathmines Transportable Zone Substation (ZS) 11kV
distribution network due to load growth in the area. To ensure a safe and reliable electricity supply for existing
customers and proposed developments in the area, an integrated strategy is required to provide additional
11kV network capacity to meet projected load growth. Possible investment options investigated to address the
identified limitations affecting the supply network are described below:

Demand Management

Option 1 – Change open points

Option 2 – Establish a new feeder from Rathmines Permanent ZS and augment 11kV network

Option 3 – Establish two new feeders from Rathmines Permanent ZS and construct a new
interconnection.
Ausgrid consideration of demand management found that the overall demand reduction required represented
a significant proportion of the existing load. Given the cost of the proposed supply-side option, the potential
savings derived from deferring this option by one year would be $80,000 or $14/kVA, which is low. Based on
this information, it was not considered reasonable to expect that it would be cost effective to postpone the
proposed supply-side solution by implementing demand management. It was concluded that demand
management is not a viable option in this instance.
Ausgrid’s proposed option and recommended action which is to proceed with Option 2 – Establish a new
feeder from Rathmines Permanent ZS and augment 11kV network. This option involves constructing a new
feeder from Rathmines Permanent 132/11kV ZS to the Rathmines area by upgrading 1.1km of existing 11kV
overhead feeder, constructing 2km of new overhead 11kV feeder and 1.8km of new underground 11kV feeder.
A voltage regulator will also be installed and two feeder interconnections will be established.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC #($m)
Option 1
Change open points
F
Ranking
0
NA
Option 2
Establish a new feeder from Rathmines Permanent ZS
and augment 11kV Network
1.12
1
Option 3
Establish two new feeders from Rathmines Permanent
ZS and construct a new interconnection
5.98
2
The estimated capital cost for this option is $1.23 million (nominal) and is planned to be completed by
November 2013.
Distribution and Transmission Annual Planning Report December 2013
149
6.1.4
Final Report- Nelson Bay (Anna Bay) New 11kV Development
There are existing supply capacity limitations on the Nelson Bay Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network include:

Demand Management

Option 1 – New underground/overhead feeder along Nelson Bay Road

Option 2 – New underground feeder along Nelson Bay Road

Option 3 – New overhead feeder along Frost Rd and Gan Gan Rd to Clark St and interconnection to Port
Stephens Drive

Option 4 – New underground feeder along Frost Rd and Gan Gan Rd to Clark St and interconnection to
Port Stephens Drive.
Consideration of demand management options for the Nelson Bay ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load. Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $102,000 or $107/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management strategies.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – New
underground/overhead feeder along Nelson Bay Road. This option involves creating a new feeder to supply
the Anna Bay area by building approximately 3.8km of overhead mains on the existing 33kV feeder along
Nelson Bay Rd to Gan Gan Rd and providing an underground interconnection (approximately 1km) to Port
Stephens Dr from Gan Gan Rd.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC ($m)
Ranking
Option 1 - New underground/overhead feeder along
Nelson Bay Road
1.43
1
Option 2 - New underground feeder along Nelson Bay
Road
4.20
3
Option 3 - New overhead feeder along Frost Rd and
Gan Gan Rd to Clark St and interconnection to Port
Stephens Drive
2.01
2
Option 4 - New underground feeder along Frost Rd and
Gan Gan Rd to Clark St and interconnection to Port
Stephens Drive
5.42
4
The estimated capital cost for this option is $1.57 million (nominal) and is planned to be completed by June
2014.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
150
6.1.5
Final Report- Nelson Bay New 11kV Development
There are existing supply capacity limitations on the Nelson Bay Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified limitations affecting the supply network considered
include:

Demand Management

Option 1 – New interconnection along fire trail from Marine Drive to Government Road

Option 2 – New interconnection along Shoal Bay Road from Harwood Avenue to Government Road

Option 3 – New interconnection along Marine Drive, Gowrie Avenue and Shoal Bay Road.
Consideration of demand management options for the Nelson Bay ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load. Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $63,000 or $33/kVA, which is low. Based on this information it was not considered reasonable
to expect that it would be cost effective to postpone the proposed supply-side solution by implementing
demand management. Therefore, it was concluded that demand management is not a viable option in this
instance.
Ausgrid’s proposed option and recommended action was to proceed with Option 1 – New interconnection
along fire trail from Marine Drive to Government Road. This option involves establishing a new underground
11kV interconnection along the fire trail from Marine Drive to Government Road (approximately 1.5km) and
installing an air break switch.
Summary of base case economic analysis (12/13 real dollars):
NPC ($m)
Ranking
Option 1
New interconnection along fire trail from Marine Drive to
Government Road
0.88
1
Option 2
New interconnection along Shoal Bay Road from Harwood
Avenue to Government Road
1.31
2
Option 3
New interconnection along Marine Drive, Gowrie Avenue
and Shoal Bay Road
1.78
3
Options
The estimated capital cost of the preferred option is $0.96 million (nominal) and is planned to be completed by
December 2013.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
151
6.1.6
Final Report- Edgeworth New 11kV Development
There are existing supply capacity limitations on the Edgeworth Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options investigated to address the identified limitations affecting the supply network
included:

Demand Management

Option 1 – New overhead feeder and interconnection from Edgeworth ZS

Option 2 – New underground/overhead feeder and interconnection from Edgeworth ZS.
Consideration of demand management options for the Edgeworth ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load. Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $352,000 or $154/kVA, which is low. Based on this information, it was not reasonable to
expect that it would be cost effective to postpone the proposed supply-side solution by implementing demand
management.
Ausgrid’s proposed and recommended action was to proceed with Option 2 – New underground/overhead
feeder and interconnection from Edgeworth ZS. This option involves installing a new 4-way duct line with two
11kV circuits from Edgeworth ZS to Dunbar Road. From there, one circuit will be constructed as a single
circuit overhead line and provide interconnection with feeders from Maryland ZS. The other feeder will
continue as underground construction and provide interconnection with other feeders from Edgeworth ZS.
Summary of base case economic analysis (12/13 real dollars):
Options

NPC ($m)
Ranking
Option 1
New overhead feeder and interconnection from
Edgeworth ZS
3.08
2
Option 2
New underground/overhead feeder and interconnection
from Edgeworth ZS
2.90
1
The estimated capital cost for this option is $3.41 million (nominal) and is planned to be completed by
December 2013.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
152
6.1.7
Final Report- Kurri Kurri New Heddon Greta 11kV Development
There are existing supply capacity limitations on the Kurri Kurri Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network included:

Demand Management

Option 1 – Upgrade feeder 48010

Option 2 – Establish a new underground feeder to Cliftleigh

Option 3 – Establish a new overhead feeder to Heddon Greta

Option 4 – Create Interconnection to Kurri Kurri Feeder 80923.
Consideration of demand management options for the Kurri Kurri ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load (41%).
Given the cost of the proposed supply-side option, the potential savings derived from deferring this option by
one year would be $63,000 or $37/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s proposed option and recommended action was to proceed with Option 3 – Establish a new
overhead feeder to Heddon Greta. This option involves installing a regulator near the Heddon Greta recloser
and establishing a new overhead/underground feeder from Kurri Kurri ZS via Kurri Sub-transmission
Substation (STS) to Cliftleigh by utilising spare 33kV overhead feeder along Northcote Street, Kurri, spare
conduits to Kurri STS and the abandoned 66kV overhead feeder 860.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC ($m)
Ranking
Option 1 - Upgrade feeder 48010
1.96
4
Option 2 - Establish a new underground feeder to
Cliftleigh
1.43
2
Option 3 - Establish a new overhead feeder to Heddon
Greta
0.88
1
Option 4 - Create Interconnection to Kurri Kurri Feeder
80923
1.82
3
The estimated capital cost for this option is $0.96 million (nominal) and is planned to be completed by June
2014.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
153
6.1.8
Final Report- Kurri Kurri Zone Substation 11kV Feeders
There are existing supply capacity limitations on the Kurri Kurri Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible options to address the identified needs affecting the supply network include:

Demand Management

Option 1 – Install a regulator on feeder 80922 and upgrade feeders 48028, 80922 and 80931

Option 2 – Install new interconnection to 80922 and upgrade feeders 48028, 80922 and 80931

Option 3 – Establish a new feeder to Abermain and upgrade feeders 48028, 80922 and 80931.
Consideration of demand management options for the Kurri Kurri ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load. Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $70,000 or $45/kVA, which is low. Based on this information, it was not considered reasonable
to expect that it would be cost effective to postpone the proposed supply-side solution by implementing
demand management.
Ausgrid’s preferred option and recommended action is to proceed with Option 1 – Install a regulator on feeder
80922 and upgrade feeders 48028, 80922 and 80931. This option involves installing a regulator in Sawyers
Gully, adjusting settings on two reclosers and replacing approximately 3.6km of conductor on feeders 48028,
80922 and 80931.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC*($m)
Ranking
Option 1
Install a regulator on feeder 80922 and upgrade feeders
48028, 80922 and 80931
0.97
1
Option 2
Install new interconnection to 80922 and upgrade
feeders 48028, 80922 and 80931
1.73
2
Option 3
Establish a new feeder to Abermain and upgrade
feeders 48028, 80922 and 80931
2.34
3
The estimated capital cost for this option is $1.07 million (nominal) and is planned to be completed by June
2014.
Distribution and Transmission Annual Planning Report December 2013
154
6.1.9
Final Report- Maitland Central New 11kV Development
There are existing supply capacity limitations on the Maitland Central Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network include:

Demand Management

Option 1 – Upgrade Wallalong overhead 11kV feeder 48164 (Future Brandy Hill feeder 82579)

Option 2 – Upgrade East Maitland overhead 11kV feeder 48011 (Future Brandy Hill feeder 82576)

Option 3 – Upgrade Maitland Central overhead 11kV feeder 48122.
Consideration of demand management options for the Maitland Central load area was carried out in
December 2012. The overall demand reduction required represented a significant proportion of the existing
load. Given the cost of the proposed supply-side option, the potential savings derived from deferring this
option by one year would be $84,000, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action which is to proceed with Option 3 – Upgrade Maitland
Central overhead 11kV feeder 48122. This option involves replacing approximately 2.5km of conductor on
existing Maitland Central feeder 48122, constructing approximately 700m of new 11kV overhead line and
installing a regulator on existing Maitland Central feeder 48123.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC ($m)
Ranking
Option 1
Upgrade Wallalong overhead 11kV feeder 48164
(Future Brandy Hill feeder 82579)
1.27
3
Option 2
Upgrade East Maitland overhead 11kV feeder 48011
(Future Brandy Hill feeder 82576)
1.21
2
Option 3
Upgrade Maitland Central overhead 11kV feeder 48122
1.17
1
The estimated capital cost for this option is $1.28 million (nominal) and is planned to be completed by
December 2013.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
155
6.1.10 Final Report- Mosman Zone Substation Panel 18 20 22 29 and 42 Feeders
There are existing supply capacity limitations on the Mosman Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth
Possible investment options to address the identified needs affecting the supply network include:

Demand Management

Option 1 – Install new 11kV feeder from Mosman ZS

Option 2 – Install new 11kV feeder from Crows Nest ZS.
Consideration of demand management options for the Mosman ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load. Given
the cost of the proposed supply-side option, the potential savings derived from deferring this option by one
year would be $205,000 or $107.52/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action which is to proceed with Option 1 – Install new 11kV
feeder from Mosman ZS. This option involves installing a new 11kV feeder using new and existing ducts from
Mosman ZS to relieve panels 18, 20, 22, 29 and 42 at Mosman ZS in order to address the identified
constraints on the Mosman ZS distribution network.
Summary of base case economic analysis (12/13 real dollars):
Options

NPC [$m]
Ranking
Option 1 – Install new 11kV feeder from Mosman ZS
2.74
1
Option 2 – Install new 11kV feeder from Crows Nest ZS
5.57
2
The estimated capital cost for this option is $2.74m and is planned to be completed in June 2014.
6.1.11 Final Report- Greenacre Park 11kV Feeders
There are existing supply capacity limitations on the Greenacre Park Zone Substation (ZS) 11kV distribution
network due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers
and proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management.

Option 1 – Install two new 11kV feeders using existing ducts

Option 2 – Install one new 11kV feeder using existing ducts

Option 3 – Install two new 11kV feeders in new ducts

Option 4 – Install one new 11kV feeder in new ducts.
Consideration of Demand Management options for the Greenacre Park ZS load area was carried out in
November 2012. The overall demand reduction required represented a significant proportion of the existing
load (123%). Given the cost of the proposed supply side option, the potential savings derived from deferring
this option by one year would be $305,000 or $170.10/kVA, which is low. Based on this information it was not
considered reasonable to expect that it would be cost effective to postpone the proposed supply-side solution
by implementing demand management.
The preferred option and recommended action is to proceed with Option 1 – Install two new 11kV feeders
using existing ducts. This option involves installing a new 11kV feeder from Greenacre Park ZS to relieve this
substation’s panel 27L and a new 11kV feeder from Potts Hill ZS to relieve panel 27R at Greenacre Park ZS.
It also involves the upgrade of two existing 11kV feeders connected to panels 20R, 31L, 33R and 36 at
Greenacre Park ZS to address the identified constraints on the Greenacre Park ZS distribution network.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
156
Summary of base case economic analysis (12/13 real dollars):
Options
NPC [$m]
Ranking
Option 1 – Install two new 11kV feeders using existing
ducts
4.04
1
Option 2 – Install one new 11kV feeder using existing
ducts
4.73
3
Option 3 – Install two new 11kV feeders in new ducts
4.66
2
Option 4 – Install one new 11kV feeder in new ducts
5.31
4
The estimated capital cost for this option is $4.38m and is planned to be completed in October 2014.
6.1.12 Final Report- Mosman Zone Substation 11kV Panel 24 41 and 43 feeders
There are existing supply security issues under emergency switching conditions on the Mosman Zone
Substation (ZS) 11kV distribution network due to load growth in the area. To ensure a safe and reliable
electricity supply for existing customers and proposed developments in the area, an integrated strategy is
required to provide additional 11kV network capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network include:

Demand Management

Option 1 – Augment existing 11kV feeders

Option 2 – Install new 11kV feeder.
Consideration of Demand Management options for the Mosman ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load (127%).
Given the cost of the proposed supply side option, the potential savings derived from deferring this option by
one year would be $102,000 or $190.61/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – Augment existing 11kV
feeders. This option involves installing sections of new 11kV cables on a total length of approximately 700
metres to relieve panels 24, 41 and 43 at Mosman ZS in order to address the identified constraints on the
Mosman ZS distribution network.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC#[$m]
Ranking
Option 1 – Augment existing 11kV feeders
1.35
1
Option 2 – Install new 11kV feeder
4.69
2
The estimated capital cost for this option is $1.36m and is planned to be completed in June 2014.
Distribution and Transmission Annual Planning Report December 2013
157
6.1.13 Final Report- Mosman Zone Substation 11kV Panel 9,10,17,23,30,32, 34 feeders
There are existing supply capacity limitations on the Mosman Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management

Option 1 – Augment existing 11kV feeders

Option 2 – Install new 11kV feeder.
Consideration of Demand Management options for the Mosman ZS load area was carried out in December
2012. The overall demand reduction required represented a significant proportion of the existing load (158%).
Given the cost of the proposed supply side option, the potential savings derived from deferring this option by
one year would be $218,000 or $156.43/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – Augment existing 11kV
feeders. This option involves installing sections of new 11kV cables on a total length of approximately 1.4
kilometres to relieve panels 9, 10, 17, 23, 30, 32 and 34 at Mosman ZS in order to address the identified
constraints on the Mosman ZS distribution network.
Summary of base case economic analysis (12/13 real dollars):
Options

NPC [$m]
Ranking
Option 1 – Augment existing 11kV feeders
2.89
1
Option 2 – Install new 11kV feeder
5.30
2
The estimated capital cost for this option is $2.91m and is planned to be completed in December 2013.
6.1.14 Final Report- Cardiff New 11kV Development
There are supply security issues on the Cardiff 11kV distribution network due to lack of 11kV network
interconnections. To ensure a safe and reliable electricity supply for existing customers and proposed
developments in the area, an integrated strategy is required to provide supply security to meet projected load
growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management

Option 1 – One new feeder from Cardiff ZS to Warners Bay via Macquarie Rd

Option 2 – One new feeder from Cardiff ZS to Warners Bay using trunk of feeder 8667

Option 3 – Two new feeders from Charlestown ZS to Warners Bay via Hillsborough Rd.
Consideration of Demand Management options for the Cardiff ZS load area was carried out in May 2012. The
overall demand reduction required represents a significant proportion of the existing load (19%). Given the
cost of the proposed supply side option, the potential savings derived from deferring this option by two years
would be $472,000 or $420/kVA, which is moderate. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management. Therefore, it was concluded that Demand Management is not a viable
option in this instance.
The preferred and recommended action is Option 2. This option utilises the essentially spare feeder 8667 after
the load transfer to Argenton ZS. It involves the construction of approximately 2km of new underground feeder
from the intersection of Pendlebury Rd and Macquarie Rd, Cardiff, to substation 55679 ‘ McDonalds Warners
Bay.’ The trunk overhead section of feeder 8667 is utilised as the trunk of the new feeder. Two small
underground interconnections and one overhead interconnection will also be constructed with this option.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
158
Summary of base case economic analysis (12/13 real dollars):
Options
NPC ($m]
Ranking
Option 1
One new feeder from Cardiff ZS to Warners Bay via
Macquarie Rd
4.26
2
Option 2
One new feeder from Cardiff ZS to Warners Bay using
trunk of feeder 8667
3.36
1
Option 3
Two new feeders from Charlestown ZS to Warners Bay
via Hillsborough Rd
5.51
3
The planning estimate for this option is $3.27million (nominal) and is planned to be completed by November
2013.
6.1.15 Final Report- Sefton Zone Substation 11kV Panel 16, 34, 35 feeders
There are existing supply capacity limitations on the Sefton Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified issues affecting the supply network, include:

Demand Management.

Option 1 – Install a new 11kV feeder from Sefton ZS

Option 2 – Install a new 11kV feeder from Lidcombe ZS.
Consideration of Demand Management options for the Sefton ZS load area was carried out in December
2011. The overall demand reduction required represented a significant proportion of the existing load (136%).
Given the cost of the proposed supply side option, the potential savings derived from deferring this option by
one year would be $164,000 or $104.74/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – Install a new 11kV feeder
from Sefton ZS. This option involves installing a new 11kV feeder from Sefton ZS and replacing a short
limiting feeder section on panel 34 feeder at Sefton ZS to address the identified constraints on the Sefton ZS
distribution network.
Summary of base case economic analysis (12/13 real dollars):
Options

NPC [$m]
Ranking
Option 1 – Install a new 11kV feeder from Sefton ZS
2.18
1
Option 2 – Install a new 11kV feeder from Lidcombe ZS
4.28
2
The estimated capital cost for this option is $2.10m (Nominal) and is planned to be completed in October
2013.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
159
6.1.16 Final Report- Thornton Zone Substation 11kV Development
There are existing supply capacity limitations on the Thornton Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management

Option 1 – Install new feeder from Thornton ZS to Beresfield Industrial Estate

Option 2 – Install new feeder from Tarro ZS and upgrade Thornton ZS feeders.
Consideration of Demand Management options for the Thornton ZS load area was carried out in June 2012.
The overall demand reduction required represented a significant proportion of the existing load (124%). Given
the cost of the proposed supply side option, the potential savings derived from deferring this option by one
year would be $133,000 or $97/kVA, which is low. Based on this information, it was not considered
reasonable to expect that it would be cost effective to postpone the proposed supply-side solution by
implementing demand management.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – Install new feeder from
Thornton ZS to Beresfield Industrial Estate. This option involves installing a new 11kV feeder from Thornton
ZS to the Beresfield Industrial area on Weakleys Drive to address the identified constraints on the Thornton
ZS distribution network. In addition, Thornton ZS to Tarro ZS feeders will be reconfigured and new
interconnectors will be formed in the Thornton ZS network.
Summary of base case economic analysis (12/13 real dollars):

NPC [$k]
Ranking
Option 1 – Install a new feeder from Thornton ZS to
Beresfield Industrial Estate
1,765
1
Option 2 – Install a new feeder from Tarro ZS and
upgrade Thornton ZS feeders
3,820
2
Options
The estimated capital cost for this option is $1.65m (Nominal) and is planned to be completed in November
2013.
6.1.17 Final Report- Pelican 11kV Zone 11kV Development
There are existing supply capacity limitations on the Pelican Zone Substation (ZS) 11kV distribution network
due to load growth in the area. To ensure a safe and reliable electricity supply for existing customers and
proposed developments in the area, an integrated strategy is required to provide additional 11kV network
capacity to meet projected load growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management

Option 1 – Install new feeder from Pelican ZS to Belmont CBD

Option 2 – Install new feeder from Croudace Bay ZS to Halyard Way substation

Option 3 – Reconductor feeders from Pelican ZS to Belmont CBD.
Consideration of Demand Management options for the Pelican ZS load area was carried out in July 2012. The
overall demand reduction required in the next 12 months represents a significant proportion of the existing
load (156%). Given the cost of the proposed supply side option, the potential savings derived from deferring
this option by one year would be $323,000 or $101/kVA, which is low. Based on this information, it was not
considered reasonable to expect that it would be cost effective to postpone the proposed supply-side solution
by implementing demand management.
Ausgrid’s preferred option and recommended action was to proceed with Option 1 – Install new feeder from
Pelican ZS to Belmont CBD. This option involves installing a new 11kV underground feeder from Pelican ZS
to Belmont CBD to address the identified constraints on the Pelican ZS distribution network. In addition,
Pelican ZS to Croudace Bay ZS cables will be reconfigured and new interconnectors will be formed in the
Pelican ZS network.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
160
Summary of base case economic analysis (12/13 real dollars):
Options

NPC [$k]
Ranking
Option 1 – Install a new feeder from Pelican ZS to
Belmont CBD
4,303
1
Option 2 – Install a new cable from Croudace Bay ZS to
Halyard Way substation
4,524
2
Option 3 – Reconductor feeders from Pelican ZS to
Belmont CBD
5,286
3
The estimated capital cost for this option is $4.07m and is planned to be completed in November 2013.
6.1.18 Final Report- South Eastern Flemington ZS 11kV Development
There are supply security issues on the Flemington Zone Substation (ZS) 11kV distribution network due to
load growth in the area. To ensure a safe and reliable electricity supply for existing customers and proposed
developments in the area, an integrated strategy is required to provide additional supply system capacity to
meet projected load growth.
Possible investment options to address the identified needs affecting the supply network, include:

Demand Management

Option 1 – Install new interconnection cable

Option 2 – Modify network connectivity and install new interconnection cable

Option 3 – Augment existing underground cables and install new interconnection cable.
Consideration of Demand Management options for the Flemington ZS load area was carried out in November
2011. The overall demand reduction required in the next 12 months represents a significant proportion of the
existing load. Given the cost of the proposed supply side option, the potential savings derived from deferring
this option by one year would be $73,000 or $52.5/kVA, which is low. Based on this information, it was not
considered reasonable to expect that it would be cost effective to postpone the proposed supply-side solution
by implementing demand management strategies.
Ausgrid’s preferred option and recommended action which is to proceed with Option 1 – Install new
interconnection cable. This option involves installing a new interconnection cable between Flemington ZS
panels 11 and 40 feeder cables by utilizing available cables recently installed, as well as replacing the limiting
sections of panel 45 feeder cable to cater for current and future demand and address the constraints on the
Flemington ZS distribution network.
Summary of base case economic analysis (12/13 real dollars):
Options
NPC# [$k]
Option 1 – Install new interconnection cable
Ranking
969
1
Option 2 – Modify network connectivity and install new
interconnection cable
1,020
2
Option 3 – Augment existing underground cables and
install new interconnection cable
1,167
3
The estimated capital cost for this option is $1.05m and is planned to be completed in November 2014.

The Net Present Cost also includes operation and maintenance costs.
Distribution and Transmission Annual Planning Report December 2013
161
6.2
Regulatory Tests in progress during the year
6.2.1
Development of Alexandria 132/33kV STS
Ausgrid published a Consultation Paper on the development of Alexandria 132/3kV STS on 12 August, 2013.
The identified network needs are the asset condition of the 33kV feeders to Sydney Airport and emerging
capacity issues due to new data centre loads in Green Square and Mascot from mid 2014.
The distribution network asset replacement options identified in the Consultation Paper are not driven by a
need to increase network capacity. However, some of the replacement options presented also contain an
augmentation component that facilitates future capacity increases associated with the new Alexandria Sub
Transmission Substation (STS) that would result in a new distribution network asset. Although the least cost
option has an augmentation component of less than $10 million, the proposed works would introduce a
significant change in the topology of the network. For this reason, Ausgrid conducted preliminary Regulatory
Test economic evaluations of the network replacement options identified below and invited alternative
proposals and comments from Registered Participants and Interested Parties.
Based on a condition assessment report for the Sydney Airport 33kV feeders:

Sydney Airport feeders 331 (12.9km long) and 352 (8.0km) as well as International Terminal feeder 356
(10.1km) have been prioritised for replacement by 2016

Feeder 345 (8.3km) to Sydney Airport has been prioritised for replacement by 2018, and

The remaining 33kV feeder 359 (10.0km) is also aged and will reach the end of its serviceable life by
2026.
Possible asset replacement options for addressing the identified needs that affect the supply network are:

Consideration of Demand Side Management

Strategy 1: Refurbish Mascot 33/11kV Zone Substation (ZS) and new Alexandria STS

Strategy 2: Mascot 132/11kV ZS and new Alexandria STS

Strategy 3: Mascot 132/11kV ZS and maintain Bunnerong North STS supply

Strategy 4: Refurbish Mascot 33/11kV ZS and maintain Bunnerong North STS supply.
The following table shows the preliminary ranking of the options considered by Ausgrid in terms of increasing
Net Present Cost utilising a base case 8.5% discount rate.
Options
NPC ($m)
Capital Cost
($m)
Option1 - Refurbish Mascot 33/11kV ZS and new
Alexandria STS
67.69
101.81
Option 2 - Mascot 132/11kV ZS and new Alexandria STS
94.00
133.29
Option 3 - Mascot 132/11kV ZS and maintain Bunnerong
North STS supply
97.20
143.62
Option -3 Refurbish Mascot 33/11kV ZS and maintain
Bunnerong North STS supply
87.47
144.16
Ausgrid did not receive any submissions to the Consultation. It is anticipated that a Final Report will be
published by March 2014.
6.2.2
System limitations in circuits 9SA and 9SB/1
Ausgrid published a Consultation Paper on the identified limitations on feeders 9SA and 9SB/1 in December,
2013. Lane Cove STSS to Dalley Street ZS 132kV circuits 92L/3 and 92M/1 are oil filled cables which were
due for retirement in 2011 following the commissioning of 132kV circuit 9S4. However, the de-rating of circuits
9SA and 9SB/1 has prevented this. The condition of these feeders impacts on the transmission capacity
across part of the Sydney Inner Metropolitan load area. 132kV circuits 9SA and 9SB/1 run from Beaconsfield
BSP to Campbell St ZS and Surry Hills Annex STSS respectively. Following the commissioning of Belmore
Park ZS, these circuits will form part of the major transmission supply to the eastern suburbs. The existing
circuits are oil-filled cables with an expected replacement date of 2024.
Distribution and Transmission Annual Planning Report December 2013
162
Recent analysis of soil, backfill and mutual heating along the route of 132kV circuits 9SA and 9SB/1 which run
from Beaconsfield BSP to Campbell St ZS and Surry Hills Annex STSS respectively, has indicated previously
unknown limitations to their thermal capability. As a result, the rating for each of these circuits has been
reduced from 250MVA to 130MVA, which results in a 240MVA reduction in capacity. The consequence is a
previously unaccounted capacity constraint of 30MVA by summer 2014/15 and 100MVA by summer 2017/18
in the 132kV network between the Haymarket and Beaconsfield BSPs. Further constraints will emerge after
summer 2018/19 as demand grows and a number of circuits reach the end of their service life.
Potential options for addressing the identified needs that affect the supply network are:

Option 1 – Installation of new 132kV circuit from Beaconsfield to Belmore Park and partial remediation of
circuits 9SA and 9SB/1

Option 2 – Full remediation of circuits 9SA and 9SB/1 and Demand Management

Option 3 – Advance replacement of circuits 9SA and 9SB/1, partial remediation of circuits 9SA and 9SB/1
and Demand Management, and

Option 4 – Replacement of circuits 92L/3 and 92M/1, partial remediation of circuits 9SA and 9SB/1 and
Demand Management.
The following table shows a preliminary ranking of the options considered by Ausgrid in terms of increasing
NPC utilising a base case 7.0% discount rate.
6.2.3
Options
NPC
($m)
Capital Cost
($m)
Augmentation
Cost ($m)
Option 1 - Installation of new 132kV circuit from
Beaconsfield to Belmore Park and partial remediation of
circuits 9SA and 9SB/1
92.3
147.8
21.4
Option 2 - Full remediation of circuits 9SA and 9SB/1
and Demand Management
109.4
169.1
42.7
Option 3 - Advance replacement of circuits 9SA and
9SB/1, partial remediation of existing circuits 9SA and
9SB/1 and Demand Management
119.6
138.7
23.9
Option 4 - Replacement of circuits 92L/3 and 92M/1,
partial remediation of circuits 9SA and 9SB/1 and
Demand Management
206.4
291.5
45.8
Top Ryde Additional 132/11kV Transformer and 11kV Switchgear
Macquarie Park Zone Substation (ZS) is forecast to exceed its license capacity in 2016/17. This is mainly due
to the substantial development around the area of Macquarie Park and North Ryde, in particular data centre,
Macquarie University and North Ryde station precinct developments. As a result, some of the loads need to
be transferred to nearby zones which presently do not have adequate capacity.
Options considered to address this identified capacity need include:

Option 1 - Top Ryde ZS additional transformer and 11kV Switchgear

Option 2 – Demand management.
A Demand Management screening test was carried out and it was found that it is not considered reasonable
to expect that it would be cost effective to postpone the proposed supply-side solution by implementing
demand management strategies. It is anticipated that a Final Report detailing the result of the economic
assessment under the Regulatory Test will be published by June 2014.
Distribution and Transmission Annual Planning Report December 2013
163
6.3
Regulatory Investment Tests (RIT-D) for the forward planning period
The table below shows the identified capacity needs that will require a RIT-D within the 5 year forward
planning period.
Project Name
Identified
need date
Proposed
(RIT-D) date
Tarro to Thornton
11kV LT (8MVA)
Dec-2018
Mar-2017
Capacity constraint at Tarro 33/11kV
Zone Substation
Pyrmont STS 4th
Transformer
Sep-2016
Mar-2014
Large data centre customer driven
need that will also require shared
network augmentation
11kV supply from
Mayfield West Zone
Substation
Mar-2017
Jun-2014
Large customer driven need at
Newcastle Port that will also require
shared network augmentation
Distribution and Transmission Annual Planning Report December 2013
Identified Need
164
6.4
Commited Investments
6.4.1
Refurbishment and replacement investments
Ausgrid has identified all committed refurbishment or replacement investments with an estimated capital cost
of $2 million or more. Capital cost estimates are shown in real 2013/14 dollars.
Load Area
Committed Refurbishment or
Replacement Investment
Timing
Capital Cost
Estimate
DAPR
Section
Canterbury –
Bankstown
Bankstown STS 33kV switchgear
replacement
01-Jul-14
$18.0m
6.4.1.1
Canterbury –
Bankstown
Canterbury STS 33kV switchgear
replacement
30-Jun-14
$46.6m
6.4.1.2
Carlingford
Epping zone substation 11kV
switchgear replacement
30-Jun-14
$13.6m
6.4.1.3
31-Mar-15
$98.4m
6.4.1.4
Eastern Suburbs
New Rose Bay 132/11kV zone
substation and feeder.
Eastern Suburbs
New Waverley 132/11kV zone
substation
30-Jun-14
$31.7m
6.4.1.5
Camperdown &
Blackwattle Bay
Camperdown 33kV Feeder
Replacement
30-Apr-14
$22.4m
6.4.1.6
30-Dec-14
$5.4m
6.4.1.7
Lower Central Coast Refurbishment of Gosford STS
Lower Central Coast
Peats Ridge 33kV and 11kV
switchgear replacement
30-May-15
$10.8m
6.4.1.8
Maitland
Metford zone substation (East
Maitland ZS replacement)
31-Mar-15
$28.7m
6.4.1.9
New Castle Inner
City
Newcastle CBD ZN 33kV feeders
replacement FDR 770
30-Sep-13
$15.2m
6.4.1.10
New Castle Inner
City
New Lambton 11kV switchgear
Replacement
30-Jun-15
$12.3m
6.4.1.11
New Castle Inner
City
New Tighes Hill zone substation
30-Nov-15
$27.8m
6.4.1.12
Newcastle Port
Mayfield to Carrington 33kV
feeder replacement
01-Jun-15
$3.6m
6.4.1.13
North East Lake
Macquarie
11kV transportable switchroom
at Pelican ZS
30-Dec-13
$3.8m
6.4.1.14
Port Stephens
Nelson Bay ZN 11kV switchgear
replacement
30-Aug-15
$8.3m
6.4.1.15
Singleton
Newdell ZN 11kV switchgear
replacement
30-Mar-15
$8.1m
6.4.1.16
Upper Hunter
Muswellbrook ZN replacement
- Upgrade to 132/11kV
30-Jun-16
$40m
6.4.1.17
Sydney Inner
Metropolitan (St
George)
132kV feeder 91L and 91M
replacement.
01-Jul-14
$209.8m
6.4.1.18
30-Nov-15
$33.9m
6.4.1.19
Sydney Inner
New Croydon 132/11kV
Metropolitan
zone substation
(Auburn-Homebush)
Distribution and Transmission Annual Planning Report December 2013
165
Load Area
Committed Refurbishment or
Replacement Investment
Timing
Capital Cost
Estimate
DAPR
Section
Sydney Inner
Metropolitan (Inner
West)
132kV feeder 900 replacement.
Rozelle STS to Mason Park
STSS 132kV feeder 900
replacement
31-Mar-15
$80.0m
6.4.1.20
Lower North Shore
Lindfield to Castle Cove 132kV
feeders 925/3 and 9E4/3
replacement
31-Aug-15
$23.4m
6.4.1.21
Lower North Shore
Crows Nest ZN conversion to
132/11kV
31-Dec-15
$20.1m
6.4.1.22
Lower North Shore
New North Sydney 132/11kV
zone substation
28-Feb-15
$82.3m
6.4.1.23
Manly Warringah
Manly zone substation 33kV
switchgear replacement
31-Dec-13
$9.9m
6.4.1.24
Sutherland
Engadine 132/11kV ZN & feeder
912/284 reconfiguration
$41.0m
6.4.1.25
Sutherland
Jannali ZN 11kV switchgear
replacement
31-Mar-14
$16.5m
6.4.1.26
Sutherland
New Kurnell 132/11kV zone
substation on Kurnell STS site
and decommission existing
Kurnell 33/11kV zone substation
30-Mar-14
$15.8m
6.4.1.27
Sutherland
Port Hacking STS 132kV and
33kV busbar replacement
31-Mar-14
$38.9m
6.4.1.28
Sydney CBD
New eastern CBD 132kV cable
tunnel
30-Mar-15
$189.5m
6.4.1.29
Upper North Shore
Kuringai STS 33kV switchgear
replacement
30-Jun-17
$25.9m
6.4.1.30
Upper North Shore
Lindfield zone substation 33kV
feeder and 11kV switchgear
replacement
30-Jun-13
$33.5m
6.4.1.31
Upper North Shore
St Ives 33kV feeder and high
voltage current transformers
replacement
30-Sep-14
$10.2m
6.4.1.32
Upper North Shore
Turramurra zone substation
11kV switchgear replacement
and 33kV feeders replacement
28-Feb-13
$9.3m
6.4.1.33
Upper North Shore
Lindfield to Willoughby 132kV
feeders 9E3(2) and 9E4/2
replacement
30-Sep-15
$44.0m
6.4.1.34
West Lake
Macquarie
New Toronto 132/11kV zone
substation
$25.8m
6.4.1.35
Distribution and Transmission Annual Planning Report December 2013
31-May-14
30-Nov-15
166
6.4.1.1
Bankstown STS 33kV switchgear replacement
The 33kV circuit breakers at Bankstown STS are of the bulk oil type and are at the end of their service lives.
Replacement requirements will be addressed in conjunction with work to address the non-compliant busbar
height.
The Bankstown STS 33kV switchgear replacement project is common across all strategies considered in the
Bankstown Area Plan. Since this project is driven by asset condition and Duty of Care requirements, there are
no viable non-network alternatives for this project. The sub-transmission substation 33kV switchgear
replacement is the committed option.
6.4.1.2
Canterbury STS 33kV switchgear replacement
The 33kV circuit breakers are of the bulk oil type and are at the end of their service lives. Replacement
requirements will be addressed in conjunction with work to address the non-compliant busbar height. Work is
in progress to replace the 33kV switchgear and busbar at Canterbury STS. In conjunction with this work,
additional 132kV feeder bays and a series reactor will also be installed to allow for the connections of feeders
91M and 91L. The capacitor banks are to be replaced at the same time as the above mentioned works.
Options considered include:
Outdoor 132kV busbar refurbishment and indoor 33kV rebuild. This involves rebuilding sections of the outdoor
132kV busbar, construction of a new feeder bay for future feeder 907, refurbishment of an existing feeder bay
for future feeder 906, construction of a new 33kV switchroom, re-routing all 33kV underground feeders into the
new switchroom. This option requires two transformers to be out of service for a period of up to three months,
which from a system security perspective is not viable.
Full 132kV and 33kV switchgear rebuild as indoor Gas Insulated Switchgear (GIS) is the least cost option and
would utilise significantly less land area due to the compactness of indoor GIS plant. This will also free up a
large portion of land at the Canterbury STS site.
Demand Management - This option is not viable as the issues at Canterbury STS are driven by condition and
not capacity.
The preferred and committed option is a full 132kV and 33kV rebuild with GIS. This is a dual function asset,
also described in the TAPR section 12.8.1.2.
6.4.1.3
Epping zone substation 11kV switchgear replacement
Epping zone substation 11kV switchgear replacement
The Epping 11kV switchgear replacement project is common across all strategies considered in the
Carlingford Area Plan. No other alternative option was considered as this is an asset condition based
replacement.
6.4.1.4
New Rose Bay 132/11kV zone substation.
Previous TAPRs identified that the existing Rose Bay 33/11kV ZS equipment and feeders (distribution assets)
are approaching the end of their service life and that there is an emerging winter load constraint in the Rose
Bay area.
Options considered include:
1.
New 132/11kV Rose Bay zone substation
2.
33kV supply retained for Rose Bay ZS - This option involves the construction of a new substation with
three 33MVA transformers and supplied by dedicated 33kV feeders from Surry Hills STS. Under this
option it is also proposed that Surry Hills ZS be converted to 132kV supply as this driven by loading on
132kV cables to Surry Hills STS.
The preferred option to address these issues was to replace the existing Rose Bay ZS with a new 132/11kV
zone substation. The substation will be connected to new 132kV feeders to be developed from the vicinity of
the Sydney CBD. A consultation process was carried out in accordance with clause 5.6.6 of the NER. As the
total augmentation component of the projects was under $20M, publication of an Application Notice was not
required. A Final Report (Rose Bay 132kV Conversion and Installation of 132kV Feeders) was published in
December 2009.
Since the project was driven by replacement of aged assets, rather than demand growth, non-network options
were not considered.
The preferred and committed project is option 1 - New Rose Bay 132/11kV ZN. This is a dual function asset,
also described in the TAPR section 12.8.1.6.
Distribution and Transmission Annual Planning Report December 2013
167
6.4.1.5
New Waverley 132/11kV zone substation
The existing Waverley 33/11kV ZS (a distribution asset established in 1929) 11kV switchgear needs
replacement and that the 33kV supply feeders from Surry Hills STS (390, 391 and 396) are approaching the
end of their service life. It was also identified that the most likely option to address these asset condition
issues is to replace the existing Waverley 33/11kV ZS with a new 132/11kV substation, connected by looping
into one of the new committed 132kV feeders from the Sydney CBD area supplying the new Rose Bay
132/11kV ZS.
Since the project was driven by the replacement of aged assets, rather than demand growth, non-network
options were not considered. Options considered include:
1.
New 132/11kV Waverley zone substation
2.
33kV supply retained for Waverley ZS. This option involves the construction of a new substation with 4 x
33MVA transformers and supplied by dedicated 33kV feeders from Surry Hills STS. Under this option it
is also proposed that Surry Hills ZS be converted to 132kV supply as this driven by loading on 132kV
cables to Surry Hills STS.
The preferred and committed project is option 1 - New 132/11kV Waverley zone substation. This is a dual
function asset, also described in the TAPR section 12.8.1.5.
6.4.1.6
Camperdown 33kV Feeder Replacement
The 33kV feeder 638 from Canterbury STS to Camperdown zone is at the end of its serviceable life and has
been prioritised for replacement. The 33kV feeders 333, 334, 351 and 462 from Bunnerong STS to
Camperdown zone are at the end of their serviceable lives and have been prioritised for replacement in the
period 2017-2027 (Ref15).
Since the project was driven by the replacement of aged assets, rather than demand growth, non-network
options were not considered. Options considered include:
1.
Replace Camperdown 33kV feeders with new feeders from Pyrmont
2.
Camperdown to Leichhardt 11kV load transfer - This option involves transferring around 25MVA of 11kV
load from Camperdown to Leichhardt zone (Inner West Area Plan). An additional 50MVA, 132/11kV
transformer and associated 11kV switchgear would be required at Leichhardt zone by Summer 2015/16.
The preferred least cost and committed option is option 1 to replace 33kV feeders at Camperdown with new
feeders from Pyrmont.
6.4.1.7
Refurbishment of Gosford STS
Condition of the assets requires the replacement of steel structures supporting the busbar, swichgear and
instrument transformers at Gosford STS. Options investigated: include:
1.
Refurbishment of Gosford STS
2.
Retirement of Gosford STS - This option involves retirement of Gosford STS. To do this, suitable
alternate supplies to Avoca, Erina, Umina and Woy Woy zones are required by either converting these
zones to 132/11kV operation or building a new STS. However, this option involves complex works and
staging issues and will not be cost effective. (Hence, this option is not a viable solution)
3.
Demand Management - this option is not viable as the issues at Gosford STS are driven by condition
and not capacity.
Based on the cost and the need addressed, the preferred and committed option is Option 1 – Refurbishment
of Gosford STS.
6.4.1.8
Peats Ridge 33kV and 11kV switchgear replacement
The 11kV outdoor switchgear at Peats Ridge zone substation has been prioritised for replacement. The 33kV
circuit breakers at Peats Ridge zone substation are of bulk oil type and are at the end of their lives. They are
recommended for replacement in 2015. Options investigated included:
1. Peats Ridge 33kV and 11kV Switchgear replacement
2. Retire Peats Ridge ZS - This option involves transferring all the existing 11kV loads from Peats Ridge to
Somersby zone substation and ultimately decommissioning the existing Peats Ridge 33/11kV zone
substation
3. Demand Management - This option is not viable as the issues at Peats Ridge zone substation are driven
by condition and not capacity.
The preferred and committed option is Option 1 – Peats Ridge 33kV and 11kV Switchgear replacement.
Distribution and Transmission Annual Planning Report December 2013
168
6.4.1.9
Metford zone substation (East Maitland ZS replacement)
East Maitland ZS was constructed in 1966. It is equipped with an outdoor 33kV switchyard and an indoor 11
kV busbar. Aged 33kV assets at East Maitland ZS have limited remaining useful life. The 11kV switchgear at
East Maitland ZS also has limited useful life, and its design compromises high voltage clearances during any
work and/or testing within the switchgear.
Options considered include:
1.
Metford 132/11kV ZS. The new ZS will increase the licence capacity of the substation. This solves the
asset condition, and 33kV loading issues at East Maitland ZS. (A future 33kV feeder connection from
Maitland ZS to feeder 30025 will support the 33kV network supplying Maitland ZS)
2.
Metford 33/11kV ZS
3.
Demand management.
Non-network option investigation concluded that it was not viable for demand management to postpone the
preferred network option. Building the preferred Option 2 -a new Metford ZS at 33/11kV is the most cost
effective option in meeting the network needs and is the committed project.
6.4.1.10 Newcastle CBD ZN 33kV feeders replacement
The 33kV outdoor oil circuit breakers have limited remaining useful life and are recommended for replacement
in 2014. The 11kV Air Insulated Switchboard has barrier board issues and is recommended for replacement in
2012. .Options considered include:
1.
Fourth 33kV feeder and fourth zone transformer - This option resolves the capacity constraint on feeder
770 and the substation by the addition of a fourth 33kV feeder and fourth zone transformer. This will
allow for the reduction of zone substation load current on feeder 770
2.
11kV LT from Newcastle CBD to Adamstown 132kV ZS - This option resolves the capacity constraint on
the substation by the transfer of 11kV load from Newcastle CBD ZS to Adamstown 132/11kV ZS
3.
Demand management. As the capacity constraint does not arise until Summer 2020/21, this process has
not been initiated.
Based on the cost and the needs addressed, the preferred and committed option is a combination of
Newcastle CBD busbar and fourth feeder and 11kV LT to Adamstown ZS.
6.4.1.11 New Lambton 11kV switchgear Replacement
New Lambton 11kV SG replacement was common to all strategies considered for Newcastle Inner City Area
Plan. No alternative options for considered as this is a condition driven project.
6.4.1.12 New Tighes Hill zone substation
The existing Carrington Zone Substation (ZS) supplies the industrial area associated with the port facilities of
Newcastle. The zone was established in 1967 and its 33kV indoor switchgear and 11kV indoor switchgear are
nearing the end of their service lives. This project addresses asset issues at Carrington ZS by constructing a
new zone substation on a new site at Tighes Hill. The options considered include:
1.
a new Tighes Hill 33/11kV ZS
2.
Build a new 33/11kV ZS proposed on a site provided by the Buildev Intertrade Consortium. Initially this
would be a two transformer substation with the ability to expand to a three transformer substation. This
option however requires extensive 33kV feeder works to extend feeders 763 and 769 to the Buildev site
This project is driven by asset condition rather than demand growth. On this basis, no investigation of potential
demand management options has been undertaken. The preferred and committed option to construct a new
Tighes 33/11kV ZS is the least cost option that addresses the identified network need.
6.4.1.13 Mayfield to Carrington 33kV feeder replacement
The oil-filled cable section in Feeder 3022 between Mayfield and Carrington is reaching the end of its service
live. The condition of the cable is such that from a risk management point of view it should be replaced before
2015. This cable is required to supply the 33kV Tubemakers customer substation which is owned and
maintained by Ausgrid solely for supply to OneSteel. There is no 11kV connection to Ausgrid's 11kV
distribution network from this substation. The substation is significantly aged and has various condition and
Duty of Care issues which need to be addressed. Options considered include:
1.
Replace 33kV oil filled cable. The oil filled cable out of Mayfield ZS is approximately 2.7km in length. This
option will not allow for the decommissioning of the existing Tubemakers 33/11kV substation, resulting in
ongoing maintenance requirements
2.
Transfer Tubemakers supply to 11kV.
Distribution and Transmission Annual Planning Report December 2013
169
Option 2 - a project to build a new 11kV connection from Mayfield West to Tubemakers is committed and
under construction. Completion of this project will allow for the 33kV connection to be decommissioned,
including the oil-filled cable section on Feeder 3022. Since this is an asset condition issue non-network
options were not considered viable.
6.4.1.14 11kV transportable switchroom at Pelican ZS
Pelican zone was constructed in 1956. The following asset condition issues are present at Pelican zone
substation and need to be addressed within this regulatory period:

The 11kV switchgear is approaching the end if its service life and is recommended for replacement

The 11kV switchroom building is subsiding, and

The 33kV circuit breakers are of the outdoor bulk oil type and are recommended for replacement
Options considered include:
1. 11kV transportable switchroom at Pelican
2. Refurbish Pelican ZS - Install a new switchroom to replace the 11kV switchgear. The substation site is
constrained and does not have any spare land to allow for the construction of a new switchroom
3. Retire Pelican ZS - Transfer load at Pelican ZS to Jewells and Croudace bay ZS. This would create an
immediate capacity constraint at Jewells ZS, requiring a project to increase the capacity at Jewells ZS.
There is adequate capacity at Croudace Bay ZS. This option would require extensive 11kV augmentation
works due to the terrain and geography in the immediate area. Minor works to reconfigure the 33kV
network would also be required
4. Build a replacement substation in the adjacent suburb of Belmont north of Pelican.
The preferred Option 1 - 11kV transportable switchroom at Pelican is the most cost effective option in meeting
the network needs and is the committed project.
6.4.1.15 Nelson Bay ZN 11kV switchgear replacement
The condition of the 11kV switchgear at Nelson Bay zone is such that from a risk management point of view
the optimal time to replace the switchgear is in the period 2012-14. The condition of the 33kV circuit breakers
at Nelson Bay zone is such that from a risk management point of view the optimal time to replace the breakers
is in 2013. Options considered include:
1.
Retirement of Nelson Bay ZS - This option resolves the 11kV asset condition issue by retiring Nelson
Bay ZS and transferring loads to Tomaree ZS. This option will introduce capacity a constraint at
Tomaree
2.
New Nelson Bay ZS - This option involves the construction of a new 33/11kV ZS adjacent to the existing
substation.
The preferred and committed option to replace the 11kV switchgear at Nelson Bay ZS is the least cost option
that addresses the identified need.
6.4.1.16 Newdell ZN 11kV switchgear replacement
The Newdell ZN 11kV SG replacement is a replacement project common to all strategies considered in the
Singleton Area Plan. There are no viable non-network alternatives for this project.
6.4.1.17 Muswellbrook 33/11kV ZN replacement - Upgrade to 132/11kV
Muswellbrook 33/11kV ZS upgrade to 132/11kV. Options considered include:
1.
Muswellbrook 33/11kV ZS upgrade to 132/11kV
2.
Muswellbrook 66/11kV ZS - A new 66/11kV ZS is constructed in Muswellbrook to replace the existing
Muswellbrook 33/11kV ZS and allow for the retirement of Muswellbrook STS. The impact of spot loads at
Mitchell Line STS will advance the timing for the installation of a third transformer.
The preferred option of a 132/11kV ZS had a very similar net present cost to the 66/11kV ZS option. However,
the decision to construct a new 132/11kV ZS has advantages with respect to possible future developments in
the area and this is the committed option.
6.4.1.18 132kV feeder 91L and 91M replacement
The existing 132kV feeders 91L and 91M/1 (Peakhurst STS to Bunnerong STS and Beaconsfield BSP
respectively) and 91M/3 (from Beaconsfield BSP to Bunnerong STS) comprise of oil-filled cables
commissioned in the early 1970’s.
Distribution and Transmission Annual Planning Report December 2013
170
These cables are at the end of their service life and have been prioritised for replacement. They incur
significant maintenance costs as they require extended repair times and specialist cable jointing. In
addition, failure of the cables can lead to oil leaks with the potential for environmental damage.
Ausgrid is to replace 91L and 91M/1 with XLPE cable. A Final Report (Replacement of 132kV Feeders
91L and 91M Peakhurst to Bunnerong and Beaconsfield) was issued in May 2010. This is a committed
dual function project and the works are planned to be completed by November 2013. Refer to TAPR
section 12.8.1.4.
6.4.1.19 New Croydon 132/11kV zone substation
The existing Five Dock 33/11kV zone substation equipment and associated 33kV feeders (distribution
assets) are approaching the end of their service life. A combined Application Notice (Replacement of
Feeder 900, Leichhardt and Five Dock Zones) was published in December 2008 outlining the issues and a
preliminary application of the regulatory test. Both 132/11kV zone substations have been approved
internally. A Final Report was issued on 10 September 2010.
The options considered include:
1.
New Croydon 132/11kV zone substation to decommission existing Five Dock 33/11kV zone
2.
Retain 33kV in the Easter Inner West load area - This option involves a like for like replacement of feeder
900 from Mason Park STSS to Rozelle STS. At the same time Rozelle STS would be uprated and new
33kV feeders would be installed from Rozelle STS to Leichhardt ZS to retire the existing 33kV feeders to
Leichhardt. A new 33/11kV Croydon ZS would be constructed with new 33kV feeders from Homebush
STS to replace Five Dock ZS.
No non-network alternatives were considered viable alternatives to this project.
The preferred and committed option is to convert the eastern Inner West load area to 132kV, including the
installation of new 132/11kV Croydon ZS. This project was reported in previous TAPRs as a dual function
asset, is now considered as distribution. Following Ausgrid’s annual review of the operational status of dual
function assets of this project is now considered as distribution.
6.4.1.20 132kV feeder 900 Rozelle STS to Mason Park STSS 132kV replacement
The need to replace feeder 900 in addition to replacing the existing Leichhardt and Five Dock 33/11kV
zone substations is driven by three needs:

The existing 132kV feeder 900 is an underground oil-filled cable that connects Mason Park STSS to
Rozelle STS and was installed in 1962. The cable is approximately 11km in length and is close to the
end of its economic life. In addition, the conductor size is inadequate for present system fault levels

The existing Leichhardt 33/11kV zone substation equipment and associated 33kV feeders (distribution
assets) are approaching the end of their service life

The existing Five Dock 33/11kV zone substation equipment and associated 33kV feeders (distribution
assets) are approaching the end of their service life.
A combined Application Notice (Replacement of Feeder 900, Leichhardt and Five Dock Zones) was published
in December 2008 outlining the issues and a preliminary application of the regulatory test. Both 132/11kV
zone substations have been approved internally. A Final Report was issued on 10 September 2010. No nonnetwork alternatives were considered viable alternatives to this project.
Ausgrid’s preferred option is the replacement of feeder 900 along a revised route and the replacement of
Leichhardt and Five Dock zones with new 132/11kV substations. Both the new Leichhardt and Five Dock (the
new Five Dock zone is to be renamed Croydon ZS) will be looped into the new replacement 132kV feeder
900. Feeder 900 Mason Park STSS to Rozelle and the conversions of Leichhardt 33/11kV ZS and Five Dock
33/11kV ZS to 132/11kV are committed projects. These projects are no longer considered as dual function
following an annual review of the status of dual function assets by Ausgrid.
Distribution and Transmission Annual Planning Report December 2013
171
6.4.1.21 Lindfield STSS to Castle Cove 132kV feeders 925/3 and 9E4/3 replacement
The 132kV feeder 9E4/3 and Feeder 925/3 are approaching the end of their service life and require
replacement in the 2009-14 regulatory period due to asset condition issues.
The Lindfield STSS to Castle Cove 132 kV cables replacement is a common requirement across all proposed
strategies in the Lower North Shore Area Plan. No non-network alternatives were considered viable
alternatives to this project.
6.4.1.22 Crows Nest ZN conversion to 132/11kV
The four aged 33kV underground gas pressure feeders supplying Crows Nest are in need of replacement.
The options considered for the refurbishment of Crows Nest zone substation include:
1.
Refurbish Crows Nest and retain 33/11kV supply voltage with new 33kV feeders and new 33kV
switchgear
2.
Convert Crows Nest to 132/11kV supply voltage with new 132kV feeders and new 132kV switchgear.
The preferred and committed option is to establish a new 132/11kV Crows Nest zone substation and retire the
existing 33/11kV zone substation. Non non-network options were considered viable to this asset condition
driven replacement project.
6.4.1.23 New North Sydney 132/11kV zone substation
North Sydney 33/11kV ZS was commissioned in 1968 and the majority of the 11kV switchgear and the 33kV
incoming gas pressure cables require replacement within 10 years. The timing of the replacement is driven by
the risks associated with aging substation equipment and cables and the limited interconnection, in addition to
the need to improve reliability of supply to the North Sydney high rise commercial area.
Options considered include:
1.
North Sydney 33/11kV zone substation. A new 33/11kV zone is constructed in North Sydney to replace
the existing North Sydney ZS. This project addresses the asset condition issues at North Sydney ZS. A
new 132/11 kV ZS would also be constructed to address forecast load constraints at Willoughby STS in
2023-24
2.
North Sydney 132/11kV zone substation. A new 132/11kV ZS constructed in North Sydney to replace the
North Sydney ZS. The new zone substation will result in a net increased licence capacity. This project
addresses the asset condition issues at North Sydney ZS and will not add load to Willoughby STS.
The preferred and committed option is Option 2 - North Sydney 132/11kV zone substation based on least net
present cost. It also requires significantly less overall expenditure than Option 1. Non non-network options
were considered viable to this asset condition driven replacement project.
6.4.1.24 Manly zone substation 33kV switchgear replacement
11kV oil-filled circuit breakers have been prioritised for replacement with vacuum circuit breaker trucks in the
period 2014–16. The 33kV indoor bulk oil circuit breakers need to be replaced within the next five years. There
is a committed project to replace 33kV bulk oil circuit breakers at Manly ZS with anticipated completion in
2013.
Options considered include:
1.
Replacement of 33kV switchgear at Manly ZS. This option involves replacing the aged 33kV switchgear
at Manly ZS
2.
Development of Kangaroo Point Switching Station. This option involves the establishment of a switching
station with a 33kV busbar in the vicinity of Kangaroo Park. The transformers at Manly ZS would be tailended enabling the retirement of the existing 33kV.
Option 1 – replacement of 33kV switchgear at Manly ZS it the least cost and committed option. Non-network
options were not considered viable for a asset condition driven replacement project.
6.4.1.25 Engadine 132/11kV ZN & feeder 912/284 reconfiguration
Engadine 33/11kV Zone substation was commissioned in 1964. A significant portion of the substation
equipment is approaching the end of its service life and requires replacement. The 11kV switchgear at
Engadine zone substation is prioritised for replacement between 2012 and 2014; and three 33kV circuit
breakers are of the bulk oil type and are at the end of service life and require replacement in the short term.
Distribution and Transmission Annual Planning Report December 2013
172
Options considered include:
1.
Convert Engadine zone substation to 132/11kV operation
2.
Refurbish existing Engadine zone substation at 33/11kV.
Option 1 – Convert Engadine zone substation to 132/11kV operation is the preferred and committed option.
This option includes conversion of the existing Engadine 33/11kV zone substation to 132/11kV operation,
feeder connection works and reconfiguration of the associated 33kV and 132kV feeder networks. A Final
Report Development of Engadine Zone Substation was issued in January, 2010.
6.4.1.26 Jannali ZN 11kV switchgear replacement
The 11kV switchgear and bulk oil 33kV circuit breakers at Jannali 33/11kV ZS are approaching the end of their
service life and have been prioritised for replacement. In addition. the 33kV busbar height does not comply
with clearance standards.
There are no viable strategic alternatives to the Jannali 11kV switchgear replacement.
Non-network options were not considered viable as the works are driven by the asset condition of the 11kV
and 33kV switchgear, and the non-compliant 33kV busbar height which is a duty of care issue.
6.4.1.27 New Kurnell 132/11kV zone substation
The 11kV switchgear at Kurnell 33/11kV Zone substation is approaching the end of its service life and is
prioritised for replacement. The 6.3kV switchgear is also at the end of its service life and no spares are
available.
Options considered include:
1.
Develop new Kurnell 132/11kV zone substation and decommission existing Kurnell 33/11kV zone
2.
Refurbish existing Kurnell zone substation at 33/11kV.
Ausgrid’s preferred and committed option is Option 1 – Develop new Kurnell 132/11kV zone substation and
decommission existing Kurnell 33/11kV zone.
The works are driven by asset condition at the existing Kurnell ZS. A Final Report detailing the outcome of the
Regulatory Test and the the preferred option was published in December, 2010. The conclusion of the Final
Report was that demand reductions would not enable a lower cost solution to this network need, either
through deferral or installation of a smaller capacity zone substation.
6.4.1.28 Port Hacking STS 132kV busbar replacement
Port Hacking STS outdoor 132kV steel busbars are at the end of their service lives due to extensive corrosion
and require replacement. The 33kV circuit breakers are of the bulk oil type and are at the end of their service
lives and have been prioritised for replacement. Also, the height of the existing outdoor 33kV busbar at Port
Hacking STS is no longer compliant with current standards and is a duty of care issue.
There are no viable strategic alternatives to the Port Hacking STS 132kV busbar replacement.
Non-network options were not considered viable as the works are driven by the asset condition, and the noncompliant 33kV busbar height which is a duty of care issue.
6.4.1.29 New Eastern CBD 132kV cable tunnel
It is necessary to construct a 132kV cable tunnel from the Riley Street, Surry Hills site to the proposed Bligh St
and recently completed City North Zone Substations (ZS) to accommodate new feeders for supply to these
zones and nearby 33kV zones.
Options considered include:
1.
Construct a duct line. This option involves excavating from Riley Street to the new City East, Dalley
Street and City North ZS. This would require the construction of three duct lines from Riley St to
New City East and two duct lines from the new City East to Dalley St and City North. Under this
option a separate 33kV duct line would also be required from Surry Hills STS to Graving Dock ZS
2.
Construct an Eastern CBD 132kV cable tunnel. This option involves constructing a tunnel from Riley
Street to City North ZS using a tunnel boring machine and the construction of a stub tunnel from the
new City East site to the main tunnel, as well as a cable riser at Dalley St ZS. Under this option the
33kV feeders could be replaced via the tunnel to a riser at Woolloomooloo, then excavation to
Graving Dock Zone. A separate economic analysis has been undertaken on this and it is considered
appropriate that the Graving dock feeders should also be installed in the tunnel.
Distribution and Transmission Annual Planning Report December 2013
173
The preferred and committed option is Option 2 - Construct an Eastern CBD 132kV cable tunnel based on
least cost. This option is consistent with Ausgrid’s preferred strategy specified in the Sydney CBD Area Plan.
Non-network options were not considered viable as this project is driven by asset replacement needs does not
add capacity.
6.4.1.30 Kuringai STS 33kV switchgear replacement
The 33kV switchgear replacement at Kuringai STS is driven by non-compliance of the 33kV bus bar with
current clearance requirements. as well as the poor condition of the bulk-oil circuit breakers which have
reached the end of their service lives and are scheduled for replacement in 2014/2015.
No alternative options were considered as the asset replacement is driven by the condition of the bulk oil
circuit breakers, and the 33kV busbar clearance duty of care issue. Non-network options were not considered
viable as this project is driven by asset replacement and duty of care needs.
6.4.1.31 Lindfield zone substation 33kV feeder and 11kV switchgear replacement
Lindfield ZS was commissioned in 1961. The 11kV oil filled switchgear at Lindfield zone substation is
approaching the end of its service life and has been prioritised for total replacement. Two out of the three
33kV cables from Kuringai STS to Lindfield zone substation are also approaching the end of their service life.
The 33kV feeders 534 and 535 need to be replaced before 2011, while feeder 536 needs to be replaced
before 2021. Replacement of feeder 536 has been advanced from 2021 to 2012 to provide additional capacity
at Lindfield zone substation.
Options considered include:
1.
Replacement of 33kV feeders supplying Lindfield Zone substation, and
2.
Conversion of Lindfield to 132/11kV operation.
This committed replacement project is consistent with Ausgrid’s preferred strategy for the Upper North Shore
Area Plan. As this replacement project addresses asset condition needs and involves an expected
augmentation component of less than $1 million, investigation of demand management alternatives was not
considered viable. A Final Report – Replacement of 33kV Feeders to Lindfield Zone Substation was published
in March, 2010.
6.4.1.32 St Ives 33kV feeder and high voltage current transformers replacement
Kuringai STS to St. Ives Feeders 540 and 542 need to be replaced before 2017 and feeder 541 needs to be
replaced before 2022. However, to address capacity constraint at St Ives, the feeder replacement was
advanced to 2013. The 11 kV oil filled circuit breakers have also been prioritised for replacement with vacuum
circuit breakers.
Options considered include:
1.
Replace aged 33kV feeders 540, 541 and 542
2.
Replace aged 33kV feeders 540, 541 and 542 feeders and 33kV HV current transformers and install a
fourth 33kV feeder in 2013.
Option 2 - Replace aged 33kV feeders 540, 541 and 542 feeders and 33kV HV current transformers and
install a fourth 33kV feeder in 2013 was the preferred and committed option. As this replacement project
addresses asset condition needs and involves an expected augmentation component of less than $1 million,
demand management alternatives were not considered viable.
6.4.1.33 Turramurra zone substation 11kV switchgear replacement
Turramurra Zone Substation was commissioned in 1963. The 11kV switchgear at Turramurra is approaching
the end of its service life and is prioritised for replacement between 2017 and 2019 based purely upon its
condition. The firm capacity at Turramurra zone substation is limited by the 11kV switchgear and is not
sufficient to support a required load transfer of approximately 7MVA from St Ives. Additionally, there are
presently no spare or double bankable 11kV panels at Turramurra to accommodate this transfer.
The preferred and committed option is to replace the 11kV switchboard. As this is a replacement project with
the augmentation component of the expenditure less than $1 million demand management options were not
considered viable.
6.4.1.34 Lindfield to Willoughby 132kV feeders 9E3(2) and 9E4/2 replacement
The 132kV cables 9E3 and 9E4/2 from Lindfield STSS to Willoughby STS are aged and approaching the end
of their service life. These oil-filled cables are approximately 9 km in length and currently supply transformer
No.1 and transformer No.3 in Willoughby STS at 132kV. It is proposed to replace the existing 132kV feeders
between Lindfield STSS and Willoughby to address asset condition issues. The 132kV feeder 9E4/2 requires
replacement in the period 2009-2014. Feeder 9E3 requires replacement in the period 2014-19.
Distribution and Transmission Annual Planning Report December 2013
174
No alternative options were considered as the replacement of 132kV feeders 9E3 and 9E4/2 is common
across all strategies in the Upper North Shore Area Plan. Since this was a replacement driven project no
demand management options were not viable.
6.4.1.35 New Toronto 132/11kV zone substation
Toronto zone substation was constructed in 1961. It comprises an outdoor 33kV switchyard and an indoor 11
kV busbar. The majority of equipment is approaching the end of its service life. The 33kV circuit breakers are
of the outdoor bulk oil type, and are recommended for replacement. The indoor 11 kV switchgear for is also
due for replacement.
Options considered are:
1.
Toronto 33/11kV zone substation. A new 33/11kV zone is constructed in Toronto to replace the existing
Toronto ZS. The new zone will result in a net increased licence capacity. This project addresses the
asset condition issues at Toronto zone
2.
Toronto 132/11kV zone substation. A new 132/11kV Zone is constructed in Toronto to replace the
existing Toronto ZS. The new zone will result in a net increased licence capacity. This project addresses
the asset condition issues at Toronto zone.
The preferred and committed option is Option 2 - Toronto 132/11kV zone substation.
The project is driven by the need to replace the assets at Toronto Zone Substation due to their deteriorated
condition. A change in the level of demand would not alter the timing of the required investment. On this basis
there is no prospect of a lower cost option being enabled by demand management strategies, demand
management was not considered viable.
6.4.2
Urgent and unforseen investments
There were no distribution network Regulatory Test projects required to address an urgent or unforeseen
network investment in the preceding year.
Distribution and Transmission Annual Planning Report December 2013
175
7
Joint Planning
7.1
Joint Planning with TransGrid TNSP
Joint Planning is carried out with other Network Service providers, in particular TransGrid, Endeavour
Energy and Essential Energy.
Ausgrid plans its transmission network jointly with TransGrid as the Ausgrid 132kV dual function network
provides support to TransGrid’s 330kV network. In carrying out joint planning TransGrid and Ausgrid:

meet regularly, at least 4 times per year

record minutes and decisions

prepare workplans and monitor progress

assess augmentation options on the basis of least cost to the community

initiate projects within each organisation following the normal approval processes, and

jointly consider demand management as an option.
Ausgrid and TransGrid have established a Joint Planning Committee structure which comprises a steering
committee and a customer sub-committee to coordinate the planning activities of Ausgrid and TransGrid in
accordance with the joint planning requirements of the National Electricity Rules. Under the agreed terms of
reference, there are quarterly meetings of the sub-committee and bi-annual steering committee meetings.
Members include relevant planning, operations and project development staff. The key considerations of the
joint planning committees are:

load forecasting

connection agreement issues, including major new connections

reliability criteria

major plant refurbishment

plant retirement issues

demand management and embedded generation opportunities

network augmentation options

reactive plant requirements

system fault levels

earthing coordination

major network control coordination

overview of protection, metering and communication issues, and

network business communication requirements.
Committee activities and deliverables are managed through an agreed work plan, with decisions documented
in Memorandums of Understanding (MOUs) and approved Joint Planning Reports for major milestones.
MOU and Joint Planning Report sign-offs range from Planning Manager level (Ausgrid L5) for more routine
agreements up to Chief Executive Officer/Chief Operating Officer level. The more routine operational
decisions and actions required are agreed on and recorded via the joint planning meeting minutes.
7.1.1
Process and Methodology
Ausgrid plans the Inner Sydney Metropolitan, Central Coast and Lower Hunter Transmission Load areas
jointly with TransGrid.
The joint reliability standard for the Inner Sydney Metropolitan transmission system, as agreed in a
Memorandum of Understanding between TransGrid and Ausgrid, is that the system will be capable of
supplying peak load under the following contingencies:

A coincident outage of TransGrid’s 330kV cable 41 or 330kV cable 42 and any 132kV feeder or
330/132kV transformer, and
Distribution and Transmission Annual Planning Report December 2013
176

An outage of any section of 132kV busbar.
The NER sets out the planning process and consultation requirements and includes requirements on
forecasting, annual reviews, regulatory tests and consultations. The main inputs to the joint planning process
are:
7.1.2

Ausgrid supply point load forecasts

Review of network capacity and utilisation

Planning criteria and indicators

Condition, operational and risk assessments

TransGrid transmission network and Ausgrid supporting dual function network loadflow analysis, and

TransGrid – Ausgrid network planning reviews.
Joint TransGrid - Ausgrid planning completed in 2013
Sydney Metropolitan
Joint planning is underway with TransGrid to address reliability and asset condition issues, and maintain
transmission capacity in the Sydney Metropolitan area. TransGrid have installed new GIS switchgear at
Beaconsfield Bulk Supply Point and Ausgrid’s 132kV feeders are currently being transferred to the new
switchgear, with the transfers due to be completed by 2016. A new Bulk Supply Point at Rookwood Road is
currently under construction to increase transmission capacity and better utilise existing 132kV network
assets, and is scheduled for completion in December 2013. Due to thermal rating issues identified with
TransGrid circuit 41 and some Ausgrid 132kV feeders, a number of aged and poor condition 132kV circuits
will be maintained longer than anticipated until reconfiguration work on circuit 41 can be completed. Ausgrid is
currently constructing replacement circuits from Kogarah to Beaconsfield BSP and Canterbury for several
aged 132kV cables to improve 132kV network reliability and capacity. The first steps in relieving supply
constraints and replacing cables from Lane Cove to Dalley St has been completed with two new circuits from
Beaconsfield to Green Square and from Beaconsfield and Haymarket. An additional circuit from Beaconsfield
to the CBD is anticipated in 2015 as a result of issues identified with two older existing cables from
Beaconsfield to Surry Hills.
Central Coast
To meet the forecasted increasing demand in the Gosford/Ourimbah area, options being considered include
installation of additional 132kV feeders between Berkeley Vale and Ourimbah, and Wamberal and Gosford.
Hunter
Joint planning with TransGrid has resulted in the development of a new 132/11kV zone substation at Brandy
Hill to be commissioned in 2013 utilising new TransGrid 132kV circuits between Tomago BSP and Scone.
7.1.3
Planned Joint Transgrid-Ausgrid Network Investments
Planned future network investments, excluding committed projects, discussed at TransGrid - Ausgrid joint
planning meetings in the preceding year include:

Demand Management requirements for summer 2013/14. Analysis and agreement on system
requirements for the upcoming 2013/14 summer

Rating constraints on feeder 9SA and 9SB/1. Joint planning discussion was conducted on the
establishment of a new 132kV feeder 90Y from Beaconsfield BSP to Belmore Park ZS. Studies are
underway to confirm the feasibility of installing Ausgrid's new feeder in TransGrid’s Sydney Park to
Haymarket tunnel. Investigations on-going. The identified project need date is Sept 2015

Decommissioning of the 330/33kV transformers at Munmorah Power Station by Delta Energy.
Establishment of Doyalson STS - due to the proposed decommissioning of 330/33kV transformers at
Munmorah P.S by Delta Energy. Joint Ausgrid – TransGrid investigations into the establishment of
Doyalson STS and the sharing of easements outside Munmorah BSP to supply local 33kV zone
substations. The identified need date is September 2015

Replacement of the current transformers at Sydney East BSP on feeders 9E3/1 and 9E5/1. The identified
need date is September 2015

New Alexandria STS requirements for switchbay connections at Beaconsfield BSP. The identified need
date for this project is March 2016
Distribution and Transmission Annual Planning Report December 2013
177




7.1.4
De-rating of TransGrid 330kV feeder 41. To mitigate against the de-rating of feeder 41, TransGrid
proposes to reconfigure the 330kV series reactors at Sydney South. The identified need date is
September 2016
Strathfield South 132/11kV ZS (formerly referred to as Enfield 132/11kV ZS). Requirements were
identified for network protection changes at Sydney South BSP for the connection of Strathfield South
ZS. Identified need date is September 2016
Looping of Ausgrid feeder 957 at Tuggerah BSP. The availability of feeder bays and terminations at
Tuggerah BSP discussed. The identified need date is 2017/18
Establishment of a new 330kV supply to the CBD. Discussions covered option analysis, identified needs
reviews and on-going feasibility studies. The identified need date is September 2018.
Additional information
Further information on TransGrid and Ausgrid’s completed joint planning and joint network investment can be
found in:

TransGrid’s Transmission Annual Planning Report, and

Ausgrid’s Distribution and Transmission Annual Planning Report.
These are published on our respective websites, as well as AEMO’s website.
7.2
Joint planning with other DNSPs
Ausgrid follows the same principles when joint planning with Endeavour Energy and Essential Energy.
However due to the limited number of network dependencies between the organisations, joint planning
meetings may only take place once per year unless a particular issue has been identified and needs to be
progressed and monitored.
7.2.1
Process & Methodology
Joint planning meetings with Endeavour Energy and Essential Energy are arranged on a needs basis, and
generally there are not more than two meetings in any year. The joint planning process and methodology
is similar to the joint planning process between Ausgrid and TransGrid.
Joint planning meetings may be initiated by any party to discuss planning issues, identified network needs
and proposed solutions near adjoining network boundaries that are likely to affect either party. The joint
planning meetings are also the forum used to discuss proposed changes on the network that may have a
material impact on either DNSPs network.
7.2.2
Joint Ausgrid and other DNSP planning completed in preceding year
No joint planning has been undertaken with Essential Energy this year. There are no identified network issues
that affect any Essential Energy customers that are supplied from Ausgrid's network. Essential Energy has not
proposed any changes to their network that could impact the planning of Ausgrid's network that supplies
Essential Energy.
An annual request for Essential Energy's forecast demand for substations supplied by Ausgrid's network was
made by email and the forecast information received in accordance with NER requirements. This forecast is
used to confirm the forecast demand for the upstream Ausgrid network.
No joint planning has been undertaken with Endeavour Energy in the preceding year. There are no identified
network issues that affect either Endeavour Energy or Ausgrid.
7.2.3
Planned DNSP Joint Network Investments
There were no jointly planned network investments with either Endeavour Energy or Essential Energy in the
preceding year.
7.2.4
Additional information
Information on completed Ausgrid and other DNSP joint planning and joint network investments may be found
in future Ausgrid Distribution and Transmission Annual Planning Reports published on website. Where a
proposed future DNSP joint planning project satisfies the requirements for a RIT-D project, the identification of
non-network options, the consultation on potential credible options and their economic assessment will be
published in accordance with the NER.
Distribution and Transmission Annual Planning Report December 2013
178
8
Network Performance
8.1
Reliability measures and standards
Ausgrid’s objective is to maintain the overall reliability of our electricity network, given the condition and
utilisation of existing network assets and the funding available to maintain and augment the electricity network.
In addition Ausgrid also aims to use all reasonable and practicable efforts to ensure that in any financial year,
it meets the targets set by the Minister for Resources and Energy in respect of reliability standards and
individual feeder standards set out in the Design, Reliability and Performance (DRP) licence conditions.
The purpose of the conditions is to facilitate the delivery of a safe and reliable supply of electricity. The
conditions impose design, reliability and performance standards on distribution network service providers.
Distribution network service providers are required to report to the Minister to ensure compliance with the DRP
licence conditions.
In stating the above objectives, Ausgrid excludes the following types of interruptions in the assessment and
reporting of network reliability outcomes:

momentary interruptions (interruptions of one minute or less)

interruptions occurring on major event days as defined in the DRP licence conditions

transmission system outages

load shedding due to insufficient generation to meet system load

automatic load shedding controlled by under frequency relays following
the occurrence of a power system under frequency condition

faults in a customer’s premises or equipment

compliance with directions from grid system operators or emergency
services or,

planned interruptions.
Our customers must plan around the possibility that the electricity supply may not be available at all times and
that interruptions could occur without notice, or with notice in accordance with their supply contract.
Two related indices are applied when reporting network reliability. SAIDI represents the average number of
customer minutes lost in a year, while SAIFI represents the average number of interruptions in a year.
The classification of Ausgrid’s approximately 2,100 high voltage distribution feeders into the categories CBD,
Urban, Short Rural and Long Rural is reviewed at the start of each annual reporting period. To cater for
augmentation work through the year new feeders are classified at the time of commissioning.
Reliability reporting uses the IEEE methodology for defining Major Event Days as outlined in the DRP licence
conditions. Ausgrid measures and records customers affected and the customer base on a daily basis.
Reliability performance indices are calculated on a daily basis rather than using the average of the number of
customers at the beginning and the end of the reporting period. The daily calculation method provides a more
representative customer performance at the time of the event. Ausgrid does not exclude inactive accounts.
There are natural time delays in updating customer account details into the real-time Outage Management
System, particularly where Ausgrid relies on information from electricity Retailers. Ausgrid considers the
recording of reliability performance for all active premises (whether the premise is vacant or not) to be a
practical administrative outcome. This action has little effect on reported reliability performance. The inclusion
of vacant premises increases both the customers affected (numerator) and the customer base (denominator)
of the Indices calculations.
In regard to the calculation for the Major Event Day Threshold (Tmed), the Design, Reliability and
Performance Licence Conditions Review Working Group agreed in March 2010 that the Tmed calculation
should be consistent with the Australian Energy Regulator (AER) Tmed calculation method. The DRP licence
conditions require that Planned Outages be included in the daily SAIDI dataset for calculation of the Tmed
value. The AER requires (STPIS definitions November 2009) that Planned Outages be excluded from the daily
SAIDI dataset for calculation of the Tmed value. Ausgrid has applied this change to the reliability performance
reporting to ensure consistency with the AER reliability performance reporting definitions.
Distribution and Transmission Annual Planning Report December 2013
179
8.1.1
Supply Reliability Standards
Average feeder category reliability standards
The purpose of the DRP licence condition Schedule 2- Reliability Standards is to:

define minimum average reliability performance, by feeder type, for a distribution network service provider
across its distribution network, and

provide a basis against which a distribution network service provider’s reliability performance can be
assessed.
Average reliability duration Standards
SAIDI (average minutes of supply interruption per
SAIFI (average number of network interruptions per
CBD
45
0.3
Urban
80
1.2
Short Rural Long Rural
300
700
3.2
6.0
Individual feeder standards
The purpose of the DRP licence condition Schedule 3 - Individual Feeder Standards is to:

specify minimum standards of reliability performance for individual feeders;

require a distribution network service provider to focus continually on improving the reliability of its
feeders, and

enable the reliability performance of feeders to be monitored over time.
Individual feeder Standards
CBD
Urban
SAIDI (average minutes of supply interruption per
customer)
100
350
1000
1400
SAIFI (average number of network interruptions per
customer)
1.4
4.0
8.0
10.0
8.1.2
Supply reliability in the preceding year
8.1.2.1
Performance of individual feeders against the Standard
Short Rural Long Rural
The 2012/13 performance for both SAIDI and SAIFI was the best result in the last 5 years and has been
trending downwards over this period. This year’s results can be attributed to the Regulatory Works Program
as well as favourable weather conditions.
There were two Major Event Days for 2012/13, firstly on 10 August, 2012 (6.03 SAIDI for the day) and
secondly on 23 February, 2013 (5.80 SAIDI for the day). Both events were predominantly due to strong wind
storms impacting the entire Ausgrid Network.
As required under the current Licence Conditions for Ausgrid, each feeder currently exceeding the Individual
Feeder Standard is analysed and an investigation report identifying the causes and, as appropriate, any action
required to improve the poor performance is reported in the next quarterly performance report. All actions
required were completed in the timeframes required.
Overall, the percentage of poor performing feeders in each feeder category is relatively low. Ausgrid has an
ongoing reliability management program in place. The program targets those feeders that have exceeded the
Individual Feeder Standards as outlined in Schedule 3 of the Design, Reliability and Performance Licence
Conditions.
Distribution and Transmission Annual Planning Report December 2013
180
Individual feeder performance against the Standard during 2012/13
CBD
Urban
55
1733
287
4
Feeders that exceed the Standard during the year
2
59
6
0
Feeders not immediately investigated
0
0
0
0
Feeders not subject to a completed investigation
report by the due date
0
0
0
0
Feeders not having identified operational actions
completed by the due date
0
0
0
0
Feeders not having project plan completed by the due
date
0
0
0
0
Feeders (Total Number)
8.1.2.2
Short Rural Long Rural
Performance of feeder categories against the Standard
All feeder category performances were compliant against the Reliability Standards for 2012/13. CBD
performance increased from previous years due to cable fault in pit in the CBD. Both Urban and Short
Rural feeders continued to improve. Long Rural was similar to the previous year. There are so few feeders
in this category that results can fluctuate dramatically year to year.
Performance of feeder categories against the Standard during 2012/13
8.1.3
System
CBD
Urban
Short Rural Long Rural
SAIDI (average minutes of supply
interruption per customer)
68.24
38.49
56.91
147.87
533.15
SAIFI (average number of network
interruptions per customer)
0.73
0.12
0.65
1.42
2.56
Service Target Performance Incentive Scheme (STPIS)
STPIS does not come into effect for NSW DNSPs until the commencement of the 2015-19 regulatory period.
During the current 2009-2014 regulatory period, NSW DNSPs are required to set up methodologies and to
perform a paper trial indicating the impacts of the STPIS as if it had been in effect.
8.1.4
Forecast of Network Reliability Performance
Ausgrid forecasts the reliability performance of each feeder category based on 5 years of historical
performance and considers the impact of the following:

The cumulative performance increase due to proposed investments

The cumulative performance reduction due to the general ageing of network assets and increase in
demand.
The net reliability gap is the difference between the management targets and the forecast SAIDI and
SAIFI metrics for each feeder category. Investments are initiated when the forecast performance of a
feeder category becomes worse than the relevant management target. Planning is based on a minimum
ten year investment horizon.
There are generally three methods for the improvement of feeder category performance. It is anticipated
that a combination of these methods in a suite of individual projects will normally be implemented to
achieve the required performance levels. These methods include:

improvements of individual feeder performance - affecting a sufficient number of individual feeders to
influence the category average, or

Improvements at a sub-transmission level, or

Improvements with wide spread impacts such as operating policy and its implementation, SCADA
systems, and the development of intelligent network options.
Distribution and Transmission Annual Planning Report December 2013
181
Options are short-listed and the reasons for discarding options recorded. The anticipated value of costs
and benefits of each short-listed option are estimated. The cost estimates are based on standard unit
costs and adjusted to reflect, to the extent practicable, the realities of implementing the solution.
SAIDI
(average minutes of supply
interruption per customer)
System
Forecast
Reliability Standards
95% Management Target
Reliability Gap
CBD
Forecast
Reliability Standards
95% Management Target
Reliability Gap
Urban
Forecast
Reliability Standards
95% Management Target
Reliability Gap
Short Rural Forecast
Reliability Standards
95% Management Target
Reliability Gap
Long Rural Forecast
Reliability Standards
95% Management Target
Reliability Gap
SAIFI
System
(average number of network
interruptions per customer)
Forecast
Reliability Standards
95% Management Target
Reliability Gap
CBD
Forecast
Reliability Standards
95% Management Target
Reliability Gap
Urban
Forecast
Reliability Standards
95% Management Target
Reliability Gap
Short Rural Forecast
Reliability Standards
95% Management Target
Reliability Gap
Long Rural Forecast
Reliability Standards
95% Management Target
Reliability Gap
8.1.5
2013/14
86.80
N/A
24.12
45.00
23.81
0.31
73.48
80.00
71.57
1.91
170.51
300.00
256.24
-85.73
507.46
700.00
453.78
53.69
2014/15
83.81
N/A
23.96
45.00
23.81
0.15
69.78
80.00
71.57
-1.79
159.53
300.00
256.24
-96.72
507.06
700.00
453.78
53.29
2015/16
83.35
N/A
23.80
45.00
23.81
-0.01
66.99
80.00
71.57
-4.59
151.52
300.00
256.24
-104.73
508.17
700.00
453.78
54.40
2016/17
83.23
N/A
23.66
45.00
23.81
-0.15
65.95
80.00
71.57
-5.62
150.57
300.00
256.24
-105.68
509.49
700.00
453.78
55.71
2017/18
82.76
N/A
23.54
45.00
23.81
-0.27
65.03
80.00
71.57
-6.55
150.17
300.00
256.24
-106.07
510.83
700.00
453.78
57.06
2018/19
82.55
N/A
23.40
45.00
23.81
-0.40
64.82
80.00
71.57
-6.76
150.06
300.00
256.24
-106.18
512.16
700.00
453.78
58.39
2013/14
1.04
N/A
0.16
0.30
0.16
0.00
0.94
1.20
1.06
-0.12
1.84
3.20
2.73
-0.90
3.63
6.00
4.24
-0.61
2014/15
1.03
N/A
0.16
0.30
0.16
0.00
0.93
1.20
1.06
-0.13
1.83
3.20
2.73
-0.90
3.63
6.00
4.24
-0.61
2015/16
1.02
N/A
0.16
0.30
0.16
0.00
0.92
1.20
1.06
-0.14
1.82
3.20
2.73
-0.91
3.64
6.00
4.24
-0.60
2016/17
1.02
N/A
0.16
0.30
0.16
-0.01
0.92
1.20
1.06
-0.14
1.82
3.20
2.73
-0.91
3.65
6.00
4.24
-0.59
2017/18
1.02
N/A
0.16
0.30
0.16
-0.01
0.92
1.20
1.06
-0.14
1.82
3.20
2.73
-0.91
3.65
6.00
4.24
-0.58
2018/19
1.02
N/A
0.16
0.30
0.16
-0.01
0.92
1.20
1.06
-0.14
1.82
3.20
2.73
-0.91
3.66
6.00
4.24
-0.57
Compliance with Network Reliability Standards
Ausgrid monitors feeder outages and records the duration of any outage event that we respond to into our
Outage Management System. For reliability reporting purposes, our network performance is measured at the
11kV distribution level. Excluding any planned interruptions and Major Event Days, the recorded outage
information provides Ausgrid with the frequency and duration of feeder outages that are used to determine the
SAIDI and SAIFI of individual feeders. In turn these individual feeders are grouped into categories, to enable
an average SAIDI and SAIFI to be determined for each category.
Currently Ausgrid sends both a Reliability Standards report and an Individual Feeder Standards report to the
Minister administering the Electricity Supply Act 1995 within one month of the end of each quarter.
Performance against the pro-rata SAIDI and SAIFI average standards is reported in the Reliability Standards
document, along with any reasons for non-compliance and Ausgrid’s plans to improve the feeder
Distribution and Transmission Annual Planning Report December 2013
182
performance. Similarly, the Individual Feeder document details the date at which a feeder first exceeded the
relevant Individual feeder standard and the SAIDI and SAIFI performance for that 12 month period, including
details of the remedial action to be taken to improve performance, and the planned date of completion for the
action plan. Typical remedial action plans include either operational or capital expenditure, a combination of
both, or in some cases non-network solutions.
Operational work may include works like vegetation maintenance or retro-fitting of animal proofing on electrical
mains and apparatus. Any identified and reported operational work is due to be completed by the end of the
third quarter following the feeder first exceeding the individual feeder standards.
Capital expenditure to improve feeder reliability can be in the form of a network augmentation project involving
feeder reclosers or covered overhead mains to prevent or correct some known outage triggers. Any required
capital work is to be developed, planned and commenced by the end of the second quarter following the
feeder first exceeding the individual feeder standards. Some investigations find that a feeder outage occurred
due to a one-off event that is not likely to occur again. In those situations monitoring of the individual feeder
performance is recommended as a non-network resolution to the feeder exceeding individual feeder
standards.
8.2
Quality of supply standards
It is not possible to supply all customers with the idealised voltage and current due to the physical nature of
the network and the characteristics of the customers’ loads. Ausgrid’s objective is to achieve the best possible
overall supply quality of our electricity network, given the condition and utilisation of existing network assets,
within the funding available to maintain and augment the electricity network. Current network supply quality
standards are available on Ausgrid’s internet site at www.ausgrid.com.au.
The National Electricity Rules require Distribution Network Service Providers to establish planning levels for a
range of supply quality parameters. At Ausgrid, monitoring for supply quality is undertaken by a number of
means including fixed meters at Distribution Substations, random PQ surveys at customer premises and
participation in the Long Term National Power Quality Survey conducted by the University of Wollongong.
Ausgrid does not control the frequency on the electricity supplied through its electricity network, as this
standard is set during the electricity generation process. The Australian Energy Market Operator (AEMO)
establishes standards and regulates the frequency of supply on the national grid. If Ausgrid becomes aware of
frequency excursions in excess of AEMO’s standards, Ausgrid will endeavour to bring these to AEMO’s
attention.
8.2.1
Voltage range for supplied electricity
Supply voltage is the voltage, from phase to neutral or phase to phase, for electricity that is supplied at a
customer’s point of supply. Maintaining this steady state supply voltage is important to ensure appropriately
designed equipment does not malfunction and is not damaged. When Ausgrid identifies or is notified that the
steady state supply voltage is outside the specified target range, Ausgrid will take reasonable steps to modify
the network to ensure that the voltage will be maintained at the required level and achieve Ausgrid’s steady
state voltage supply objective.
Low voltage network
Ausgrid’s objective for the operation of its network is to maintain a target steady state phase to neutral supply
voltage (measured as a ten-minute average) within the range of 216V to 253V at customers’ points of supply
under normal operating conditions. This range is the nominal voltage range of 230V in the relevant Australian
Standard AS 60038 Standard Voltages, with a tolerance of +10%/- 6% to allow for voltage regulation on the
mains between distribution substations and customers’ points of supply.
High voltage network
Ausgrid’s high voltage distribution network operates at several voltage ranges. Accordingly, high voltage
customers must obtain from Ausgrid, the network operating objective for supply voltage applicable to their
location, particularly before proceeding with any project expenditure or commitments.
Ausgrid relies on the following standards and/or guidelines when setting and assessing network voltage
performance:

Ausgrid Customer Supply Standard “Electricity Network Operation Standards (ENOS)” Section 5

Australian Standards: AS/NZS 60038 and AS 61000.3.100

NER S5.1a.4 – Power Frequency Voltage

NSW Service and Installation Rules (SIR): Section 1.4 refers to AS/NZS 600038 & AS 61000.3.100.
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8.2.2
Harmonics and total harmonic distortion
Voltage waveform distortion including harmonic distortion results from the operation of appliances or
equipment that draw non-sinusoidal currents from the network. Harmonic distortion can cause the supply
voltage to depart from a sine wave in a repetitive manner. Maintaining waveform distortion within acceptable
limits is important because it can otherwise cause interference and damage to sensitive customer and network
equipment. This form of distortion can also cause light flicker, incorrect operation of ripple control devices
(used for off peak electric hot water) and computers, audible noise in television, radio and audio equipment
and vibration in induction motors.
Ausgrid relies on the following standards and/or guidelines when setting and assessing harmonics
performance:
8.2.3

Ausgrid Customer Supply Standard “Electricity Network Operation Standards (ENOS)” Section 6

Australian Standards: AS/NZS 61000.3.6:2001, (SA/SNZ) TR IEC 61000.3.6:2012, AS 61000.2.2, AS
61000.2.12, SA/SNZ TR IEC 61000.3.14:2013

Standards Australia handbook for power quality HB264

NER S5.1a.6 – Voltage Waveform Distortion

NSW Service and Installation Rules (SIR): Section 1.10.2.1 (b) refers to AS/NZS 61000.3.2, 61000.3.4,
61000.3.12.
Voltage fluctuations (flicker)
Ausgrid relies on the following standards and/or guidelines when setting and assessing Voltage
fluctuations performance:
8.2.4

Ausgrid Customer Supply Standard “Electricity Network Operation Standards (ENOS)” Section 6

Australian Standards: AS/NZS 61000.3.7:2001, (SA/SNZ) TR IEC 61000.3.7:2012, AS 61000.2.2, AS
61000.2.12, SA/SNZ TR IEC 61000.3.14:2013

NER S5.1a.5 – Voltage Fluctuations

NSW Service and Installation Rules (SIR): Section 1.10.2.1 (b) refers to AS/NZS 61000.3.3, 61000.3.5,
61000.3.11.
Voltage unbalance
Ausgrid relies on the following standards and/or guidelines when setting and assessing Voltage
Unbalance performance:
8.3

Ausgrid Customer Supply Standard “Electricity Network Operation Standards (ENOS)” Section 6

Australian Standards: (SA/SNZ) TR IEC 61000.3.13:2012, AS 61000.2.2, AS 61000.2.12, SA/SNZ TR
IEC 61000.3.14:2013)

NER S5.1a.7 – Voltage Unbalance.
Quality of Supply Performance for preceding year
During the 2012-13 period, 206 randomly selected Ausgrid low voltage customer sites were monitored for
1 week using Class A Power Quality monitors following the requirements of AS/NZS 61000.4.30. The
sites were then evaluated for compliance of a number of power quality parameters against the relevant
standards:

Range of Supply Voltage – AS 61000.3.100

Voltage Unbalance – AS/NZS 61000.2.2

Harmonic Content of the Voltage Waveform – AS/NZS 61000.2.2

Voltage Fluctuations (Flicker) – AS/NZS 61000.2.2.
A set of 1 week’s low voltage data was also recorded in April 2013 for a sample set of 1090 distribution
transformers. This data was analysed for voltage performance and was compared to the data gathered from
225 distribution transformers in April 2012.
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184
8.3.1
Supply voltage performance
Australian Standard AS 61000.3.100, which is written for a nominal low voltage supply of 230V, states that the
th
99 percentile (V99%) of the 10 minute average voltage readings for a 1 week survey should be less than 253
Volts and that the 1st percentile (V1%) of the 10 minute average voltage readings for a 1 week survey should
be greater than 216V.
All monitored customer low voltage sites complied with the V1% limit and approximately 70% of sites complied
with the V99% limit. The high V99% figure is a consequence of the network historically designed for a nominal
240V range.
The results of the sampled Distribution Substations indicate that on average, there has been a 1 Volt drop in
th
the median and 99 percentile values for supply voltage between the 2012 and 2013 measured data.
Ausgrid‟s 230V migration program is progressively delivering a voltage range reduction using adjustments of
zone substation voltage regulation settings and distribution substation tap changes. The benefits of this
program should begin to be seen in the 2013-14 reporting period with the expectation that a higher percentage
of the LV sites will meet the limits.
8.3.2
Harmonic Content of Supply Voltage Waveform
The results of the survey show that the Total Harmonic Distortion (THD) was at or below 3.6% against the
permitted compatibility level of 8% THD for low voltage. All measured sites were compliant for THD.
th
th
All harmonics apart from the 15 harmonic were compliant. For the 15 harmonic, about 30% of
measured sites were above the limit of 0.3% compatibility level (maximum recorded level was 0.5%). This
is not seen as a significant issue and it should be noted that New Zealand imposes a higher limit of 1.8%
as the compatibility level for the 15th Harmonic.
8.3.3
Voltage Fluctuations (Flicker) performance
Short Term Flicker (Pst)

The results of the survey show that the majority (approximately 95%) of sites met the Short Term (Pst)
compatibility level for flicker of 1.0.
Long Term Flicker (Plt)

The results of the survey show that just over 90% of sites met the Long Term compatibility level (Plt) for
flicker of 0.8.
Long term flicker (Plt) is higher than short term flicker (Pst) due to the lower limit it is assessed against (0.8
versus 1.0).
8.3.4
Voltage Unbalance performance
The results of the survey show that voltage unbalance for all measured sites with 3 phase connection were
under the compatibility level of 3% as specified in AS/NZS 61000.2.2.
All measured sites were compliant for Voltage Unbalance.
8.3.5
Action planned to meet quality of supply standards
Supply Voltage
Measurements on the LV network indicate that a number of sites exceed the V99% value when measured to
AS 61000.3.100. Ausgrid is currently undertaking the following activities to lower the LV across the network
and deliver network functional compliance:

Lowering of the Zone substation 11kV float voltages

Change of Distribution transformer tap settings to deliver the correct 99th percentile voltage (to AS
61000.3.100:2011).
Harmonics
Measurements on the LV network indicate that a number of sites exceed the limit for the 15th harmonic.
th
Ausgrid is currently investigating the existing standards and limits applied for the 15 harmonic to see if the
limit can be relaxed to a more realistic level (noting that the IEEE 519 and New Zealand set higher limits apply
th
for some harmonics including the 15 ).
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185
Flicker
Measurements on the LV network indicate that a number of sites exceed the limit for Plt (Long Term flicker). In
the next 12 months Ausgrid will carry out an investigation to quantify the main sources of the flicker and to
determine mitigation means to lower the levels. Ausgrid will also carry out a review of the relative standards
limits between Short Term and Long Term flicker with a view to determining if the limit for Long Term flicker is
unreasonably low.
8.3.6
Compliance with quality of supply standards
Under the Standard Form Customer Connection Contract with Ausgrid, our low voltage network customers are
required to comply with the requirements of the Service and Installation Rules of NSW and any other
reasonable Ausgrid requirements. Consistent with those Rules and our rights under the Contract, Ausgrid
requires our customers to ensure that:

their electrical installation does not adversely affect Ausgrid’s network or other customers’ installations,
and

that any audible or electronic noise generated by their electrical installation does not breach relevant laws
or adversely affect others. If disturbances on the network are caused by more than one customer, Ausgrid
will establish overall limits for the interference by each customer, and customers who exceed their limits
are required to rectify the situation.
Ausgrid’s network modelling process includes checks for voltage compliance on the high voltage network and
our internal standards specify compliance requirements for low voltage. Customer quality of supply complaints
are reviewed and corrective action taken as necessary.
The process for managing power quality emission limits for major customer connections is generally dictated
by the National Electricity Rules (NER) requirements for connection agreements. Ausgrid is required to
provide a 20 day turnaround on responses to connection enquiries under the NER. Limits for automatic and
minimum access standards for power quality are included in Ausgrid’s response to the connection enquiries..
There are different rules which apply to network customers and registered generators. However, generally the
allocation of emission limits for customers and generators are defined in NER clauses S5.1.5-5.1.7. Power
quality requirements for connections are based around the following access standards:

Automatic Access Standards

Minimum Access Standards

Negotiated Access Standards.
For Generators allocation limits are defined according to NER Clauses S5.2.5.2. For network customers
allocation limits are defined according to NER Clauses S5.3.7 and S5.3.8.
For both generators and customers, harmonic and flicker allocations are based on the AS/NZS61000.3 series
of documents. For voltage unbalance the proposed approach within Ausgrid is to follow (SA/SNZ) TR
IEC61000.3.13:2012, which mirrors the Stages 1-3 approach of the harmonic and flicker standards.
The process for achieving compliance with the prescribed power quality allocation limits is likely to be an
iterative process, with consideration given to alternative connection points, or mitigation measures, should
initial investigations indicate non-compliance. Where necessary this may involve a reassessment of limits, or
the acceptance of a negotiated access. Suitable clauses are included in Ausgrid’s connection agreements to
ensure compliance with the power quality allocation limit via agreed levels of monitoring of the installation, and
also for appropriate notification and approval of customers’ planned major equipment changes, such as new
distorting loads or power factor correction. It should be noted that the NER provides scope for Ausgrid to
subsequently enforce automatic access standards where network conditions change.
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186
9
Asset Management
9.1
Ausgrid’s asset management approach
Ausgrid’s business purpose is ‘to be of service to our communities by efficiently distributing electricity to our
customers in a way that is safe, reliable and sustainable’. Effective asset management is a key enabler to
safely and efficiently delivering a reliable and sustainable electricity network, while containing network tariff
increases to the rate of inflation.
Ausgrid has an organisational focus on asset management, including design, procurement, maintenance
activities, renewals/replacements, capital investment, condition monitoring and continuous improvement, to
deliver this business purpose. Our asset management philosophy enables the competing requirements of the
network to be optimised through the mature consideration of risk and is supported by an integrated asset
management system.
Asset management can be defined as “the lifecycle management of physical assets to achieve the stated
outputs of the enterprise.”3 For Ausgrid these outputs are:

Compliance with statutory obligations (ie safety and environmental management, etc.)

Specified business outcomes

Asset “fitness for purpose” and asset integrity

Minimum life cycle cost through continuous improvement of the “what, the when and the how” of
maintenance.
Sound asset management processes also ensure that Ausgrid complies with the Electricity Safety Act,
Electricity Supply Act, and the associated NSW Electricity Supply Regulations and Industry Codes of Practice
which establish the accountabilities of organisations responsible for construction and maintenance of electrical
infrastructure and assets so they are operated safely and reliably.
Sound and efficient asset management processes and methods have a further responsibility to be able to
transparently prove to industry regulators the prudence and efficiency of our expenditure as it relates to
specific assets.
9.2
Asset Management Strategic Plan
The Asset Management Strategic Plan is critical to the financial and underlying asset risk of the network. It
forms one of the seven strategic plans used by Networks NSW to drive the overall asset management
direction and focus of our business. The purpose of this plan is to provide a framework for aligning the three
DNSP business activities.
This Plan has three main focus areas:

Governance – a single investment governance framework, with a consistent risk prioritisation
methodology and approach to asset management, in order to leverage the ‘power of three’

Network performance – requiring consistent input policies, asset standards and consolidated reporting
and monitoring, and

Value for customers – delivering improvement initiatives ensuring not only that we are operating
efficiently, but also maintaining our assets in an efficient and sustainable manner.
The 2013/14 Asset Management Strategic Plan is currently under review. Ausgrid will develop its Asset
Management Plans to meet the outcomes of the 2013/14 Asset Management Strategic Plan. Ausgrid’s Asset
Management Policy and Asset Management Strategic Plan (2011) will continue to be followed until the
Networks NSW 2013/14 Asset Management Strategic Plan is published and a new Ausgrid Asset
Management Plan developed.
The 2011 Asset Management Strategic Plan provides a high level link between the NSW Total Asset
Management Manual (TAMM) and the asset management approach adopted by Ausgrid. It identifies the four
key stages in the asset lifecycle (Asset Planning, Asset Acquisition, Use & Maintain and Asset Disposal), and
identifies asset management practices and issues that must be addressed during these phases.
3
Asset Management Council – www.amcouncil.com.au
Distribution and Transmission Annual Planning Report December 2013
187
Organisational Learning and Feedback
Improve and Replace
Figure 33: Asset Management Cycle
9.3
Risk Management strategies
Risk management identification and strategies to manage the identified business risks are maintained in
Ausgrid’s Executive Risk Register and reviewed at least annually. Risk management strategies associated
with the various asset categories, are applied across the asset planning process. These are unpinned by
Ausgrid's asset management strategy.
Risk mitigation may take many forms within an acquisition project. These include:

Detailed planning of the project task, to ensure that the scope of the requirement is clearly defined and
that appropriate plans and resources are made available to meet the requirements

Selection of proven and inherently low risk approaches within the design task, where this is possible to
meet specification and other contract requirements

Technical and other reviews to monitor the progress toward meeting contract requirements and initiating
corrective action as early as possible where deviations occur.
All acquisition projects contain an element of risk. These generally relate to the level of technical complexity to
be met within the asset solution, the schedule established for the task or financial aspects of the contract.
Failure to manage these risks may result in equipment which fails to meet specified performance, delays in
project completion, or budget overruns, or a combination of the above.
Operation of the assets also contains risk, originating mainly from the consequences of unplanned failures or
from high defect rates. These can result in adverse safety, environmental, operational and/or financial
impacts. These risks are included in the determination of maintenance requirements and the repair/replace
decisions.
Risk mitigation may take many forms within the operational phase in the asset lifecycle. These include:

Initiation of testing programmes

Condition monitoring

Altered maintenance task content and/or task periods

Initiate re-design of the asset (i.e. modification)

Altered operating / work procedures

Restrictions on changing equipment loadings

Restrictions on staff access to equipment/buildings when equipment is energised

Initiation of asset replacement programmes.
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9.4
Sub-transmission underground cables replacement strategy
Ausgrid’s sub-transmission cables are in continuous use and are an essential part of our supply network,
Therefore these assets cannot routinely be taken out of service except for brief periods necessitated by the
need for maintenance and repair. A number of these cables form the critical backbone of the sub-transmission
network, and loss of multiple circuits can have significant impacts upon our customers, particularly in the
Sydney CBD and surrounding urban areas.
Ausgrid has developed a strategic asset prioritisation for the replacement sub-transmission cables due to age
and condition. The primary focus of this asset management strategy is on the gas and self contained fluid (oil)
filled (SCFF) cable technologies which are now considered as superseded and resource intensive
technologies for cables at these voltage levels. A condition based risk assessment of our sub-transmission
underground cables was carried to examine:

The asset performance issues associated with the cable technologies used in underground feeder cables
operated at sub-transmission voltages of 33kV to 132kV

The availability and defect related performance of individual feeders

The service risk associated with individual feeders, and

The resulting risk based replacement prioritisation of feeders within their respective cable technologies.
In considering the age profile, reliability analysis, and the consequences of cable leakage / failures
experienced over the six year period to 2012, the following strategy position applicable to sub-transmission
underground cables has been developed.
9.5

All SCFF cables crossing major waterways are to be prioritised for replacement by the end of the 20152019 Regulatory period. The operational, customer reliability and environmental risks associated with
SCFF cable systems traversing Sydney’s major waterways are no longer considered acceptable

All SCFF cables are to be replaced or retired by the end of the 2025-2029 regulatory period. These cable
systems will have reached/exceeded the asset standard and design life, and combined with the problems
associated with this technology in terms of environmental impact of SCFF leakages, long repair times, the
resulting impacts on system reliability and availability, along with a reducing ability to support this
infrastructure beyond 2029 mean that this asset technology must be considered no longer viable as long
term asset solutions

All 33kV gas pressure cables are to be replaced or retired by the end of the 2015-2019 regulatory period.
These cable systems will have reached/exceeded the asset design life, as evidenced by increasing
monthly leakage volumes on a decreasing asset base in service, as well as the number of multiple cable
failures impacting zone substations.
11kV switchgear asset management strategy
Between the late 1930s and the late 1960s Ausgrid progressively installed a large number of compound
insulated 11kV switchboards with bulk oil circuit breakers (OCB). Ausgrid has compound insulated
switchboards in service across fifty-one (51) different Zone Substation locations, totalling some 999 bulk
OCBs. The oldest compound insulated switchboard on the Ausgrid network is seventy-five (75) years old,
while the youngest is thirty-nine (39) years old.
As technology progressed, air insulated switchboards (non-internal arc classified technology) with bulk oil
circuit breakers (OCBs) became widely available, and were installed from the late 1960s until the late 1970s,
when vacuum circuit breakers (VCB) were introduced. Internal arc classified switchgear later became the
accepted industry standard for new installations with Ausgrid installing this style of technology from 2004. This
progression of technology has resulted in a corresponding reduction in the risk of catastrophic failure. This
reduction in risk was traded off against a larger construction footprint in a typical urban style Zone Substation.
Ausgrid has air insulated switchboards in service across one hundred and twenty five (125) different Zone
Substation locations, totalling some 718 OCBs and 2664 VCBs. The oldest air insulated switchboard on the
Ausgrid network is 52 years old, while the youngest is zero (0) years old.
In rural and lower loaded areas, outdoor 11 kV cubicle switchgear was installed from approximately 1950 to
the mid-1980's. Due to environmental conditions, this type of switchgear has markedly deteriorated, leading to
more frequent failures and higher maintenance costs. Ausgrid has outdoor 11 kV cubicle switchgear in service
across twelve (12) different Zone Substation locations, totalling some 61 bulk OCBs and 2 VCBs. The oldest
outdoor 11 kV cubicle switch on the Ausgrid network is 60 years old, while the youngest is four years old.
Distribution and Transmission Annual Planning Report December 2013
189
9.5.1
11kV compound switchgear replacement strategy
Over the years there have been a considerable number of significant failures of 11kV switchgear installed in
zone substations that have resulted in a range of consequences from simple equipment outages, to expulsion
of hot oil from the circuit breaker, to small fires confined to the switchroom, to large fires that have burnt down
the entire switchroom. A range of measures have been undertaken to attempt to mitigate against these
consequences, however, much of this type of equipment installed in Ausgrid is now considered beyond its
design life, and continued service will result infurther deterioration in condition and an increasing number of
failures that are random in nature.
The ability to support compound switchgear technology into the future is becoming more challenging in terms
of maintaining the necessary technical expertise and skills, and the industry's capability to support spare parts
has extinguished. Manufacturers no longer support compound insulated technology, resulting in a need to
'engineer' solutions to suit specific switchboards.
Following the receipt of test results from Ausgrid’s 11kV compound switchboards that were considered outside
previous test limits, an extensive accelerated testing programme was initiated. The aim was to gain a better
understanding of the condition of the switchboards and gather further information to assist the decisionmaking process for the future management of these assets. This testing programme gathered the latest
measurements and trending information to assist the management of daily operations, as well as providing the
means for prioritisation of the replacement sub-programme for switchboards which are approaching the final
years of their lives.
The replacement priority of compound switchboards is designed around the following factors:

Individual 11 kV spout bushing dielectric dissipation factor (DDF) high voltage test results

Age and forecast degradation of the remaining compound insulated switchgear

Ability to recover from a switchboard failure, including the substation configuration loading and bus bar
protection type

Ex St George County Council refurbished switchgear with non-capacitively graded spout bushings.
Ausgrid’s compound switchboard replacement strategy is summarised as:
9.5.2

An ongoing testing programme, incident investigations as required and further research and
benchmarking in order to refine this strategy

All compound insulated switchboards are proactively replaced in a prioritised manner

The target date for complete removal of this technology from the network is set at 2024

High risk switchboards are planned to be replaced in the 2010-2014 regulatory period

Medium risk switchboards are planned to be replaced in the 2015-2019 regulatory period and lower risk
switchboards be replaced in the 2020-2024 regulatory period

The 11 kV bulk oil circuit breakers in medium and low risk switchboards are to be replaced with 11kV
vacuum circuit breakers in the 2010-2014 regulatory period to mitigate the risk and consequences of
failure.
Air insulated switchboard replacement strategy
From the late 1960s Ausgrid began to install air insulated 11kV switchboards in preference to compound
insulated switchboards This type of switchboard still included bulk oil circuit breakers (OCBs), however, such
switchboards were characterised by the lack of bitumous compound in the busbar chamber and the larger
construction footprint required to install this type of switchboard. These switchboards were progressively
installed on the network until air insulated switchgear with vacuum circuit breakers (VCBs) became widely
available in the late 1970s. This resulted inn substations which have a mixture of compound and air insulated
switchboards.
The insulation condition and design features of the 11 kV air insulated switchgear and associated circuit
breakers are a key issue for the ongoing management of the Ausgrid supply system. The analysis of test
results revealed that all air insulated busbar is in a serviceable condition for its age, however the condition of
the associated OCBs varies from serviceable to poor condition and after in service failures of similar types of
OCBs it has been decided to replace the OCB with current technology VCBs wherever feasible. Complete
switchgear replacement is however required in some cases due to the following factors.
Distribution and Transmission Annual Planning Report December 2013
190
Following an investigation into high voltage testing results at New Lambton zone substation 11 kV switchboard
and also after further investigation at other zone substations, it was discovered that English Electric OLX
Types 1, 2 and 3 air insulated switchgear in the Hunter and Central Coast region do not have internal earthed
metal barriers between the Main group left hand side and right hand side busbars and also between Main
group and Auxiliary bus bars and Feeder circuits. Due to the absence of any earthed metal barriers between
panel chambers within the switchgear, any work and/or testing within the switchgear compromises high
voltage clearances. Having earthed metalwork between switchgear chambers is considered to be industry
best practice and allows for work to occur with the busbar chambers whilst other sections of the switchboard
remain in service.
This has limited the ability of Ausgrid to operate and maintain these switchboards in the immediate term and
have therefore accelerated the replacement priority. Obsolete switchboards, i.e. unique manufacturer/model
types that have a low population on the Ausgrid network, which are not economically viable to specifically
design and manufacture a suitable VCB replacement has also been prioritised within the programme. The
inability to efficiently remove the oil fire ignition risk is further compounded by lack of suitable spare parts as to
maintain this equipment in serviceable condition. This has accelerated replacement of these switchboards.
The ability to support ageing air insulated switchgear technology into the future is becoming more challenging
in terms of maintaining expertise and skills (Engineering & Trade) and the industry's capability to support
spare parts has greatly reduced.
The replacement priority of switchboards is designed around the following factors:

English Electric OLX Barrier Board Issues and OCB ignition risk

Lack of available spares to maintain obsolete air insulated switchgear and OCB ignition risk.

Lack of available spares to maintain obsolete air insulated switchgear with VCBs where OCBs were
originally installed and were subsequently retrofitted as an interim life extension measure

Age and forecast degradation of the remaining air insulated switchgear

Ability to recover from a switchboard failure based on substation configuration, loading and busbar
protection type.
Ausgrid’s air insulated switchgear replacement strategy is summarised as:
9.5.3

An ongoing testing programme, incident instigations as required and further research and benchmarking
in order to refine this strategy.

Air insulated switchboards are proactively replaced in a prioritised manner in line with factors one to five
above

High risk switchboards are replaced in the 2010-2014 regulatory period

Medium risk switchboards are replaced in the 2014-2019 regulatory period and lower risk switchboards
be replaced in the 2020-2024 & 2025-2029 regulatory periods

The 11 kV bulk oil circuit breakers in medium and low risk switchboards are replaced with 11kV vacuum
circuit breakers in the 2010-2014, 2015-2019 & 2020-2024 regulatory periods to mitigate the risk and
consequences of failure.
Outdoor 11kV switchgear replacement strategy
In some rural and lower loaded areas the decision was made to install outdoor 11kV switchgear as a more
cost effective arrangement. This type of equipment consists of stand-alone circuit breakers in separate
housings that are located in an outdoor switchyard. These were installed from approximately 1950 until the
mid-1980s. Despite generally being of a younger age than other 11kV switchgear on the Ausgrid network, the
deterioration of this type of switchgear is markedly pronounced due to its environmental conditions.
Accordingly, these circuit breakers have become more unreliable and expensive to maintain; and this type of
switchgear is now largely considered obsolete. Quality spare parts are difficult to obtain and maintenance
often consists of exchanging a failed part with a similar but well used item. The ability to maintain this style of
outdoor 11kV switchgear is also reduced due to the limited number of staff with appropriate skills to maintain
this aged and obsolete style of OCB.
The priority for outdoor 11kV switchgear was determined using several factors including known condition
derived from circuit breaker testing and visual inspection. Accordingly, Ausgrid asset management strategy for
outdoor 11kV switchgear recommends the following that all outdoor 11kV circuit breakers are replaced within
the regulatory period 2010-2014.
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9.6
Distribution network losses
Ausgrid has developed a network loss calculation methodology based on internal modelling and a
recommendation from consultants Evans & Peck. The aim of this methodology is to enable the quantification
of incremental values of network loss savings in the assessment of proposed network project options, and the
quantification of network losses as required under the new RIT-D.
Trials of network loss quantifications have been conducted with both sub-transmission network and
distribution network modelling to fine tune the methodology, and a functionality has been implemented within
our sub-transmission network modelling tool PSSE and our distribution (11kV) network modelling tool
SINCAL. Ausgrid is currently conducting case studies to develop and document a justifiable threshold of
materiality for network loss quantification, screening tests for network losses, and process implementation in
preparation for the first economic assessment and consultation under the RIT-D which commences on 1
January, 2014.
Ausgrid’s technical specifications for the assessment of losses for primary plant such as sub-transmission
transformers, distribution transformers, shunt reactors etc, specify the method of assessing capitalised losses
when comparing tender offers from suppliers.
For plant assessment purposes, the following formula, which takes into account the load factor, energy and
demand charges and interest charges on capital, may be used by Ausgrid to capitalise the guaranteed losses
to make a fair economic comparison of plant tenders.
K = C + LSi Wi + LSc. Wc
where K =
total capitalised cost in dollars
C=
purchase price of transformers in dollars
LSi =
the capitalised cost per kW of no-load loss in dollars
LSc =
the capitalised cost per kW of load loss in dollars
Wi =
no load loss in kW at nominal frequency and voltage
Wc =
load loss in kW at 75°C corresponding to the nominal ONAN rating and nominal voltage ratio.
The values of LSi and LSc are specified and updated in the technical specification for plant procurement.
9.7
Obtaining further information on asset management
Further information on asset management may be obtained in Ausgrid’s Network Management Plan and the
Electricity Network Performance Report available on the Ausgrid website.
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10
Demand Management
10.1
Demand management
When the demand for electricity at peak times approaches the capacity of network infrastructure, network
service providers must act to maintain reliable electricity supply to customers. Reliable electricity supply to
customers can be maintained by either increasing the network capacity (supply side management) or reducing
the peak electricity demand on the network (demand management or non-network solutions).
Demand management is an important part of efficient and sustainable network operations; and can involve
either the voluntary moderation of customer electricity demand at peak times or the supply of electricity from
generators connected at customer’s premises or to the distribution network. Effective use of demand
management reduces the cost to maintain the network and results in lower electricity bills.
There are a range of demand management solutions available for use by electricity networks. Examples
include:

Shifting appliance or equipment use from peak periods to non-peak periods (e.g. off peak hot water)

Converting the appliance energy source from electricity to an alternative (e.g. switching from electric to
gas heating)

Use of more efficient appliances (e.g. replacing lights with more efficient, lower wattage options)

Operating appliances at lower power demand for short periods (e.g. air conditioner load control)

Operation of embedded generators, and

Power factor correction.
When a planning review of the adequacy of an Ausgrid network load area identifies a network limitation, a
review of potential credible options that includes both reducing the network demand and increasing network
capacity is completed. Ausgrid’s goal is to find the lowest cost solution that meets the required reliability
standards. To ensure a thorough investigation of demand management possibilities, including embedded
generation, Ausgrid’s Demand Side Engagement Strategy outlines how Ausgrid consults with the community
and non-network providers about potential demand management options available to address the identified
network needs.
The demand management investigation is comprised of five separate stages:
Stage 1: Identify network need for demand related investment
Demand management options are considered during the network planning process either as part of the
development of potential credible options for individually identified network needs, or as part of the integrated
consideration of potential credible options in Area Plan reviews.
Stage 2: Conduct demand management screening test for credible non-network solutions
Each investment is screened to determine if it is reasonable to expect that a demand management or other
non-network solution could enable a deferral or avoidance of potential network investments. The screening
test is a desktop study used to establish Ausgrid’s expectation of whether non-network options are technically
and economically feasible, and implementable in time to address the network need. If the screening test
concludes that a non-network solution may be viable, a Non-network Options Report will be issued and the
options investigation process will begin.
Stage 3: Conduct demand management investigation including community consultation
The investigation process seeks to identify potential cost effective demand management or other non-network
options that could defer the network investment, and to identify the size, timing and budget costs of these
feasible options. Based on the demand reduction requirements in the demand management screening test,
the investigation stage identifies potential non-network solutions to achieve the demand reductions. Options
are identified using Ausgrid’s existing knowledge, via the public consultation, field visits to customer sites and
discussions with major customers. The investigation identifies the amount of demand reductions available and
the likely cost of each non-network option identified.
Stage 4: Select preferred non-network option, where viable and cost effective
Any feasible demand management options are considered alongside viable network augmentation options.
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Stage 5: Implement demand management solution
If a feasible demand management option is determined to be the most economical solution, it is implemented
with clear deliverables in terms of demand reduction, timing and cost. For more information on how Ausgrid
investigates and implements non-network solutions, please refer to our Demand Side Engagement Strategy.
10.2
Demand management investigations in 2012-13
Ausgrid initiated the following demand management investigations in 2012-13 to identify potential deferral of
network investment.
Project Name
1
Alexandria Subtransmission
substation
Initial
need date
March
2016
Demand
reduction
required
(Year 1)
12.0 MVA
Outcome
A demand management screening test concluded
that non-network options did not offer a potential
cost effective solution to enable deferral of the
supply side project.
Analysis as part of the area plan review indicated
that deferral of the supply side project using demand
management was likely to be viable.
2
Arncliffe to
Rockdale 11 kV
load transfer
Summer
2013/14
0.3 MVA
The subsequent demand management investigation
concluded that non-network options offered a
potential cost effective solution to enable deferral of
the supply side project. Investigation included a
public consultation paper for which no submissions
were received.
Following a change in customer requirements, a
revised electricity demand forecast has resulted in a
delay to the need date to Summer 2014/15.
3
4
Tarro to Thornton
11 kV load transfer
Summer
2016/17
0.4 MVA
Darling Harbour
11kV Zone
Development
Summer
2012/13
9.3 MVA
A demand management investigation was initiated
in 2012/13 and remains in progress.
5
6
7
8
Homebush Bay
Zone Additional
Transformer
Summer
2014/15
Jannali Zone
11kVFeeders 2 & 9
Summer
2014/15
South Greenacre
Park 11kV Zone
Development
Summer
2014/15
Top Ryde Zone
Additional
Transformer
Summer
2014/15
Analysis as part of the area plan review indicated
that deferral of the supply side project using demand
management was likely to be viable.
1.4 MVA
A demand management screening test concluded
that non-network options did not offer a potential
cost effective solution to enable deferral of the
supply side project.
A demand management screening test concluded
that non-network options offered a potential cost
effective solution to enable deferral of the supply
side project.
Following a revised electricity demand forecast and
a review of the network need, this project is no
longer required.
1.3 MVA
A demand management screening test concluded
that non-network options did not offer a potential
cost effective solution to enable deferral of the
supply side project.
9.9 MVA
A demand management screening test concluded
that non-network options did not offer a potential
cost effective solution to enable deferral of the
supply side project.
8.4 MVA
A demand management screening test concluded
that non-network options did not offer a potential
cost effective solution to enable deferral of the
supply side project.
Further information, including the screening test for potential non-network solutions and/or the demand
management investigation report for each project, can be found here on our website.
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10.3
Demand management projects implemented in 2012-13
In 2012-13, Ausgrid implemented the following demand management projects to defer network investment or
maintain network reliability.
10.4
Project Name
Demand
management
solution
Description
1
Pennant Hills NW Zone
development
Embedded
generation
(0.8 MVA)
This is a continuation of a project which began in
2010/11, to defer a $3.8m capital project. Following a
three year deferral, a revision of the electricity demand
forecast resulted in the cancellation of the project. The
total DM cost was $0.8m, and the total $3.8m capital
cost was avoided.
2
Medowie zone
substation
Embedded
generation
(5 MVA)
Continuation of non-network project to provide network
support in advance of the completion of the Medowie
zone substation. This project was forecast to reduce the
load at risk by 92% and continues into 2013/14.
Demand management innovation
As part of the Demand Management Innovation Scheme, Ausgrid investigates potential non-network solutions
to help reduce the cost of maintaining network reliability. In 2012-13, Ausgrid continued or initiated 14 nonnetwork projects across a range of customer sectors and energy appliance types. A brief description of the
projects is listed below. Further information on these investigations and trials is available on our website.
Project Name
Project Description
1
Dynamic load
control of small hot
water systems
Continuation of a trial started in 2011/12 to determine the viability of using direct
load control to manage the peak demand from electric storage hot water heaters
less than 100 litres in size.
2
CBD embedded
generator
connection
Project to develop, design and test an alternative embedded generator connection
in the Sydney CBD that addresses the potential fault level and feeder imbalance
issues which are considered to be potential barriers to the widespread adoption of
embedded generators in locations with this type of network architecture.
3
Subsidised off peak
hot water
connections
Continuation of a trial started in 2011/12 to develop & demonstrate marketing
approaches that can achieve high take-up rates of conversion of electric hot water
systems from continuous supply to direct load control and off peak electricity
tariffs.
4
Market research for
residential air
conditioner and pool
pump load control
Project to identify the likely customer acceptance rates from various air conditioner
and pool pump direct load control options for a range of financial incentives to
customers.
5
Dynamic peak
rebate for nonresidential
customers
Continuation of a trial started in 2011/12 to determine the level of demand
response available in the medium to large, low voltage, non-residential customer
sector from a dynamic peak rebate program.
6
AS4755 air
conditioner and pool
pump load control
Project to determine the viability of controlling AS4755 compliant air conditioners
and pool pumps. Trial includes the testing of two alternative, low cost
communication platforms.
Grid battery
Project started in late 2012/13 to investigate how a network grid-side battery can
be operated reliably and effectively for summer peak reduction purposes and to
potentially improve power and supply quality parameters of the network.
8
Off peak 2 summer
scheduling
Project started in late 2012/13 to determine the customer response and
operational issues from the implementation of a modified summer schedule for the
off peak 2 tariff which reduces summer peak demand.
9
Verification of
demand savings
from energy
efficiency programs
Collaborative project to determine the effect of energy efficiency programs (by
others) on peak demand that can be used in the development of demand
management programs.
10
Co-managing home
energy demand
Research project, in partnership with RMIT and TransGrid, to help understand
householder’s level of knowledge on peak demand and how they are responding
to current demand management activities.
7
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195
Project Name
10.5
Project Description
11
TransGrid triage
database
Collaborative project with TransGrid to develop a database of information to
support the investigation of demand management solutions for transmission
network investments.
12
Large customer
power factor
correction
Project to discover an optimal methodology for the implementation of power factor
correction programs by trialling a range of marketing and procurement approaches
and incentive levels.
13
Load control of
irrigation pumping
Project to investigate the likely scale and location of pumping systems in the Upper
Hunter region, the viability of load control from these systems and the projected
value from the use of pumping load control to defer network investment.
14
Small customer
power factor
correction
Project to investigate the potential for peak demand reductions from small
customer power factor correction and the technical and economic viability of single
step PFC units in the range of 12.5 kVAr to 75kVAr.
Forecast demand management projects
For the forward planning period of 2013/14 to 2018/19, Ausgrid has identified, as part of the area plan review
process, the following network investment projects where a non-network solution has been identified as a cost
effective solution, and has been included in the preferred investment strategy.
Project Name
Forecast need
date
Demand
reduction
required (Year 1)
1
Tarro to Thornton 11kV LT (8 MVA)
Summer 2016/17
0.36 MVA
2
Upgrade OH section of 33kV feeder S03(1) Belrose Zone
substation
Summer 2017/18
0.16 MVA
For other network investment projects, it was determined that a more detailed investigation closer to the need
date would be required to verify the viability of demand management, or that non-network solutions were
unlikely to offer a cost effective deferral of the supply side solution.
In advance of the forecast network need date (about 2 or more years), Ausgrid will initiate formal
investigations into the viability of using demand management including embedded generation to maintain
network reliability. This process will begin with a preliminary screening test to determine if it is reasonable to
expect that a demand management or non-network solution could enable a deferral or avoidance of the
planned network investment. Where the screening test determines that a non-network option has the potential
to be technically and economically feasible, then we will conduct a detailed demand management
investigation including community consultation.
For RIT-D projects, where the most expensive potential credible option to address an identified network need
is greater than $5 million, the consultation will also include the publication of a Non-network Options Report to
provide information on the network need and how demand management providers can submit their solutions
to be considered in our economic evaluation of the preferred solution.
Ausgrid invites interested parties and non-network solution providers to register their details on our Demand
Side Engagement Register found on our website here, to receive information updates on our demand
management activities.
For further information on our demand management programs and activities please contact Ausgrid’s Demand
Management team at demandmanagement@ausgrid.com.au. For more information on how Ausgrid
investigates and implements non-network solutions, please refer to our Demand Side Engagement Strategy
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11
Investments in metering and information
technology
11.1
Metering
Ausgrid is responsible for the Metering Provision for approximately 1.6 million sub 160MWh per annum
customer connection points across Ausgrid’s franchise area.
The management of installations connection to Ausgrid’s electricity network is essential from a revenue and
market obligations perspective. The management of installations includes market obligations to:

Supply metering hardware for all new and upgrade customer connections

Supply and install metering hardware for reactive replacement when metering unexpectedly fails in
service, and

Supply and install metering hardware for proactive replacement when populations of meters are identified
as being at risk of non compliance to Rules obligations.
Ausgrid’s maintenance and compliance approach is defined in the AEMO approved Metering Asset
Management Plan (MAMP). The summarised key components of the MAMP are as follows for Type 5 and
Type 6 metering installations:

Reactive replacement - Repairs within ten business days of fault identification. Typically, this involves
replacement of the meter

Proactive replacement – Meters are categorised into like populations, such as make and model, and each
population is field tested for accuracy and functionality under a sample testing regime defined by
Australian Standard 1284.13.
Type 5 Meter – Manually Read Interval
A metering installation containing an electronic meter, or meters, capable of recording electrical energy
consumption in National Electricity Market half hour intervals in accordance with the NER. Such meters are
read manually by meter readers. Data is down-loaded manually via probes into a hand-held data collection
device carried by Ausgrid meter readers.
Type 6 Meter - Manually read consumption only
A metering installation containing a meter or meters, (electronic or electromechanical) capable of recording
cumulative electrical energy consumption only. Such meters are read manually by Ausgrid meter readers who
record the cumulative consumption readings displayed on the Type 6 meter register. Ausgrid’s small customer
metering population comprises of approximately 2 million electromechanical meters.
Ausgrid has been monitoring the performance of in service meters for a number of years, using the sample
testing procedures defined in the MAMP. These sample test results are supplemented with customer
requested field tests where inadequate results are available. These results indicate a total of 280,380 meters
are due for replacement because of their failure to pass testing obligations under AS1284.13.
To fulfil its metering obligations in a prudent and efficient manner, Ausgrid’s metering policy is to install Basic
(type 6) metering on all new connections, except where the site consumption is greater than 40 MWh per
annum or the site requires an interval meter (eg embedded Solar generation) or specifically requested for the
site);
The anticipated growth in interval meters from new sites with consumption greater than 40 MWh pa, due to
replacement of failing electromechanical meters (where requested) and embedded generation is 15,000 per
annum. In summary, this is an increase of 54, 000 manually read interval meters (approximately 10, 800 pa)
and approximately 6000 Solar per annum over the Regulatory Period 2014-2019.
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11.1.1.1 Metering investments actual 2012/13 and forecast 2013/14
Table 31: Metering investment actual 2012/13 and forecast 2013/14
Actual 2012/13
Forecast 2013/14
Replacement metering
$9.45m
$11.40m
Franchise metering
$5.87m
$5.30m
Total metering investments
$15.32m
$16.70m
11.1.1.2 Metering investment beyond 2014/15 to 2017/18
Forecast metering investments for the period 2014/15 to 2017/18 have not been finalised and are not
available for inclusion in this report. Ausgrid is currenly preparing a regulatory submission for the period
2014/15 to 2018/19. The AER will make its next determination in early 2014 being the first of two for the
subsequent five-year period to 2019. These determinations will approve Ausgrid’s capital and operating
programs.
11.2
Information and communication technology
11.2.1 Ausgrid’s ICT plan
Ausgrid’s core business functions are reliant on information and communication technology (ICT) systems for
the business to meet its obligations as a network service provider. These ICT systems support both the
network and non-network needs. Network ICT provides Ausgrid with the ability to monitor and control our subtransmission and distribution network.
Our ICT Plan is structured to ensure the technology for the core business functions is maintained at the lowest
cost, is secure, and achieves compliance with statutory and regulatory requirements. The ICT Plan has been
developed using the Energy Industry Model (EIM) framework from AEMO. The following diagram describes
the core business functions within each Domain and the current enabling IT system.
Figure 34: Key Ausgrid IT Systems
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198
The EIM framework includes the following Domains:
Domain
Description
Asset
Management
Asset management is one of Ausgrid’s most critical functions. The asset management
business function concerns the management of all physical components of Ausgrid’s
electrical system across the lifecycle of assets from investment through to
retirement/replacement at the component level. It is also tightly integrated with operations
and planning at the Network level. The asset management systems are therefore integral
to providing services, reliability and quality of supply and protecting the safety of
customers, community and employees.
Work
Management
Work management refers to the efficient management of Ausgrid’s resources in the
delivery of services within the Network. It encompasses processes which are tightly
associated with the asset management capability described above, scheduling and
dispatch, warehousing and mobility.
Customer and
Revenue
Management
Customer and revenue management includes all of the processes related to the
collection of revenue resulting from the provision of energy distribution services. The
main processes in delivering this business capability are metering, revenue and customer
management, and network billing. Customer and revenue management also incorporates
network pricing, market transactions, meter data management and financial reporting.
Commercial
and Corporate
Commercial and corporate includes functions necessary for executive control and
oversight of normal organisational functions, such as finance, reporting, strategy
development and implementation, human resource management, non-system asset
management and property management.
Enterprise
Information
Management
The effective management of information across Ausgrid has become crucial. The nature
of the business dictates that information needs to be collected, managed and analysed in
order to provide timely and effective decision support. Information management is also
required to satisfy regulatory obligations and core financial and organisational reporting
and analysis.
The Enterprise Information management program of work was designed to organise,
design, safeguard and make accessible all information assets across Ausgrid. It includes
functions such as knowledge management (document and records management, portals
and content management), process and data management (quality, integration, workflow)
and business intelligence.
ICT
Infrastructure
Infrastructure provides the backbone to Ausgrid’s business capabilities and systems. It
includes all of the hardware, communication, operating systems and devices required to
support the business. A core component of the Ausgrid infrastructure is the two “tierthree” data centres.
System IT
System IT provides the core functions regarding provision and development of the
Distribution Network Management System (DNMS) and Supervisory Control And Data
Acquisition (SCADA) systems, core telecommunication networks (MPLS, 4G), distribution
network monitoring and control and elements of the Smart Grid Smart City program.
11.2.2 Description of key network related ICT systems
A number of major corporate systems are utilised by Ausgrid to manage the information and configuration of
the network assets.
11.2.2.1 SAP
SAP is Ausgrid’s company-wide information management system consisting of a number of integrated
modules which are used across the lines of business for budgeting and management reporting, including
tracking costs in cost centres and special financial costing (internal orders). From a network perspective SAP
provides core capabilities regarding Investment Management (IM), Project Systems (PS) and Plant
Maintenance (PM):

The Investment Management module is used as part of the investment governance for strategic planning
to maintain all aspects of the investment process, from managing the overall capital plan, from project
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inception through to completion. The IM Module contains the IM Program Structure which reflects and
controls the level at which capital plans and budgets are managed

Plant Maintenance is used for Asset Management of network system assets and interfaces with the GIS
system. It is used to maintain technical asset data, plan maintenance of technical assets, schedule and
despatch work and record details of work carried out

Project Systems is used for the management of projects across the organisation for both System and
Non-System Capital using Network Activities and Work Breakdown Structure (WBS) elements. Projects
originate in the IM module as Appropriation Requests, and when released and approved become
projects.
11.2.2.2 Geospatial Information System
The Geographical Information System (GIS) is the database of records for spatial and connectivity data
related to Ausgrid's network. It is used for Dial Before You Dig, planning and analysis along with providing
data for key business systems such as SAP, Outage Management System, and Ratings. The GIS holds
connectivity information used by the OMS, and master data on feeders and poles which is used to update
SAP PM via the GIS/SAP PM interface.
11.2.2.3 Outage Management System
The Outage Management System (OMS) is a computing application that predicts network fault locations
based on a combination of customer outage calls and network device operations. This system is used across
Ausgrid at the time of an outage to process customer outage calls, provide feedback to customers for known
outages, and to assist with managing outage identification and restoration. Data sourced from OMS is then
used by claims groups to process any customer claims resulting from outages and also for internal and
external regulatory reliability reporting. Primary users of OMS and OMS data include the Contact Centre,
Control Room, Despatch, Field Services, Network Security, Network Reliability and Network Claims.
11.2.2.4 Distribution Network Management System / Distribution Management System
The Distribution Network Management System / Distribution Management System (DNMS/DMS) is an
advanced SCADA system used by Ausgrid control rooms to monitor and control the electrical network. It
provides a real-time database to maintain a connectivity model representing the distribution and subtransmission network.
11.2.2.5 Metering Business System
The Metering Business System (MBS) supports the network metering requirements of the Australian
contestable energy market and provides a comprehensive suite of functions for the management of Meter
Reading, Meter Provision, Meter Data Provider and Network services.
11.2.2.6 ICT investment Actual 2012/13 and Forecast 2013/14
Throughout the year, key applications and infrastructure have been maintained to enable a reliable, scalable
and secure computing platform. These included our enterprise and geographic information systems, and
systems for outage management, document and records management and metering.
Ausgrid also migrated its zone substation monitoring and control systems from SCADA1 to a Distribution
Network Management system to reduce unacceptable levels of business risks.
Changes were also delivered under the National Energy Customer Framework program to assist Ausgrid in
meeting its obligations under the new framework before its launch on 1 July 2013.
The rollout of smart sensors to distribution substations continued this year, bringing the total number of
commissioned devices to 3,943. These sensors monitor ongoing transformer use, over-voltage and earth
leakage faults, as well as phase imbalances.
Ausgrid continued to deliver the Australian Government’s Smart Grid, Smart City project, commissioning more
than 22,000 trial devices on the electricity network. This project, underway since 2010, was designed to gather
information about costs and benefits of smart grid technology and included trials of distributed generation and
storage, grid trials and feedback technology that make the most of smart meters.
The key objective of the ICT Capex program is to: 
Meeting new and existing compliance obligations – In order for Ausgrid to appropriately manage its
business processes and fulfil it’s regulatory and statutory obligations, the ICT systems must be updated to
adhere to these obligations. Failure to invest in maintaining the ICT systems would result in lack of
compliance with regulatory and audit requirements and potentially result in the loss of license and
monetary fines (ATO, NECF, Market Rules)

Maintain core platforms and capabilities – Investment required to maintain the technical currency, vendor
support and capacity of existing ICT systems and assets to provide for standard control services in a
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200
prudent and efficient manner reducing the risk of potential failure and/or unplanned production outages.
Failure to maintain these platforms would lead to increased business and technical operational cost and
risk to deliver core business functions.
Table 32 contains a summary of actual ICT investment in 2012/13 and forecast investment in 2013/14, the last
year of the current regulatory period for Ausgrid.
Table 32 – ICT Investment actual 2012/13 and forecast 2013/14
ICT Program of Work
Actual 2012/13
Forecast 2013/14
IT Asset Management
$4,638,850
$4,818,416
IT Workforce Management
$1,063,492
$5,951,924
IT Customer and Revenue Management
$5,583,481
$5,784,405
IT Commercial & corporate Services
$3,677,760
$5,255,705
IT Enterprise Information Management
$7,253,850
$1,478,765
IT Infrastructure
$6,197,488
$8,241,214
System IT Capital
$61,889,997
$34,128,000
$90,304,916
$65,658,429
11.2.2.7 ICT investment beyond 2014/15 to 2017/18
Forecast ICT investments for the period 2014/15 to 2017/18 have not been finalised and are not available for
inclusion in this report. Ausgrid is currently preparing a regulatory submission for the period 2014/15 to
2018/19. The AER will make its next determination in early 2014 being the first of two for the subsequent fiveyear period to 2019. These determinations will approve Ausgrid’s capital and operating programs.
11.2.3 Smart Grid, Smart City
Smart Grid, Smart City (SGSC) is a $100 million Australian Government funded project, led by Ausgrid and
supported by our consortium partners. Up to 30,000 households have participated in the project which runs
between 2010 and 2013. The project has tested a range of smart grid and network customer technologies;
gathering information about the benefits and costs of implementing these technologies in an wider Australian
context.
During 2013, the Ausgrid Smart Grid, Smart City team analysed the trial data and are now completing the final
report for the Australian Government, which will describe the outcomes and conclusions of the trial. This report
is due for public release in early 2014.
Smart Grid, Smart City Grid Application trials
The grid-side part of SGSC, called Grid Applications, involves the deployment of new technology with control
algorithms at various points on the electricity network. The Grid Applications stream includes the following
initiatives:

Active Volt Var Control (AVVC). Uses smart grid technology to manage voltage delivery across the
network to more efficiently. This required the deployment of new voltage regulators and capacitor banks
integrated into an advanced DMS (distribution management system)

Fault Detection Isolation & Restoration (FDIR). FDIR trial included the installation of additional monitoring
and switches to better pinpoint location of faults and isolate them to restore power faster

Substation and Feeder Monitoring (SFM). The SFM project will shift some traditional substation and
feeder monitoring to an (online) condition-based monitoring approach. SFM will leverage Ausgrid’s
communications platforms to reduce the cost of getting vital asset information, including from high voltage
underground cables

Wide Area Measurement (WAM). Using integrated Phasor Measurement Devices, deployed at key points
in the Ausgrid sub-transmission and Transgrid transmission networks, to better predict system state and
possibly prevent network interruptions across a large area.
Distribution and Transmission Annual Planning Report December 2013
201
Smart Grid, Smart City Network Customer trials
The network customer trials encompass Home Energy products, distributed generation and storage, and the
electric car trial. These trials explored ways to improve consumer understanding of their energy consumption,
to reduce peak load demand on the network and to understand how changing behaviours and technologies
will affect networks in the future. The Network Customer stream includes the following trials:

The Smart Metering Infrastructure (SMI) component of Smart Grid, Smart City provides the enabling
infrastructure to collect data on household electricity usage. This data will be collected remotely,
communicated to the network operator in near real time, used for analysis and to provide feedback to the
customer

The Feedback Technologies component will help determine how better quality information can have a
measurable impact on total energy consumption and/or peak demand. This includes the installation and
evaluation of technologies such as Customer Portals, In Home Displays, Home Area Networks and Home
Energy Management Systems

The Electric Vehicle (EV) trial is to examine the impact of large scale adoption of electric vehicles to the
electricity supply industry in Australia. EV charging and load modelling will be monitored for both fleet and
home users to assess potential impacts on the electricity grid from Plug-In Hybrid EVs (PHEVs) and fully
EVs

The Energy Resource Management (ERM) stream investigates the potential of distributed storage
(battery) technology, natural gas powered fuel cells and the impacts of increase solar generation on the
distribution network.
11.2.3.1 Other Ausgrid Smart Grid Initiatives
In addition to the Smart Grid, Smart City project, Ausgrid have a number of other initiatives already underway
and planned.
Distribution Monitoring & Control
There are over 30,000 distribution substations (11kV/415V) in Ausgrid’s network. Historically, for the vast
majority of these distribution substations, there has been little or no remote telemetry available requiring
manual processes and site visits to perform such tasks as checking utilisation, checking voltage, checking
fault indications etc.
To address these issues, the Distribution Monitoring & Control (DM&C) project has been installing devices in
selected distribution substations to monitor both the 11kV and the LV network and utilising wireless
communications for returning data to Ausgrid’s IT and OT systems. Up to the end of 2013, around 3,700
DM&C devices have been deployed and commissioned.
A modified version of the DM&C device has been introduced as standard in new kiosk substations and the
deployment of DM&C devices is planned to continue in a targeted manner through to financial year
2017/2018. In addition during 2013, Ausgrid has been working on delivering a major firmware upgrade which
will provide improved integration with Ausgrid’s DMS (Distribution Management System) and it is planned to
integrate DM&C LV alarms (e.g. Blown Fuse and Loss of Voltage indications) with Ausgrid’s Outage
Management System, thus providing earlier warnings of issues with customer supply.
Low Voltage Information System
Currently obtaining measurements on distribution substation utilisation relies on field staff manually recording
and reseting Maximum Demand Indicators (MDI) meters. Although some distribution substations will have
DM&C devices, the majority will not.
A new, proposed Low Voltage Information System aims to use Ausgrid’s enterprise analytics platform to
calculate estimated load on the low voltage network and identify potential overloads for further investigation.
The system will utilise metering data in conjunction with connectivity data provided by Ausgrid’s GIS. Where
available, DM&C measurements can be used to calibrate and refine the estimates.
Smart Switch Deployment
Since late 2010 Ausgrid has been implementing a Smart Switch Program for its overhead network. This has
involved the installation of smart recloser switches as well as enclosed load break switches. As an extension
of the above Smart Switch Program, Ausgrid has been investigating the proposed trial of a decentralised fault
detection, interruption and restoration scheme.
The proposed technology functions with peer to peer communication between field devices and full
communication and control via Ausgrid’s SCADA system.
Distribution and Transmission Annual Planning Report December 2013
202
Distributed Temperature Sensing
Distributed Temperature Sensing (DTS) can be used, among other things, to monitor and calculate the
conductor temperature and dynamically rate the cables by accounting for the cables load history. and the
characteristics of the cables installation. DTS also has the capability to identify emerging issues along an
underground cable, and increase cable reliability and overall asset utilisation which can lead to a deferral in
capital expenditure.
Ausgrid plans to deploy underground cables with DTS technology on feeders that are DTS ready and meet
defined installation criteria based on target utilisation levels within the 5 and 10 year load forecast time frame.
IEC 61850 adoption
IEC 61850 is a communications protocol standard for use in substations that enables the integration of
protection, control, measurement and monitoring functionality within the one protocol, standardising data
points across devices and therefore enabling consistency and compatibility and significantly reduce design
effort required. Additionally the standard provides tools to allow for greater flexibility in designing the
secondary system.
Two deployments have already been delivered within Ausgrid, and 4 or 5 more are expected by the end of
2013. All new Ausgrid substation SCADA systems will be based on IEC 61850 communications for all controls
(local and remote from Control Room) and indications.
Distribution and Transmission Annual Planning Report December 2013
203
12
Transmission Annual Planning Report 2013 Update
12.1
Transmission Annual Planning Report 2013 update
This update to the original Transmission Annual Planning Report 2013 (TAPR) which was published in
June, 2013 is included in Ausgrid’s first Distribution Annual Planning Report (DAPR) to align the
publication dates of the DAPR and TAPR in future years. Under the NER Network Planning and Expansion
rule which came into effect on 1 January, 2013 a distribution network service provider with dual function
assets may publish a single annual planning report which includes the requirements of both the DAPR and
the TAPR.
The TAPR section of this report provides updated information to Registered Participants and Interested
Parties on the nature and location of emerging network constraints on the dual function assets in Ausgrid’s
electricity network. The timely identification of network constraints allows the market to identify potential
credible non-network options and for Ausgrid to develop and implement appropriate and timely solutions to
them. The augmentation proposals described in this report are reliability projects and do not have a
detrimental material inter-network impact.
This update of the TAPR documents processes and outcomes of the transmission annual planning review
carried out since the publication of TAPR 2013 in June 2013. The purpose of the update is to:
12.2

Provide details of load forecasts submitted by any Registered Participants

Identify emerging constraints in Ausgrid’s dual function asset network over a 10 year planning horizon

Provide advance information on the nature and location of emerging constraints on dual function
assets

Discuss planning proposals for future connection points

Provide summary information for proposed dual function asset augmentations

Briefly discuss new replacement dual function assets, and any reasonable network and non-network
options to the replacement assets, and

Provide information on urgent and unforeseen dual function network investments.
Transmission annual planning review
The National Electricity Rules (NER) require network service providers who own and operate dual function
assets to register as Transmission Network Service Providers by virtue of the definition of 'TNSP' in the
rules. Certain parts of the rules treat dual function assets in the same way as other sub-transmission
assets. However, for the purposes of the transmission annual planning review and reporting, dual function
assets are treated as transmission assets requiring a Transmission Annual Planning Report. For the
purposes of economic evaluation and consultation with Registered Participants and Interested Parties,
dual function assets are treated as distribution network assets and are subject to the same economic
evaluation test. From January 2014, the Regulatory Investment Test for Distribution (RIT-D) will replace
the former Regulatory Test for all newly commenced economic evaluations and consultations on dual
function assets.
Ausgrid’s dual function network is defined as those assets with a voltage of 66kV and above that are
owned by Ausgrid, and operate in parallel with and provide material support to the TransGrid transmission
network. These assets may either operate in parallel with the transmission network during normal system
conditions or can be configured so that they operate in parallel during specific system conditions.
An asset is deemed to provide material support to TransGrid’s transmission network if:

there is otherwise limited or no system redundancy within transmission network, or

investment in the transmission system would be required within the regulatory period if that network
asset did not exist, or

the feeder provides operational support to the transmission network (e.g. to facilitate maintenance of
transmission assets or improve security of supply) and the asset provides an effective parallel with the
transmission network via a relatively low impedance path.
Ausgrid reviews the function of its dual function assets annually to determine if they continue to provide
material support to TransGrid’s transmission network. This review is used as input for preparing Ausgrid’s
Distribution and Transmission Annual Planning Report December 2013
204
regulatory reporting, the regulatory submission, and pricing methodology. For the purpose of the regulatory
submission, the list of dual function assets is determined based on the forecast load and the system
configuration as at the beginning of the regulatory period.
12.2.1 Ausgrid’s responsibility as a registered TNSP
The NER require a DNSP also registered as a TNSP with dual function assets to:

analyse the future operation of its network to determine the extent of any future network constraints

conduct joint planning with TransGrid TNSP to determine the extent of any emerging constraints

conduct joint planning with each DNSP to which the dual function assets are connected to determine
options for the relief of constraints

develop a Demand Side Engagement Strategy and establish and maintain a demand side engagement
4
register for parties wishing to be advised of relevant developments related to Ausgrid's planning activities

establish, maintain and publish a demand side engagement database of non-network proposals and/or
case studies that demonstrate assessments undertaken by Ausgrid in considering non-network proposals

engage with non-network service providers and consider non-network options at the planning stage

coordinate a consultative process for the consideration and economic analysis of potential credible
network and non-network options in accordance with the Australian Energy Regulator’s (AER) new
Regulatory Investment Test for Distribution5 (RIT-D) after 1 January, 20146

determine the preferred solution to an identified network constraint and consult with Registered
Participants, Interested Parties and parties registered on the Demand Side Engagement Register prior to
implementation

arrange for the implementation of the preferred option, and

prepare and publish a Transmission Annual Planning Report.
The NER require that the Transmission Annual Planning Report must include:

Results of the annual planning review

Load forecasts submitted by Registered Participants

Planning proposals for future connection points

Forecasts of emerging constraints and inability to meet the network performance requirements of NER
Schedule 5.1 and the NSW Design Reliability and Performance Licence Conditions

Summary information for proposed augmentations

A brief description of new replacement dual function assets, and any reasonable network and nonnetwork options to the replacement assets, and

Information on urgent and unforeseen network investments.
4
This obligation arises from the commencement of the new NER Network Planning and Expansion rule. This rule replaces
many of the requirements formerly covered by the NSW Demand Management Code of Practice, which was withdrawn on
1 January, 2013.
5
The purpose of the RIT-D is to identify the credible option (the preferred option) that maximises the present value of the
net economic benefit to all those who produce, consume and transport electricity in the market. The RIT-D process takes
place before investment decisions are made and is applied-the estimated capital cost of the most expensive potential
credible option is more than $5 million.
6
The old Regulatory Test will continue to apply to dual function asset economic assessments commenced prior to 31
December 2013, under a NER transitional arrangement subject to each DNSP obtaining formal approval from the AER.
Distribution and Transmission Annual Planning Report December 2013
205
12.3
Developments since the publication of TAPR 2013 (June 2013)
12.3.1 Dual function projects cancelled or deferred
The following dual function asset augmentations or replacement projects described in TAPR 2013
published in June, 2013 have either been cancelled, or deferred beyond the ten year forward planning
period.
Region
TAPR 2013
(June)
Section
Project
Timing
Reason for cancellation / deferral
Sydney
3.2
Homebush Bay ZS 132kV
Additional Transformer
Cancelled
Project cancelled due to lower forecast
demand in the Inner West area.
Sydney
3.2
Riley Street STSS
Cancelled
Project cancelled due to reduced load
growth in the network area. No
requirement for STSS.
Sydney
6.21
Belmore Park 132/11kV ZS
Jan-14
Completion delayed by project delivery
issues.
Sydney
A5.2.11
Beaconsfield BSP to St
Peters ZS 132kV Feeders
91A/1 & 91B/1 Replacement
Deferred to
Dec-27
Project deferred from September 2021 to
December 2028 due to a revised cable
condition assessment.
Sydney
6.2.5
Bunnerong North 132kV
Capacitor
Sep-14
Completion delayed by project delivery
issues.
Central
Coast
7.1.3
Wyong ZS Additional
Transformer
Cancelled
Proposed major customer data centre
load is on hold.
Central
Coast
7.5
Charmhaven ZS Additional
Transformer
Cancelled
Project cancelled due to a reduction in
forecast load.
Central
Coast
A5.2.21
Lisarow 132/11kV Zone
Substation
Cancelled
Proposed solution is to retain existing
Lisarow as 33/11Kv substation due to
lower forecast and revised cost for 132kV
solutions.
Hunter
7.5
Beresfield STS 132kV
additional transformer
Cancelled
Project cancelled due to reduction in
forecast load.
Hunter
7.5
Cameron Park 132/11kV ZS
Cancelled
Project cancelled due to reduction in
forecast load.
Hunter
6.2.3
Brandy Hill 132/11kV ZS
Jan-14
Completion delayed by project delivery
issues.
Hunter
Removed from
TAPR
Newcastle BSP to
Merewether STS 132kV
Feeders 960 and 961
Replacement
Dec-28
Project deferred from September 2021 to
December 2028 due to a revised cable
condition assessment.
12.3.2 Changes in dual function asset status
The list of Ausgrid’s dual function assets is reviewed periodically and is used as input for preparing Ausgrid’s
regulatory reporting, regulatory submission and pricing methodology. For the purpose of the regulatory
submission, the list of dual function assets is determined based on the forecast load and the system
configuration as at the beginning of the regulatory period.
Ausgrid’s dual function network is defined as those assets with a voltage 66kV and above that are owned by
Ausgrid and operate in parallel with and provide material support to the TransGrid transmission network.
These assets may either operate in parallel with the transmission network during normal system conditions, or
can be configured so that they operate in parallel during specific system conditions.
An asset is deemed to provide material support to the TransGrid transmission network if:

there is otherwise limited or no system redundancy within TransGrid’s network, or

investment in the transmission system would be required within the regulatory period if that network asset
did not exist, or
Distribution and Transmission Annual Planning Report December 2013
206

the feeder provides operational support to the transmission network (e.g. to facilitate maintenance of
transmission assets or improve security of supply) and the asset provides an effective parallel with the
transmission network via a relatively low impedance path.
The following 132/11kV zone substations (ZS) and sub-transmission substations (STS) are no longer
considered as dual function assets: Beresfield ZS, Croydon ZS, Drummoyne ZS, Gwawley Bay ZS, Leichhardt
ZS, Macquarie Park ZS, and Pyrmont STS.
The following 132/11kV zone substations (ZS) and sub-transmission substations (STS) have been reclassified
as dual function assets: Potts Hill, new Rose Bay 132/11kV, Muswellbrook, Mitchell Line, Singleton, Brandy
Hill, and Rothbury.
The following augmentation or replacement projects described in TAPR 2013 are no longer considered as
dual function assets:
Region
TAPR 2013 (June)
Section
Projects no longer considered as dual function assets
Sydney
3.2
Gwawley Bay ZS 132kV Conversion.
Following Ausgrid’s review of the operational role of subtransmission assets, this project is not considered to be a dual
function asset.
Gwawley Bay ZS full conversion to 132kV has been deferred from
June 2016 to September 2021 due to lower forecast load in the area
and will function as a 33/11kV and 132/11kV ZS hybrid substation.
Sydney
6.3
Mason Park – Rozelle Feeder 900 Replacement.
Following Ausgrid’s review of the operational role of subtransmission assets, this project is not considered to be a dual
function asset.
The need to replace feeder 900 in addition to replacing the existing
Leichhardt and Five Dock 33/11kV Zone Substations is driven by
asset condition and the need for replacement. This is a committed
project.
Sydney
A5.2.13
Drummoyne ZS 132kV Feeders 203 & 204 Replacement.
Following Ausgrid’s review of the operational function of dual
function assets, this project is not considered as a dual function
asset.
Replacement options are still under consideration, however the
most likely option is to replace the oil-filled cables with XLPE cable.
Proposed date is Dec-2025.
Sydney
A5.2.21
Double Bay Feeder 90R/2 and 9SB/2 Replacement.
Following Ausgrid’s review of the operational role of subtransmission assets, this project is not considered to be a dual
function asset.
Sydney
A5.2.22
Lidcombe 132/11kV ZS, a proposed solution for the replacement of
Lidcombe 33/11kV ZS due to asset condition, is no longer
considered as a possible 132kV dual function asset.
Distribution and Transmission Annual Planning Report December 2013
207
12.4
Committed and Completed Dual Function Augmentations
12.4.1 Completed Augmentations
This section describes augmentations that have been completed since the publication of TAPR 2013.
Haymarket – Beaconsfield BSP New 132kV Feeder
At over 40 years old, the Lane Cove to Dalley Street 132kV feeders 92L and 92M were due to be retired by
September 2012. Sydney Central Business District (CBD) network limitations identified in previous TAPRs are
exacerbated with the retirement of 132kV feeders 92M and 92L.
A joint TransGrid-Ausgrid Application Notice was published in July 2010 outlining the network limitations in the
CBD. A joint Final Report (Reinforcement of Electricity Supply within the Sydney Central Business District)
was published in October 2010.
Consistent with Ausgrid’s and TransGrid’s long term strategy to develop additional 330kV capacity to the
Sydney CBD and inner metropolitan area, the Final Report proposed a Haymarket to Beaconsfield 132kV
feeder consisting of a 132kV cable section by Ausgrid from Haymarket to Sydney Park, and a 330kV section
by TransGrid (operated at 132kV) from Haymarket to Sydney Park. This 132kV feeder would not be required
after the establishment of a second 330kV supply to the CBD. It is anticipated that the 132kV section would be
utilised for future 132kV developments, and the 330kV section would be reconnected when required to form
the second CBD supply anticipated in 2018/19.
No non-network alternatives were considered to be viable alternatives to this project.
This project was completed in August 2013.
12.4.2 Committed Dual Function Augmentations
This section describes network constraints that are being relieved by augmentations that are considered
committed. These projects will normally have appeared in previous TAPR publications as proposed network
augmentations.
For the purposes of the TAPR, an augmentation is considered to be committed if it satisfies all the criteria that
are defined in AEMO’s Statement of Opportunities (SOO), as follows:

Board commitment has been achieved (this requires the appropriate planning approvals and licences to
be in place)

Funding has been approved

The project has satisfied the Regulatory Test, and

Construction has either commenced, or a firm date has been set for it to commence
The committed augmentations are as tabulated below.
Estimated costs are in real 2013/14 dollars.
Region
Refer to
section
Sydney
12.4.2.1
Sydney
Augmentation
Identified
Constraint
Timing
Estimated
Cost
Belmore Park
132/11kV Zone
Substation
Licence condition
N-2 security
standard
Jan-14
$102.1m
12.4.2.4
Bunnerong
North
132kV Capacitor
Load Growth
Sep-14
$13.3m
Sydney
12.4.2.2
Rookwood Road Bulk
Supply Point 132kV
Connections
Licence condition
N-2 security
standard
Dec-14
$8.2m
Hunter
12.4.2.3
Brandy Hill 132/11kV
Zone Substation
Asset condition,
load growth
Jan-14
$25.2m
Summary information concerning these augmentations follows.
Distribution and Transmission Annual Planning Report December 2013
208
12.4.2.1 Belmore Park 132/11kV Zone Substation
In TAPR 2013 it was identified that the most likely option to address the requirement for an N-2 security
standard in the Sydney CBD area (as per the licence conditions relating to reliability performance of DNSPs)
was to establish a new 132/11kV zone substation at the southern end of the Sydney CBD on a site opposite
Belmore Park.
Two options were considered for the development of a new CBD zone substation:

Construction of a CBD zone substation in the Southern end of the CBD (Belmore Park)

Construction of a CBD zone substation in the Northern end of the CBD
No credible non-network options were considered viable alternatives to this project.
A consultation process was carried out in accordance with clause 5.6.6 of the NER. An Application Notice
(Establishment of a New 132kV/11kV CBD Zone Substation) was published in July 2008. A Final Report was
published in July 2009 with the proposed works being unchanged from the Application Notice.
The works are planned to be completed by January 2014.
12.4.2.2 Rookwood Road BSP 132kV Connections
In TAPR 2013 it was identified that the most likely option to address constraints on the Inner Sydney Inner
Metropolitan electricity supply network when applying the modified N-2 reliability standard was the
establishment of a new 330/132kV BSP at Rookwood Road. Ausgrid is responsible for providing 132kV
connections to the BSP and undertaking the necessary augmentation works on their network. This would
involve three 132kV feeder connections at Rookwood Road BSP - two to tee points on the 132kV tower line
240, 241 (between Chullora STS and Potts Hill ZS), and another onto the Sefton ZS tee point on the existing
feeder 296 (between Potts Hill ZS and Bankstown STS).
Two 330kV strategic network options and non-network options were considered to address the identified
network need. As a result of TransGrid proposed 330/132kV BSP, the proposed Rookwood Road BSP 132kV
feeder is required to connect to Transgrid 330/132kV BSP. The following 330kV strategic options are based
on TransGrid’s Application Notice.

330kV supply from Sydney West. This option involves installing 330kV feeders from TransGrid’s Sydney
West via a proposed Holroyd BSP (to supply Endeavour Energy) to the Chullora/Potts Hill area. A 330kV
feeder would then be extended in future to provide further 330kV supply to Beaconsfield and Haymarket
BSP’s

330kV supply from Sydney North/Sydney East. This option involves installing a 330kV feeder from
Sydney East to Haymarket and Beaconsfield BSP’s and upgrading of the 132kV towers between Sydney
North and Sydney East BSP’s to 330kV, and

The implementation of 80MW of demand management to defer the constraint by 1 year.
A non-network options investigation concluded that the emergence of network constraints could potentially be
rd
delayed by one year through the implementation of an 80MW demand management project. On the 3
December 2009 TransGrid published a Request for Proposal (RFP) for network support from non-network
service providers. Following an analysis of the responses to the RFP, it was determined that as a result of
insufficient network support offered by non-network service providers, there was no viable non-network
alternative to this project.
A consultation process was carried out in accordance with clause 5.6.6 of the NER. A joint Application Notice
was published in December 2009 outlining the issues and a preliminary application of the regulatory test. A
Final Report (Development of Electricity Supply to the Sydney CBD and Inner Metropolitan Area) was
published in March 2010 with the proposed works being unchanged.
The works are expected to be completed by December 2014.
12.4.2.3 Brandy Hill 132/11kV Zone Substation
In TAPR 2013 it was identified that the most likely option to address asset condition issues at the existing
Wallalong 33/11kV ZS and an emerging capacity constraint due to significant residential development in
surrounding areas (Wallalong, Brandy Hill and Seaham) was the installation of a new 132/11kV zone
substation in the Brandy Hill area. Supply to the new zone substation will be provided from a proposed 132kV
line to be constructed by TransGrid between Tomago BSP and Stroud (ex feeder 860). Options considered to
address these issues included:

Development of 33/11kV Brandy Hill zone substation with two 33MVA 33/11kV transformers
Distribution and Transmission Annual Planning Report December 2013
209

Development of 132/11kV Brandy Hill zone substation.
No non-network alternatives were considered viable alternatives to address the asset condition issues at
Brandy Hill zone substation.
A consultation process was carried out in accordance with clause 5.6.6 of the NER. An Application Notice was
published in June 2009 outlining the issues and a preliminary application of the regulatory test. A Final Report
(Brandy Hill 132/11kV Zone Substation Development) was published in December 2009 with the proposed
works being unchanged.
The works are planned to be completed by January 2014.
12.4.2.4 Bunnerong North 132kV Capacitor
TAPR 2013 identified the installation of an 80MVAr capacitor bank at Bunnerong North STS to avoid a
significant shortfall of reactive capacity in the inner metropolitan network in the event of a planned or
unplanned outage of TransGrid’s 330kV feeders 41 or 42. The preferred option was to install an 80MVAr
capacitor bank at each of Bunnerong North STS and Peakhurst STS.
An investigation of potential non-network options was carried out. It was determined that it was not reasonable
to expect Demand Management to cost effectively defer the recommended network solution.
A consultation process was carried out in accordance with clause 5.6.6 of the NER. As the total augmentation
component of the projects was under $20m, publication of an Application Notice was not required. A Final
Report (Inner Metropolitan Reactive Support) was published in June 2011.
This work is planned to be completed in September 2014.
12.5
Planned Augmentations that have been subject to the Regulatory Test
This section describes dual function network constraints that are being relieved by augmentations that have
been subject to the Regulatory Test but have not progressed to the point where they can be considered as
committed in AEMO’s SOO.
No planned dual function augmentations which have been subject to the Regulatory Test remain
uncommitted. Following an annual review of dual function assets the Mason Park to Rozelle Feeder 900
replacement project no longer fulfils the operational criteria for a dual function asset. This project is described
in the DAPR section 6.4.1.20.
12.6
Proposed dual function network developments
The following sections describe specifically identified current and emerging constraints within Ausgrid’s dual
function network. Where dual function assets are proposed to relieve these constraints they are detailed as
required by the NER.
Section 12.6.1 describes constraints expected to emerge over a five year planning horizon that are proposed
to be relieved by dual function assets. These descriptions include an explanation of the ranking of reasonable
options to each proposal in accordance with the principles contained in the AER’s Regulatory Test.
Section 12.6.2 describes constraints expected to emerge over a five year planning horizon that are proposed
to be relieved by dual function assets for which consultation is anticipated within 12 months.
Section 12.6.3 describes constraints expected to emerge over a five year planning horizon that are proposed
to be relieved by dual function assets for which consultation is anticipated beyond 12 months.
Section 12.6.4 describes the longer term constraints expected to emerge over a five year planning horizon
that are proposed to be relieved by dual function assets.
Section 12.7 describes planning proposals for new dual function asset connection points and augmentations
existing connection points. Requirements for these can be initiated by generators or customers, or arise as the
result of joint planning with a DNSP or TransGrid TNSP.
Section 12.8 describes dual function replacement projects. This section outlines the dual function asset
replacement projects which Ausgrid is progressing or proposes to progress in the next ten years.
The dual function network constraints detailed in this TAPR 2013 Update report are subject to change in
respect to the number and nature of the constraints and their timing. In some cases changes will occur at
short notice. Changes may be brought about by changes in load growth, new load developments as well as
local generation and demand management developments. In all cases options for the relief of constraints will
be developed and commitments will be made in time to ensure that standards of supply are maintained.
Distribution and Transmission Annual Planning Report December 2013
210
12.6.1 Constraints emerging within 5 years – proposed dual function assets
This section describes constraints that are proposed to be relieved by dual function assets, as tabulated
below.
The proposed dual function assets are tabulated below. Estimated costs are in 2013/14 real dollars.
Constraint Emerging
Load
reduction for
one year
deferral
Region
Refer to
section
Proposed
Augmentation
Sydney
12.6.1.1
Top Ryde ZS
Additional
Transformer
Load
Growth
4.4 MW (3.2
MVA)
Jun -16
$7.7m
Sydney
12.6.1.2
Alexandria
132/33kV STS
Customer
NA
Sep-16
$40.2m
Within 1
year
1 to 3
years
3 to 5
years
Expected
completion
Estimated
cost
Ausgrid conducts a review of feasible options to relieve the emerging network constraint, including nonnetwork solutions such as embedded generation and demand management under our non-network options
screening and consultation process prior to finalising the economic evaluation of options under the regulatory
test7. Currently, a consultation process is carried out for all dual function asset investments over $1 million to
seek responses from non-network solution proponents prior to the finalisation of the regulatory test and
publication of the Final Report. From 1 January 2014 the Regulatory Test will be superseded by the new
Regulatory Investment Test for Distribution (RIT-D). Any economic evaluations commenced under the
Regulatory Test prior to 31 December, 2013 will be finalised under the Regulatory Test, subject to approval
from the Australian Energy Regulator.
Summary information concerning these augmentations follows.
12.6.1.1 Top Ryde ZS additional transformer
In TAPR 2013 it was mentioned that an indicative solution to an expected load growth constraint was an
additional transformer at Top Ryde 132/11kV ZS in September 2020. Substantial development in the
Macquarie Park and North Ryde area is forecast to result in rapid load growth and Macquarie Park 132/11kV
ZS is expected to exceed its licence capacity in 2016/17. Options to address this issue included:

Installation of an additional transformer at Top Ryde ZS and transfer load from Macquarie Park

Load transfers to nearby zone substations

Demand management and/or local generation.
The most likely network option to address the Macquarie Park ZS constraint is the installation of an additional
transformer at Top Ryde ZS by June 2016.
It is anticipated that a Final Report detailing the result of the economic assessment under the Regulatory Test
will be published by June 2014.
12.6.1.2 Alexandria 132/33kV STS
Mascot ZS 11kV switchgear and the Sydney Airport 33kV switchgear and 33kV cables are approaching the
end of their service life and are due for replacement by September 2016.
Replacement options are still under consideration, however the most likely option will be the establishment of
Alexandria STS to create a 33kV supply point close to Sydney Airport and a large data centre nearby supplied
at 33kV. The primary driver for the establishment of Alexandria STS is asset replacement and the
augmentation component to provide additional capacity to new data centres at Green Square and Mascot
required from mid 2014 is estimated to cost less than $10 million.
The options under consideration are:

Refurbish Mascot 33/11kV ZS and establish a new 132/33kV STS at Alexandria

Construct a new Mascot 132/11kV ZS and establish a new 132/33kV STS at Alexandria

Construct a new Mascot 132/11kV ZS and maintain Bunnerong North STS supply
7
The new RIT-D economic assessment and consultation process will apply for all new RIT-D projects commenced after 1
January, 2014.
Distribution and Transmission Annual Planning Report December 2013
211

Refurbish Mascot 33/11kV ZS and maintain Bunnerong North STS supply.
A consultation paper was issued in August 2013. A demand management screening test is currently
underway. If demand management investigations conclude it would be reasonable to expect that a nonnetwork option could defer supply side options, this will be incorporated as part of the assessment of solution
under the relevant economic test. A Final Report will detail the outcomes of the economic assessment and
the preferred solution.
12.6.2 Constraints emerging within 5 years – consultation anticipated within 12 months
This section describes constraints expected to emerge over a five year planning horizon that are proposed to
be relieved by dual function assets which are augmentation proposals, or where application of the new RIT-D
economic evaluation and consultation is anticipated within 12 months. Estimated costs are in real 2013/14
dollars.
Constraint Emerging
Region
Refer to
section
Proposed
Augmentation
Sydney
12.6.2.1
New 132kV
feeder between
Beaconsfield
BSP and
Belmore Park
ZS
Within 1
year
1 to 3
years
3 to 5
years
Load
reduction for
one year
deferral
Expected
completion
-
Nov-15
Network
Capacity
Estimated
cost
$19.0m
A description of these identified constraints and potential credible solutions to them follows.
12.6.2.1 New 132kV feeder between Beaconsfield BSP and Belmore Park
Capacity constraints Sydney CBD network area driven by the de-rating of 9SA and 9SB/1, and exacerbated
by the need to retire 92L and 92M between Lane Cove and Dalley St. The commissioning of circuit 9S4 was
originally intended to allow retirement of 92L and 92M, however due to the reduction in capacity on 9SA and
9SB (as well as other transmission circuits in this corridor) these can no longer be retired as intended. Further
constraints will emerge towards the end of this regulatory period and into the next period as additional cables
reach end-of-life.
9SA and 9SB/1 are aged oil-filled cables, with a recommended replacement date of 2024. Refurbishing the
cable trench backfill to improve ratings will not extend the life of the physical cable itself, and therefore full
remediation will not provide a long-term solution to network capacity in the inner-city area.
Potential credible options to address this issue are currently being assessed under the reliability limb of the
regulatory test. Potential credible options may also include the partial remediation of 132kV feeders 9SA and
9SB/1. If this partial remediation work is included the total estimated cost is $20.9m.
12.6.3 Constraints emerging within 5 years –consultation anticipated beyond 12 months
There are no identified constraints expected to emerge within a five year planning horizon that are proposed to
be relieved by dual function assets where application of the new RIT-D economic evaluation and consultation
is anticipated beyond 12 months.
12.6.4 Longer Term Constraints and Indicative Developments
The following table briefly summarises dual function network constraints that are expected to arise over a time
frame that is longer than 5 years. Estimated costs are in real 2013/14 dollars.
Expected
Completion
Region
Constraint
Indicative Development
Estimated Cost
Sydney
Load Growth
Kingsford ZS Additional Transformer
July-20
$5.4m
Central
Coast
Load Growth
Warnervale 132/11kV ZS
Sep-20
$27.3m
A description of these identified constraints and potential credible solutions to them follows.
Distribution and Transmission Annual Planning Report December 2013
212
12.6.4.1 Warnervale 132/11kV zone substation
Anticipated load growth from the Warnervale Mini City and Wyong Employment Zone initiatives are expected
to result in a load growth constraint in the area. Options to address this issue included:

Development of a new Warnervale 132/11kV ZS by September 2015

Load transfers to nearby Charmhaven ZS

Demand management and/or local generation.
The most likely network option to address the constraint is the development of a new Warnervale 132/11kV
ZS by September 2020.
Potential credible network and non-network options will be assessed under the new RIT-D process to identify
the preferred option to address the identified load growth constraint.
12.6.4.2 Kingsford ZS additional transformer
Initially a new 132/11kV 50MVA transformer will be required to allow for load transfer from Clovelly ZS to
Kingsford ZS. The compound-filled 11kV switchgear at Clovelly ZS requires replacement. Ultimately the
new transformer will be required to provide additional capacity due to load growth in the area. The capacity
of 132kV feeder 265 will also require to be upgraded to avoid a capacity constraint at Kingsford. The
options considered included:

Load transfer permanently to Kingsford ZS, and retire Section 1 of Clovelly 11kV switchgear

Load transfer to Waverley ZS

Load transfer to Kingsford ZS to allow replacement of Section 1 of Clovelly 11kV switchgear.
The most likely network option is to install a new transformer at Kingsford ZS to facilitate the replacement of
11kV switchgear at Clovelly ZS.
Potential credible network and non-network options will be assessed under the new RIT-D process to identify
the preferred option to address the identified load growth constraint.
12.7
Dual Function Connection Points
The NER requires a TNSP to set out planning proposals for dual function connection points.
Ausgrid’s joint planning with customers, TransGrid and other NSPs may involve the establishment of new
connection points. These augmentations are driven by constraints on the distribution network. However, when
the augmentation options are considered in the future, the preferred solution may comprise a mix of dual
function and distribution network augmentations.
Planning of new or augmented connections involves consultation between Ausgrid and the connecting party,
the determination of technical requirements, and the completion of connection agreements. New connections
can result from joint planning with TransGrid, other DNSPs, or be initiated by generators or customers through
the application to connect process.
In the following sections, proposals for augmentations to the capacity of existing dual function connection
points and proposed new connection points that may be provided over the next five years are identified.
12.7.1 Augmentation of existing dual function connection points
Ausgrid has identified constraints to the capacity of existing dual function connection points as tabulated
below.
Region
Refer to
section
Sydney
12.6.1.1
Sydney
12.6.4.2
Proposed solution
Identified limitation
Timing
Top Ryde ZS Additional
Transformer
Load growth
Jun-16
Kingsford ZS Additional
Transformer
Load growth
Mar-17
Distribution and Transmission Annual Planning Report December 2013
213
12.7.2 Proposed new dual function connection points
Ausgrid has identified proposed new dual function network connection points as tabulated below.
12.8
Region
Refer to
section
Proposal
Purpose
Timing
Sydney
12.4.2.1
Belmore Park 132/11kV Zone
Substation
Licence condition N-2 security
standard
Jan-14
Sydney
12.8.1.3
Hurstville North 132kV
Conversion
Replace existing 33kV
(distribution) infrastructure
Feb-14
Sydney
12.8.1.5
Waverley 132kV conversion
Replace existing 33kV
(distribution) infrastructure
Nov-13
Sydney
12.8.1.6
New Rose Bay 132/11kV
Zone Substation
replace the existing Rose Bay
ZS
Mar-14
Sydney
12.8.1.6
Rockdale 132/11kV Zone
Substation
Replace existing 33kV
(distribution) infrastructure
Sep-15
Sydney
12.8.1.7
South Strathfield 132/11kV
Zone Substation (previously
known as Enfield)
Replace existing 33kV
(distribution) infrastructure
Sep-16
Sydney
12.8.10
Alexandria 132/33kV STS
Replace existing 33kV
(distribution) infrastructure
Mar-16
Central Coast
12.6.4.1
Warnervale 132/11kV Zone
Substation
New connection point
Sep-16
Hunter
12.4.2.3
Brandy Hill 132/11kV Zone
Substation
Replace existing 33kV
(distribution) infrastructure
Jan-14
Dual function replacement projects
In addition to developing its dual function network to meet forecast electricity demand, Ausgrid is required to
maintain the capability of its existing network. Ausgrid has developed a long term program of asset
replacement in which condition based monitoring and asset performance data form the basis of an asset
management strategy. The program considers the risk and consequence of failure, asset sustainability,
population size and the availability of technology and spares.
This section outlines the dual function asset replacement projects which Ausgrid is progressing or proposes to
progress in the next ten years. The identification of potential replacement projects does not indicate a supply
reliability risk. Replacement programs are planned a number of years into the future to allow Ausgrid to
schedule works in order for it to continue to provide a reliable electricity supply to customers.
Distribution and Transmission Annual Planning Report December 2013
214
12.8.1 Identified dual function replacement projects
Estimated costs are in real 2013/14 dollars.
Region
Refer to
section
Refurbishment
Timing
Estimated Cost
Sydney
12.8.1.1
Replacement of Kurnell 33/11kV
substation with a new 132/11kV
Substation
Mar-14
$14.8m
Sydney
12.8.1.2
Canterbury STS 132kV Busbar
Replacement and 33kV
Switchgear Replacement
Jan-17
$46.6m
Sydney
12.8.1.3
Replacement of Hurstville North
33/11kV substation with a new
132/11kV Substation
Feb-14
$32.6m
Sydney
12.8.1.4
Peakhurst STS to Bunnerong STS
and Beaconsfield BSP 132kV
Feeders 91L & 91M Replacement
May-14
$209.8m
Sydney
12.8.1.5
Replacement of Waverley ZS with
new 132/11kV Substation
Nov-13
$29.4m
Sydney
12.8.1.6
New Rose Bay 132/11kV Zone
Substation
Mar 14
$98.4m
Sydney
12.8.1.7
Replacement of Rockdale
132/11kV Zone Substation
Sep-15
$32.3m
Sydney
12.8.1.8
Replacement of Enfield 33kV ZS
with new Strathfield South
132/11kV Substation
Sep-16
$33.1m
Sydney
12.8.1.9
Mason Park STS to Meadowbank
ZS 132kV Feeder 90X & Mason
Park STS to Top Ryde Feeder 92F
Replacement
Sep-16
$46.8m
Sydney
12.8.1.10
Beaconsfield BSP132kV Busbar
Replacement – Feeder
Reconnections
Nov-16
$32.9m
Sydney
12.8.1.11
Alexandria 132/33kV STS
Sep-16
$40.2m
Sydney
12.8.1.12
Lane Cove STSS to Meadowbank
ZS 132kV Feeder 92J & Lane
Cove STSS to Top Ryde Feeder
92G Replacement
Sep-19
$50.6m
Sydney
12.8.1.13
Haymarket BSP to Pyrmont STS
132kV Feeders 9S6/1 & 9S9/1
Replacement
Sep 24
$56.9m
Sydney
12.8.1.14
Chullora STS to Beaconsfield BSP
Feeders 91X and 91Y
decomissioning
Mar 23
$1.5m
Sydney
12.8.1.15
Campbell St ZS 132kV additional
transformer
Sep-18
$5.1m
Central Coast
12.8.1.16
Gosford STS Refurbishment
Dec-14
$5.4m
Summary information for the replacement projects not described earlier follows.
Distribution and Transmission Annual Planning Report December 2013
215
12.8.1.1 Replacement of Kurnell with new 132/11kV Substation
Kurnell ZS (distribution asset) was established in 1960 and is currently a five transformer 33/11kV zone
substation. The 11kV switchgear at the existing Kurnell 33/11kV ZS is approaching the end of its service life.
Ausgrid is to replace the existing 33/11kV ZS with a new 132/11kV substation on the Kurnell STS site. The
substation will be connected from the 132kV GIS busbar at Kurnell STS.
No non-network alternatives were considered to be viable alternatives to this project.
This project is committed.
12.8.1.2 Canterbury STS 132kV Busbar Replacement and 33kV Switchgear Replacement
Canterbury STS was established in 1961 and is currently a four transformer 132/33kV sub-transmission
substation.
In TAPR 2013 it was mentioned that the 132kV busbar has been identified as being inadequate to meet
increased fault levels on the sub-transmission system following the completion of proposed new connections
to Beaconsfield BSP and Peakhurst STS. The 33kV switchgear has been identified as approaching the end of
its service life, while the 33kV busbar height does not meet current standards.
Replacement of the 132kV outdoor busbar with indoor GIS to meet increased fault levels and the replacement
of the outdoor 33kV switchgear with an indoor busbar and switchgear are now under a single project.
No non-network alternatives were considered to be viable alternatives to this project.
This project is committed.
12.8.1.3 Replacement of Hurstville North with new 132/11kV Substation
Hurstville North ZS (distribution asset) was established in 1962 and is currently a three transformer 33/11kV
zone substation.
The compound 11kV switchgear and the 33kV gas-filled feeders from Peakhurst STS (774 and 708) have
been identified as approaching the end of their service life and have been prioritised for replacement. In
addition, the 33kV busbar height does not meet current standards.
Ausgrid is to replace the existing 33/11kV ZS with a new 132/11kV substation in the Hurstville area. The
substation will be connected by looping into the new 132kV feeders from Peakhurst STS to Kogarah ZS
(distribution asset). An Application Notice (Development of Hurstville North Zone Substation) was published in
December 2008 outlining the issues and a preliminary application of the regulatory test. The project was
internally approved in April 2010. A Final Report was issued on 30 June 2010.
No non-network alternatives were considered to be viable alternatives to this project.
This project is committed.
12.8.1.4 Peakhurst STS to Bunnerong STS and Beaconsfield BSP 132kV Feeders 91L & 91M
Replacement
The existing 132kV feeders 91L and 91M/1 (Peakhurst STS to Bunnerong STS and Beaconsfield BSP
respectively) and 91M/3 (from Beaconsfield BSP to Bunnerong STS) comprise of oil-filled cables
commissioned in the early 1970’s.
These cables are at the end of their service life and have been prioritised for replacement. They incur
significant maintenance costs as they require extended repair times and specialist cable jointing. In addition,
failure of the cables can lead to oil leaks with the potential for environmental damage.
Ausgrid is to replace 91L and 91M/1 with XLPE cable forming the following 132kV feeders:

From Beaconsfield BSP to Canterbury STS

From Beaconsfield BSP to the future Hurstville North ZS via Kogarah ZS, and

From Canterbury STS to Kogarah ZS

91M/3 between Mill Pond Road and Bunnerong STS will be replaced like-for-like with XLPE cable.
A Final Report (Replacement of 132kV Feeders 91L and 91M Peakhurst to Bunnerong and Beaconsfield) was
issued in May 2010.
These works are planned to be completed by November 2013.
This project is committed.
Distribution and Transmission Annual Planning Report December 2013
216
12.8.1.5 Replacement of Waverley Zone Substation with 132/11kV Substation
In TAPR 2012 it was identified that the existing Waverley 33/11kV ZS (a distribution asset established in 1929)
11kV switchgear needs replacement and that the 33kV supply feeders from Surry Hills STS (390, 391 and
396) are approaching the end of their service life. It was also identified that the most likely option to address
these asset condition issues is to replace the existing Waverley 33/11kV ZS with a new 132/11kV substation,
connected by looping into one of the new committed 132kV feeders from the Sydney CBD area supplying the
new Rose Bay 132/11kV ZS.
Since the project was driven by the replacement of aged assets, rather than demand growth, non-network
options were not considered. As this is a replacement project with no network augmentation component the
publication of a Dual Function Asset Consultation Paper or Final Report was not required.
This is a committed project and the works are planned to be completed by November 2013.
12.8.1.6 New Rose Bay 132/11kV Zone Substation
Previous TAPRs identified that the existing Rose Bay 33/11kV ZS equipment and feeders (distribution assets)
are approaching the end of their service life and that there is an emerging winter load constraint in the Rose
Bay area.
Options considered include:

New 132/11kV Rose Bay zone substation

33kV supply retained for Rose Bay ZS - This option involves the construction of a new substation with
three 33MVA transformers and supplied by dedicated 33kV feeders from Surry Hills STS. Under this
option it is also proposed that Surry Hills ZS be converted to 132kV supply as this driven by loading on
132kV cables to Surry Hills STS.
The preferred option to address these issues was to replace the existing Rose Bay ZS with a new 132/11kV
zone substation. The substation will be connected to new 132kV feeders to be developed from the vicinity of
the Sydney CBD. A consultation process was carried out in accordance with clause 5.6.6 of the NER. As the
total augmentation component of the projects was under $20M, publication of an Application Notice was not
required. A Final Report (Rose Bay 132kV Conversion and Installation of 132kV Feeders) was published in
December 2009.
Since the project was driven by replacement of aged assets, rather than demand growth, non-network options
were not considered.
The preferred and committed project is option 1 - New Rose Bay 132/11kV ZS.
12.8.1.7 Replacement of Rockdale with new 132/11kV Substation
Rockdale ZS (distribution asset) was established in 1971 and is currently a two transformer 33/11kV zone
substation.
The compound 11kV switchgear and the 33kV gas-filled feeders from Peakhurst STS (775 and 776) have
been identified as approaching the end of their service life and have been prioritised for replacement. In
addition, the 33kV busbar height does not meet current standards.
The most likely option is to replace the existing 33/11kV ZS with a new 132/11kV substation in the Rockdale
area. The substation will be connected by looping into the committed new 132kV feeder from Kogarah to
Canterbury.
No non-network options were considered to be viable alternatives to this project.
12.8.1.8 Strathfield South132/11kV Zone Substation
There are emerging asset condition issues in the area. The 11kV compound switchgear at Enfield 33/11kV ZS
is approaching the end of its service life and is prioritised for replacement in the period 2017-19. Several 33kV
gas filled feeders have also been prioritised for replacement in the period 2012-2017.
Potential credible options identified to address this issue include:

A new Strathfield South 132/11kV ZS (previously referred to as Enfield 132/11kV ZS in TAPR 2013)

A new Enfield 33/11kV ZS, and

Demand management and/or local generation.
The most likely network option is to develop a new Enfield 132/11kV ZS replacement asset. Investigation of
non-network options will continue to be pursued. This project is expected to be completed by September
2016.
Distribution and Transmission Annual Planning Report December 2013
217
12.8.1.9 Mason Park STS to Meadowbank ZS 132kV Feeder 90X and Mason Park STS to Top Ryde Feeder
92F Replacement
The 132kV feeder 90X from Mason Park STSS to Meadowbank ZS comprises an oil-filled section made up of
two parallel cables, 90XA and 90XB, of approximately 2km in length which were commissioned in the 1980’s.
The 132kV feeder 92F from Mason Park STSS to Top Ryde ZS comprises an oil-filled section made up of two
parallel cables, 92FA and 92FB, of approximately 4km in length which were commissioned in the 1960’s.
The oil filled cables 92FA, 92FB, 90XA and 9XB have been identified as approaching the end of their service
life.
The most likely option is to replace the oil-filled cable sections with XLPE cable.
12.8.1.10 Beaconsfield BSP 132kV - Ausgrid Feeder Reconnections
TransGrid’s Beaconsfield 330/132kV substation is a major point of supply to Ausgrid for the electricity needs
of the southern and inner metropolitan region of Sydney. TransGrid has determined that the 132kV busbar at
the Beaconsfield BSP has reached the end of its technical life and is due for replacement.
Due to emerging asset condition issues and the need for additional 132kV connections by Ausgrid, TransGrid
is undertaking a project that will replace the existing gas insulated busbar and allow the transfer of existing
Ausgrid cables to a new Southern GIS busbar (BFS) and a new Northern GIS busbar (BFN).
Ausgrid will reconnect 12 existing cables, five to BFS and seven to BFN in two stages, with all works planned
to be completed by December 2015. This is a committed project.
No non-network alternatives were considered to be viable alternatives to this project.
Provision will also be made for the termination of Ausgrid’s new 132kV feeders from Green Square (90T),
Haymarket BSP (9S4), Canterbury STS (906), and Hurstville North ZS (91H/2). The 132kV feeder from Green
Square (90T) is a committed project.
12.8.1.11 Alexandria 132/33kV STS
Mascot ZS 11kV switchgear and the Sydney Airport 33kV switchgear and 33kV cables are approaching the
end of their service life and are due for replacement by September 2016.
Replacement options are still under consideration, however the most likely option will be the establishment of
Alexandria STS to create a 33kV supply point close to Sydney Airport and a large data centre nearby supplied
at 33kV. The primary driver for the establishment of Alexandria STS is asset replacementand the
augmentation component to provide additional capacity to new data centres at Green Square and Mascot
required from mid 2014 is estimated to cost less than $10 million.
The options under consideration are:

Refurbish Mascot 33/11kV ZS and establish a new 132/33kV STS at Alexandria

Construct a new Mascot 132/11kV ZS and establish a new 132/33kV STS at Alexandria

Construct a new Mascot 132/11kV ZS and maintain Bunnerong North STS supply

Refurbish Mascot 33/11kV ZS and maintain Bunnerong North STS supply.
A consultation paper was issued in August 2013. A demand management screening test is currently
underway. If demand management investigations conclude it would be reasonable to expect that a nonnetwork option could defer supply side options, this will be incorporated as part of the assessment of solution
under the relevant economic test. A Final Report will detail the outcomes of the economic assessment and
the preferred solution.
12.8.1.12 Lane Cove STS to Meadowbank ZS 132kV Feeder 92J and Lane Cove STS to Top Ryde 132kV
Feeder 92G Replacement
The 132kV feeder 92J from Lane Cove STS to Meadowbank ZS comprises a section of two parallel oil-filled
underground cables, 92JA and 92JB, approximately 12.9km long which were commissioned in the 1960’s.
The 132kV feeder 92G from Lane Cove STS to Top Ryde ZS comprises a section of two parallel oil-filled
underground cables, 92GA and 92GB, approximately 7.2km long which were commissioned in the 1960’s.
Distribution and Transmission Annual Planning Report December 2013
218
The oil filled cables 92JA, 92JB, 92GA and 92GB have been identified as approaching the end of their service
life. Replacement options are still under consideration, however the most likely option is to replace the oil-filled
cable sections with XLPE cable.
12.8.1.13 Haymarket BSP to Pyrmont STS 132kV Feeders 9S6/1 and 9S9/1 Replacement
The 132kV underground feeders 9S6/1 and 9S9/1 from Haymarket BSP to Pyrmont STS were commissioned
in the 1980’s and comprise an oil-filled section of approximately 2km in length and for the most part are oilfilled cables.
The oil filled cables 9S6/1 and 9S9/1 have been identified as approaching the end of their service life.
Replacement options are still under consideration, however the most likely option is to replace the oil-filled
cable sections with XLPE cable.
12.8.1.14 Chullora STS to Beaconsfield BSP 132kV Feeders 91X and 91Y Replacement
The 132kV feeders 91X and 91Y from Chullora STS to Beaconsfield BSP comprise of two oil-filled
underground cable sections, with one section consisting of two cables 91X/1 and 91X/2, and the other section
consisting of cables 91Y/1 and 91Y/2. Both feeders 91X and 91Y are of approximately 16.2km in length and
were commissioned in the 1970’s.
These cables have been identified as approaching the end of their service life. Replacement options are still
under consideration, however the most likely option is to decommission these cables in March 2023.
12.8.1.15 Campbell Street Additional Transformer
Due to the condition of 33kV feeders 386, 388 & 389 - Surry Hills STS to Darlinghurst ZS, these feeders are
required to be replaced by December 20018. Potential credible replacement solutions include:


decommission Darlinghurst ZS via an 11kV load transfer to Campbell Street ZS / Padington ZS which
requires installation of an additional transformer and 11kV switchgear at Campbell St ZS, and
a like for like feeder replacement at Darlinghurst ZS.
12.8.1.16 Gosford STS 132/66/33kV Substation Refurbishment
Gosford STS was established in 1972 and is currently a four transformer 132/66/33kV sub-transmission
substation.
Most of the steel structures in the Gosford STS yard have been scheduled for replacement. The 132kV, 66kV
and 33kV isolator supports, voltage transformer (VT) and current transformer (CT) supports and lightning
protection mast structures have deteriorated and require replacement. Ausgrid has also scheduled circuit
breakers, CTs, VTs, transformer bushings and some protection equipment at Gosford STS for replacement
due to condition issues.
No non-network alternatives were considered to be viable alternatives to this project.
12.9
Urgent and unforeseen dual function projects
There were no dual function asset RIT-T projects or Regulatory Test projects required to address an urgent or
unforeseen network investment in the preceding year.
12.10 National Transmission Statement
The annual National Transmission Statement (NTS) is the outcome of the Australian Energy Market Operator
(AEMO) annual national transmission review. It provides an integrated overview of the current state and
potential future development of National Transmission Flow Paths (NTFPs).
The NTS includes a review of the:

national transmission flow paths

historical and forecast utilisation and constraints in respect of the national transmission flow paths, and

options that are technically capable of relieving forecast constraints in respect of national transmission
flow paths.
A copy of the annual National Transmission Statement is available on AEMO’s website at www.aemo.com.au
Distribution and Transmission Annual Planning Report December 2013
219
12.10.1 NSW Responsibility
In the NTS, network augmentation proposals by TNSPs that affect NTFPs are taken into account by AEMO in
the development of conceptual augmentation options and market development scenarios.
TransGrid is the Jurisdictional Planning Body (JPB) for NSW in the NEM. In this role TransGrid:

represents the NSW jurisdiction on the Inter-Regional Planning Committee (IRPC), and

provides jurisdictional information to the IRPC to enable it to assist AEMO in producing its annual
Statement of Opportunities (SOO) and NTS.
Accordingly, TransGrid is responsible for providing information concerning transmission developments in NSW
which may affect the power transfer capacity of NTFPs. Further details are available on TransGrid’s website at
www.transgrid.com.au
12.11 Requests for Proposal
The commencement of the NER Network Planning and Expansion Rule on 1 January, 2013 required all
DNSPs to develop and publish a demand side engagement strategy document, and develop and maintain a
demand side register of interested parties by 31 August, 2013. For Ausgrid, these obligations are similar to the
former jurisdictional requirements under the Demand Management Code.
Dual function assets are treated as distribution network assets under the Network Planning and Expansion
rule. Ausgrid is therefore not required to issue Requests for Proposal as our public consultation for nonnetwork solutions such as local generation and demand management is carried out under our demand side
engagement strategy. From 1 January, 2014, the results of non-network option screening tests, including
consultations via Non-network Options Reports or Notices, will also be published on our web site for any
identified network needs that will require a project evaluation and consultation under the RIT-D. More
information on Ausgrid’s demand management activities in the preceding year and planned future activities is
detailed in the DAPR chapter 9 - Demand Management.
Ausgrid publishes all demand management public consultation papers and our Demand Management
Investigation Reports on the Ausgrid web site at www.ausgrid.com.au.
12.12 Demand Forecasts
Ausgrid has made significant process changes to the forecasting methodology – particularly relating to the
probabilistic weather correction and load normalisation, implementation of a new forecasting information
technology platform, and the inclusion of econometric growth data into the spatial forecasts. Ausgrid’s dual
function asset network forecasts are developed in conjunction with the distribution network forecasts. A
description of the forecasting methodology and assumptions used is presented in DAPR section 3.1.
The demand growth figures used in this update to TAPR 2013 are based on Ausgrid loads at Bulk Supply
Points excluding the direct loads of Hydro Aluminium, BHP Billiton and inter-distributor transfers. The peak
demand figures are weather corrected and reflect a 50% probability of exceedance (PoE). On the whole, the
forecasts for demand growth are lower than previous forecasts, continuing a recent trend.
Factors contributing to the lower demand growth include:

a high Australian dollar dampening manufacturing sector

the lingering effects of the Global Financial Crisis

energy efficiency impacts of Government policy in areas such as building construction under the Building
Code of Australia, and electrical appliance Minimum Energy Performance Standards

recent rapid uptake of rooftop Solar PV embedded generation driven by state government incentives - ie
Solar Bonus Scheme, and

recent electricity price rises and the resultant customer response to decrease their demand.
While at the aggregate level the demand growth is lower, the growth rates differ by location with rates ranging
from slightly negative to moderately increasing. Because of this spatial diversity, a requirement for growth
driven investment remains. Summer is confirmed as the dominant season. However, there are still a
significant number of substations and corresponding load areas that peak in winter, or both summer and
winter.
Distribution and Transmission Annual Planning Report December 2013
220
12.12.1 Ausgrid Network Global Peak Demand Forecasts
This section presents forecasts of demand for the Ausgrid network, covering:

Network summer peak demand 50% Probability of Exceedence (PoE) in Mega Watts (MW), and

Network winter peak demand 50% PoE in MW.
Ausgrid network Summer Global Peak Forecast values are illustrated below.
Summer Peak Demand
Actual
Forecast Based on 2012/13 Actual
7000
6000
5000
4000
W
M
3000
2000
1000
0
2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23
Year
TAPR 2013 Update - forecast summer peak demand is based on actual data up to and
including summer 2012/13.
Ausgrid network Winter Global Peak Forecast values are illustrated below.
Winter Peak Demand
Actual
Forecast Based on 2012 Actual
7000
6000
5000
4000
W
M
3000
2000
1000
0
2008
2009
2010
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
Year
TAPR 2013 Update - forecast winter peak demand is based on actual data up to and
including winter 2012.
Distribution and Transmission Annual Planning Report December 2013
221
12.12.2 Dual Function Substation Demand Forecasts
12.12.2.1 Sydney Region Winter Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast winter peak demand (MW and MVAr) based on Winter 2012 actual load is:
Actual
Forecast
2012
MW
Belmore Park ZS
2013
MVAr
MW
2014
MVAr
MW
2015
MVAr
MW
2016
MVAr
MW
2017
MVAr
MW
2018
MVAr
MW
2019
MVAr
MW
2020
MVAr
MW
2021
MVAr
MW
2022
MVAr
MW
2023
MVAr
MW
MVAr
0.0
0.0
0.0
0.0
5.5
1.8
33.8
0.0
51.0
0.0
51.7
0.0
52.2
0.0
52.4
0.0
52.8
0.0
53.1
0.0
53.4
0.0
53.7
17.6
Bunnerong North STS
180.1
2.7
199.4
4.2
184.0
3.5
202.2
0.4
210.6
3.5
212.0
4.0
214.0
4.7
215.7
5.3
217.7
6.0
219.8
6.7
221.9
7.4
224.1
8.2
Campbell St ZS
31.5
10.1
33.4
10.7
33.4
10.7
33.3
10.7
34.4
11.1
35.7
11.5
37.2
12.0
38.7
12.4
40.3
13.0
41.9
13.5
43.7
14.1
45.3
14.6
Canterbury STS
126.3
18.0
132.7
18.6
126.8
15.5
126.3
15.3
127.5
15.9
129.0
16.7
131.2
17.8
133.3
18.8
135.6
19.9
137.9
21.1
140.4
22.4
142.7
23.5
Green Square ZS
27.0
8.8
30.4
9.8
40.0
13.0
39.5
12.8
40.8
13.2
42.3
13.7
44.1
14.3
45.9
14.9
47.8
15.5
49.8
16.1
51.9
16.8
53.8
17.4
Homebush Bay ZS
33.9
6.7
35.9
7.5
42.8
8.9
35.9
7.5
36.3
7.6
36.8
7.7
37.6
7.8
38.3
8.0
39.1
8.1
39.9
8.3
40.8
8.5
41.6
8.7
Hurstville North ZS
0.0
0.0
0.0
0.0
8.8
0.1
16.4
2.6
16.8
2.7
17.3
2.9
17.9
0.1
18.5
0.3
19.1
0.5
19.7
0.7
20.3
0.9
20.9
1.1
Kingsford ZS
42.2
20.4
46.0
22.3
46.5
22.5
46.3
22.4
47.7
23.1
49.3
23.9
51.2
24.8
53.1
25.7
55.1
26.7
57.1
27.7
59.3
28.7
61.2
29.7
Kogarah ZS
58.5
29.0
62.0
30.7
62.0
30.7
62.0
30.7
64.2
31.7
66.5
32.9
69.4
34.3
72.3
35.8
75.4
37.3
78.5
38.8
81.9
40.5
84.9
42.0
Kurnell STS
39.4
18.2
43.3
2.0
32.4
15.0
20.7
9.6
21.4
9.9
22.2
10.3
23.1
10.7
24.0
11.1
25.0
11.6
26.0
12.0
27.1
12.5
28.0
13.0
Kurnell South ZS
0.0
0.0
0.0
0.0
12.6
6.0
24.8
11.8
24.9
11.9
25.0
12.0
25.4
12.1
25.7
12.3
26.0
12.4
26.3
12.5
26.6
12.7
26.9
12.9
Maroubra ZS
46.1
18.1
47.9
18.8
48.8
19.1
48.7
19.0
50.3
19.7
52.2
20.4
54.4
21.2
56.5
22.1
58.8
23.0
61.2
23.9
63.7
24.9
66.0
25.8
Marrickville ZS
50.6
10.8
50.7
10.8
49.2
10.5
47.7
10.2
47.8
10.2
48.2
10.3
48.8
10.5
49.3
10.6
49.9
10.7
50.5
10.8
51.1
10.9
51.7
11.1
Meadowbank ZS
54.7
19.3
53.6
18.9
53.0
18.7
54.1
19.1
54.3
19.2
54.7
19.3
55.4
19.6
56.0
19.8
56.7
20.0
57.3
20.2
58.0
20.5
58.7
20.7
Peakhurst STS
141.8
4.9
152.5
5.4
143.0
2.4
133.4
7.5
134.4
7.8
135.8
0.3
138.2
0.9
140.2
1.5
142.5
2.2
144.8
2.8
147.2
3.5
149.5
4.2
Potts Hill ZS
0.0
0.0
0.0
0.0
55.2
15.0
53.6
14.5
53.9
14.6
54.3
14.7
55.2
15.0
55.8
15.2
56.6
15.3
57.3
15.5
58.1
15.8
58.8
16.0
Rose Bay ZS
14.6
13.4
12.2
13.1
11.9
12.8
7.0
8.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
St Peters ZS
51.9
14.5
54.2
15.2
57.7
16.6
60.3
17.3
62.0
17.8
63.9
18.4
66.4
19.1
68.7
19.7
71.3
20.5
74.0
21.3
76.8
22.1
79.3
22.8
Top Ryde ZS
42.5
8.4
42.4
8.4
43.8
8.7
44.9
8.9
45.1
8.9
45.5
9.0
46.3
9.2
46.9
9.3
47.5
9.4
48.2
9.5
48.9
9.7
49.5
9.8
Waverley ZS
0.0
0.0
0.0
0.0
14.3
3.3
28.1
6.5
28.2
6.5
28.4
6.5
28.7
6.6
29.0
6.7
29.4
6.8
29.7
6.8
30.1
6.9
30.4
7.0
Distribution and Transmission Annual Planning Report December 2013
222
12.12.2.2 Sydney Region Summer Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast summer peak demand (MW and MVAr) based on Summer 2012/13 actual load is:
Actual
2012/13
MW
Belmore Park ZS
MVAr
Forecast
2013/14
MW
MVAr
2014/15
MW
MVAr
2015/16
MW
MVAr
2016/17
MW
MVAr
2017/18
MW
MVAr
2018/19
MW
MVAr
2019/20
MW
MVAr
2020/21
MW
MVAr
2021/22
MW
MVAr
2022/23
MW
MVAr
2023/24
MW
MVAr
0.0
0.0
0.0
0.0
6.7
2.2
41.8
0.0
63.2
0.0
63.7
0.0
63.8
0.0
64.1
0.0
64.5
0.0
64.9
0.0
65.2
0.0
65.6
21.6
Bunnerong North STS
227.4
2.3
221.6
18.1
238.4
6.4
245.4
9.9
246.3
10.3
248.2
11.2
249.7
11.9
251.2
12.7
252.9
13.5
254.6
14.3
256.3
15.2
258.2
16.1
Campbell St ZS
40.6
16.0
41.4
16.3
41.7
16.4
41.9
16.5
43.2
17.0
45.0
17.7
46.6
18.4
48.3
19.0
50.1
19.7
51.9
20.5
53.8
21.2
55.5
21.9
Canterbury STS
128.2
2.1
127.4
1.2
129.8
2.2
130.1
2.3
133.3
3.5
137.5
5.1
141.3
6.6
145.6
8.3
150.1
10.0
154.8
11.8
159.5
13.7
163.8
15.3
Green Square ZS
27.1
21.3
38.2
30.0
42.6
33.4
39.8
31.3
41.7
32.7
44.0
34.6
46.3
36.4
48.6
38.2
51.1
40.1
53.7
42.2
56.4
44.3
58.8
46.2
Homebush Bay ZS
44.2
12.3
51.0
14.2
50.1
13.9
43.9
12.2
44.1
12.2
44.6
12.4
44.9
12.5
45.5
12.6
46.1
12.8
46.8
13.0
47.4
13.2
48.0
13.3
Hurstville North ZS
0.0
0.0
11.2
1.8
20.5
2.8
20.1
2.6
20.2
2.7
20.5
2.8
20.7
2.9
20.9
3.0
21.1
0.1
21.3
0.1
21.5
0.2
21.7
0.3
Kingsford ZS
33.7
16.3
37.0
17.9
37.2
18.0
37.4
18.1
38.5
18.7
40.1
19.4
41.5
20.1
42.9
20.8
44.4
21.5
46.0
22.3
47.5
23.0
48.9
23.7
Kogarah ZS
67.5
32.7
68.8
33.3
68.7
33.3
68.6
33.2
70.3
34.1
72.6
35.2
74.7
36.2
76.9
37.2
79.1
38.3
81.5
39.5
83.8
40.6
86.0
41.6
Kurnell STS
39.9
23.9
31.9
1.1
21.0
12.6
20.5
12.3
20.6
12.3
20.9
12.5
21.0
12.6
21.2
12.7
21.3
12.8
21.5
12.9
21.7
13.0
21.9
13.1
Kurnell South ZS
0.0
0.0
12.3
3.8
24.3
7.5
23.6
7.3
23.5
7.3
23.6
7.3
23.7
7.3
23.7
7.3
23.6
7.3
23.6
7.3
23.6
7.3
23.6
7.3
Maroubra ZS
42.0
14.9
45.1
16.1
44.8
16.0
44.5
15.9
45.4
16.2
46.7
16.6
47.7
17.0
48.9
17.4
50.0
17.9
51.2
18.3
52.4
18.7
53.5
19.1
Marrickville ZS
45.1
19.9
45.8
20.2
44.4
19.6
43.1
19.0
42.9
18.9
43.0
19.0
43.0
19.0
42.9
18.9
42.9
18.9
42.8
18.9
42.8
18.9
42.8
18.9
Meadowbank ZS
63.0
20.5
71.0
23.1
74.6
24.3
75.2
24.5
77.7
25.3
81.0
26.4
84.1
27.4
87.3
28.4
90.6
29.5
94.0
30.6
97.5
31.7
100.7
32.8
Peakhurst STS
157.4
28.1
161.5
15.2
155.0
12.4
155.3
12.5
159.6
14.3
165.5
16.8
170.9
19.0
176.4
21.3
182.3
23.7
188.4
26.3
194.7
28.9
200.3
31.2
Potts Hill ZS
0.0
0.0
61.0
24.6
59.8
24.2
58.7
23.7
59.1
23.9
59.9
24.2
60.5
24.5
61.2
24.7
61.9
25.0
62.6
25.3
63.2
25.5
63.9
25.8
Rose Bay ZS
10.1
4.9
10.9
4.8
10.7
4.8
6.8
2.8
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
St Peters ZS
61.6
23.8
67.4
26.4
69.9
27.4
69.4
27.2
70.7
27.7
72.6
28.4
74.2
29.1
76.1
29.8
78.1
30.6
80.1
31.4
82.2
32.2
84.0
32.9
Top Ryde ZS
52.9
16.4
53.7
16.6
56.1
17.3
57.6
17.8
59.3
18.3
61.5
19.0
63.6
19.7
65.6
20.3
67.6
20.9
69.8
21.6
72.0
22.3
74.0
22.9
Waverley ZS
0.0
0.0
10.5
3.7
20.8
7.4
20.5
7.3
20.7
7.3
21.1
7.5
21.4
7.6
21.7
7.7
22.1
7.8
22.4
7.9
22.7
8.0
23.0
8.1
Distribution and Transmission Annual Planning Report December 2013
223
12.12.2.3 Central Coast Region Winter Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast winter peak demand (MW and MVAr) based on Winter 2012 actual load is:
Actual
Forecast
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
Charmhaven ZS
33.7
6.8
33.4
6.8
29.4
6.0
28.6
5.9
29.0
5.9
29.4
6.0
29.8
6.1
30.3
6.2
30.8
6.3
31.3
6.4
31.9
6.5
32.4
6.6
Gosford STS (33kV)
20.1
4.3
20.6
4.3
20.3
4.2
20.0
4.1
20.5
4.2
21.0
4.3
21.4
4.4
22.0
4.6
22.6
4.7
23.2
4.8
23.9
4.9
24.5
5.1
Gosford STS (66kV)
114.0
22.0
116.4
2.6
114.5
2.1
112.6
1.6
115.2
2.3
117.9
3.0
120.4
3.7
123.5
4.6
126.8
5.5
130.1
6.4
133.7
7.4
137.1
8.4
Ourimbah STS (33kV)
13.1
3.2
13.6
3.3
15.2
3.7
15.1
3.7
15.5
3.8
16.0
3.9
16.4
4.0
16.9
4.1
17.4
4.2
18.0
4.4
18.6
4.5
19.1
4.6
Ourimbah STS (66kV)
43.7
28.0
46.7
27.8
46.4
27.6
46.0
27.3
47.2
28.0
48.4
28.7
49.5
29.4
50.9
30.2
52.4
31.1
53.9
32.0
55.5
32.9
57.0
33.8
Somersby ZS
15.1
6.2
18.1
7.4
16.9
7.0
16.7
6.8
17.1
7.0
17.5
7.2
17.8
7.3
18.3
7.5
18.8
7.7
19.3
7.9
19.8
8.1
20.3
8.3
West Gosford ZS
37.5
9.4
41.6
1.4
42.1
1.6
40.8
1.2
41.2
1.3
41.6
1.4
41.9
1.5
42.4
1.6
42.9
1.8
43.4
1.9
44.0
2.0
44.6
2.2
Wyong ZS
29.9
7.5
33.0
8.3
32.0
8.0
31.1
7.8
31.3
7.8
31.6
7.9
31.8
8.0
32.1
8.0
32.5
8.1
32.9
8.2
33.3
8.3
33.8
8.5
12.12.2.4 Central Coast Region Summer Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast summer peak demand (MW and MVAr) based on Summer 2012/13 actual load is:
Actual
2012/13
Forecast
2013/14
2014/15
2015/16
2016/17
2017/18
2018/19
2019/20
2020/21
2021/22
2022/23
2023/24
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
Charmhaven ZS
45.1
15.8
38.8
13.5
34.9
12.2
34.7
12.1
35.5
12.4
36.1
12.6
36.8
12.8
37.7
13.1
38.6
13.5
39.5
13.8
40.5
14.1
41.4
14.5
Gosford STS (33kV)
26.6
11.7
22.0
11.8
22.2
11.9
22.4
12.0
23.1
12.4
23.7
12.8
24.3
13.1
25.2
13.6
26.2
14.1
27.2
14.7
28.3
15.3
29.3
15.8
Gosford STS (66kV)
135.0
56.0
125.7
12.4
126.2
12.7
126.7
12.8
130.5
14.4
134.0
15.9
137.8
17.4
142.2
19.3
146.8
1.5
151.7
3.6
156.8
5.7
161.4
7.6
Ourimbah STS (33kV)
14.1
5.4
14.7
5.7
16.3
6.3
16.3
6.2
16.5
6.3
16.8
6.4
17.0
6.5
17.4
6.7
17.7
6.8
18.1
6.9
18.4
7.1
18.8
7.2
Ourimbah STS (66kV)
52.0
32.5
40.0
32.4
39.9
32.3
39.7
32.2
40.4
32.8
41.0
33.3
41.6
33.8
42.4
34.5
43.3
35.2
44.2
35.9
45.1
36.6
46.0
37.4
Somersby ZS
16.0
6.3
17.4
6.9
15.9
6.3
15.4
6.1
15.3
6.1
15.2
6.0
15.1
5.9
15.0
5.9
15.0
5.9
14.9
5.9
14.9
5.9
14.9
5.9
West Gosford ZS
46.1
22.3
47.1
25.9
45.7
25.1
44.2
24.3
44.0
24.2
43.6
24.0
43.3
23.8
43.2
23.8
43.1
23.7
43.0
23.6
42.9
23.6
42.9
23.6
Wyong ZS
34.0
11.2
33.9
11.1
32.8
10.8
32.8
10.8
32.5
10.7
32.2
10.6
31.9
10.5
31.8
10.4
31.7
10.4
31.6
10.4
31.5
10.4
31.6
10.4
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12.12.2.5 Hunter Region Winter Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast winter peak demand (MW and MVAr) based on Winter 2012 actual load is:
Actual
Forecast
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
Kurri 132kV ZS
20.1
5.9
18.7
1.9
18.7
1.9
18.6
1.9
19.2
2.2
19.7
2.6
20.3
2.9
21.1
0.4
21.9
0.8
22.7
1.3
23.5
1.8
24.3
2.3
Kurri STS
88.8
23.9
98.7
26.6
98.1
26.4
97.3
26.2
98.8
26.6
100.4
27.0
102.4
27.6
104.7
28.2
107.2
28.9
109.7
29.5
112.4
30.3
115.0
31.0
Muswellbrook STS
17.9
5.0
16.0
4.7
12.6
3.7
12.3
3.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Mitchell Line STS
61.2
23.4
61.4
23.7
64.7
25.0
65.0
25.1
65.3
25.2
65.6
25.3
66.2
25.5
66.9
25.8
67.5
26.0
68.3
26.3
69.1
26.6
69.8
26.9
Singleton STS
135.0
31.8
138.1
33.0
141.5
34.3
170.0
44.8
170.3
44.9
170.6
45.0
171.3
45.3
172.0
45.5
172.7
45.8
173.5
46.1
174.3
46.4
175.3
46.7
Brandy Hill 132kV ZS
0.0
0.0
1.5
0.4
2.4
0.6
9.6
3.3
9.8
3.4
9.9
3.4
10.2
3.5
10.4
3.6
10.7
3.7
10.9
3.8
11.2
3.9
11.5
4.0
Rothbury ZS
6.1
0.0
8.4
0.5
9.3
0.6
9.2
0.6
9.5
0.6
9.8
0.7
10.1
0.7
10.4
0.7
10.8
0.7
11.2
0.7
11.6
0.8
11.9
0.8
12.12.2.6 Hunter Region Summer Peak Demands
The following Ausgrid 132kV substations are classified as dual function network assets. Their forecast summer peak demand (MW and MVAr) based on Summer 2012/13 actual load is:
Actual
2012/13
Forecast
2013/14
2014/15
2015/16
2016/17
2017/18
2018/19
2019/20
2020/21
2021/22
2022/23
2023/24
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
MW
MVAr
Kurri 132kV ZS
27.3
7.5
27.3
1.4
27.6
1.5
27.9
1.6
28.5
1.8
29.3
2.1
30.1
2.5
31.1
2.8
32.2
0.2
33.3
0.7
34.4
1.1
35.5
1.5
Kurri STS
124.2
9.6
136.9
10.6
136.9
10.6
136.9
10.6
138.4
10.7
140.7
10.9
143.3
11.1
146.3
11.4
149.5
11.6
152.9
11.9
156.4
12.1
159.7
12.4
Muswellbrook STS
22.1
5.3
20.0
4.3
19.5
4.2
19.4
4.2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Mitchell Line STS
73.9
30.6
80.7
32.0
81.8
32.5
81.8
32.5
82.1
32.6
82.9
32.9
83.6
33.2
84.5
33.6
85.4
34.0
86.5
34.4
87.5
34.8
88.5
35.2
Singleton STS
145.4
47.8
137.9
45.3
151.3
51.4
169.8
59.8
170.4
60.0
171.4
60.5
172.3
60.9
173.5
61.4
174.6
62.0
175.9
62.5
177.2
63.1
178.5
63.7
Brandy Hill 132kV ZS
0.0
0.0
0.9
0.3
8.1
3.3
8.1
3.3
8.2
3.4
8.4
3.4
8.6
3.5
8.8
3.6
9.1
3.7
9.3
3.8
9.5
3.9
9.8
4.0
Rothbury ZS
10.1
2.6
14.8
4.1
14.7
4.1
14.7
4.1
14.9
4.1
15.1
4.2
15.4
4.3
15.7
4.4
16.0
4.5
16.4
4.5
16.7
4.6
17.1
4.7
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13
Appendix 1 - Glossary
Primary distribution feeder
Distribution line connecting a sub-transmission asset to either other
distribution lines that are not sub-transmission lines, or to distribution
assets that are not sub-transmission assets
Sub-transmission
Any part of the power system which operates to deliver electricity from the
higher voltage transmission system to the distribution network and which
may form part of the distribution network, including zone substations
NER
National Electricity Rules
AER
Australian Energy Regulator
AEMC
The Australian Energy Market Commission is the rule maker and developer
for Australian energy markets
DNSP
A Distribution Network Service Provider who engages in the activity of
owning, controlling, or operating a distribution system, such as Endeavour
Energy, Ausgrid and Essential Energy
DAPR
Distribution Annual Planning Report prepared by a Distribution Network
Service Provider under National Electricity Rules clause 5.13.2
V volt
A volt is the unit of potential or electrical pressure
W watt
A measurement of the power present when a current of one ampere flows
under a potential of one volt
kW kilowatt
One kW = 1000 watts
KWh kilowatt hour
The standard unit of energy which represents the consumption of electrical
energy at the rate of one kilowatt for one hour
kV kilovolt
One kV = 1000 volts
MW megawatt
One MW = 1000 kW or one million watts
MWh megawatt hour
One MWh = 1000 kilowatt hours
GWh gigawatt hour
One GWh = 1000 megawatt hours or one million kilowatt hours
GJ gigajoule
One gigajoule = 1000 megajoules. A joule is the basic unit of energy used
in the gas industry equal to the work done when a current of one ampere is
passed through a resistance of one ohm for one second
Sub-transmission system
Consists of 132kV, 66kV and 33kV assets, including dual function assets
HV high voltage
Consists of 11kV and 22kV distribution assets
LV low voltage
Consists of 400V and 230V distribution assets
TNSP
Transmission Network Service Provider
pf
Power Factor
RIT-D
Regulatory Investment Test for Distribution
Dual function asset
Any part of a network owned, operated or controlled by a Distribution
Network Service Provider which operates between 66kV and 220kV and
which operates in parallel, and provides support, to the higher voltage
transmission network and is an asset which forms part of a network that is
predominantly a distribution network
STPIS
Service Target Performance Incentive Scheme
SAIDI
System Average Interruption Duration Index
SAIFI
System Average Interruption Frequency Index
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14
Appendix 2 - Design, Reliability & Performance
Licence Condition Criteria
Design, Reliability
and Performance
licence conditions:
Network Element
Load Type
CBD
Sub-transmission
Line
Sub-transmission
Substation
Zone Substation
Distribution Feeder
Distribution
Substation
1
Urban & NonUrban
Urban & NonUrban
Forecast
Demand or
Expected
Demand
Security
Standard
Customer Interruption Time
Any
N-26
Nil for 1st credible contingency
< 1hr for 2nd credible contingency
≥ 10 MVA
N-11
< 1 minute
< 10 MVA
N2
Best practice repair time
CBD
Any
N-26
Nil for 1st credible contingency
< 1hr for 2nd credible contingency
Urban & NonUrban
Any
N-1
< 1 minute
CBD
Any
N-26
Nil for 1st credible contingency
< 1hr for 2nd credible contingency
≥ 10 MVA
N-11
< 1 minute
< 10 MVA
N2
Best practice repair time
Any
Any
Any
Any
N-13
N-14
N
N-13
Nil
< 4 Hours5
Best practice repair time
Nil
Any
N7
Best practice repair time
Urban & NonUrban
Urban & NonUrban
CBD
Urban
Non-Urban
CBD1
Urban & NonUrban
For a Sub-transmission line – Overhead and Zone substation:
(a)
under N-1 conditions, the forecast demand is not to exceed the thermal capacity for more than 1% of the
time i.e. a total aggregate time of 88 hours per annum, up to a maximum of 20% above the thermal
capacity under N-1 conditions.
(b)
under N conditions, a further criterion is that the thermal capacity is required to meet at least 115% of
forecast demand.
For a Sub-transmission line – Underground, any overhead section may be designed as if it was a Subtransmission line – Overhead, providing the forecast demand does not exceed the thermal capacity of the
underground section at any time under N-1 conditions.
2
Under N conditions, thermal capacity is to be provided for greater than 115% of forecast demand.
3
The actual security standard is an enhanced N-1. For a second coincident credible contingency on the CBD
triplex system, restricted essential load can still be supplied.
4
By 30 June 2014, expected demand is to be no more than 80% of feeder thermal capacity (under system
normal operating conditions) with switchable interconnection to adjacent feeders enabling restoration for an
unplanned network element failure. By 30 June 2019, expected demand is to be no more than 75% of feeder
thermal capacity. In order to achieve compliance, feeder reinforcement projects may need to be undertaken
over more than one regulatory period. In those cases where a number of feeders form an interrelated system
(such as a meshed network), the limits apply to the average loading of the feeders within one system.
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5
The timeframe is expected only, and is based on the need to carry out the isolation and restoration switching
referred to in note 4. This standard does not apply to interim / staged supplies, i.e. prior to completion of the
entire development or to excluded interruptions outside the control of the licence holder.
6
In the CBD area, N-2 equivalent is achieved by the network being normally configured on the basis of N-1 with
no interruption of supply when any one line or item of electrical apparatus within a substation is out of service.
The licence holder must plan the CBD network to cater for two credible contingencies involving the loss of
multiple lines or items of electrical apparatus within a substation, by being able to restore supply within 1 hour.
Restoration may be via alternative arrangements (e.g. 11kV interconnections).
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