Distribution and Transmission Annual Planning ReportDecember 2016

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Disclaimer

Ausgrid is registered as both a Distribution Network Service Provider and a Transmission Network Service Provider. This Distribution and Transmission Annual Planning Report 2016 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.

DOCUMENT AND AMENDMENT HISTORY

Issue No.

Date Approved by Summary of Changes

1 December 2016 GM - Asset Management (Acting)

Initial Issue

Contact

For all enquiries regarding the Distribution and Transmission Annual Planning Report 2015 and for making written submissions contact:

Ausgrid Manager – Network Risk and Planning GPO Box 4009 Sydney NSW 2001 Email: mwebb@ausgrid.com.au

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Contents

1 EXECUTIVE SUMMARY ............................................................................................................................ 8

2 INTRODUCTION ........................................................................................................................................ 9 2.1 About Ausgrid ................................................................................................................................. 9

2.1.1 Our purpose and vision ............................................................................................................10 2.1.2 Our principal activities ..............................................................................................................10 2.1.3 Our operating environment .......................................................................................................10 2.1.4 Ausgrid customer, demand and energy supply statistics ..........................................................11

2.2 Ausgrid’s network ...........................................................................................................................12 2.2.1 Number and types of network assets .......................................................................................12

2.3 Annual planning review ..................................................................................................................14 2.3.1 Distribution ...............................................................................................................................14 2.3.2 Transmission ............................................................................................................................14 2.3.3 Distribution and Transmission Annual Planning Review and Reporting ...................................14

2.4 Ausgrid’s planning approach ..........................................................................................................14 2.4.1 Investment objectives and decision criteria ..............................................................................14 2.4.2 Network planning process ........................................................................................................15 2.4.3 Network area plans ..................................................................................................................16

2.5 Significant changes from previous DTAPR ....................................................................................17

3 FORECASTS FOR THE FORWARD PLANNING PERIOD .......................................................................18 3.1 Zone and subtransmission substation load forecasting methodology ............................................18

3.1.1 Near term component of forecast .............................................................................................18 3.1.2 Medium to long term component of forecast ............................................................................18 3.1.3 Assumptions applied to substation load forecasts ....................................................................19 3.1.4 Explanation of substation forecast outcomes ...........................................................................21

3.2 Transmission - distribution connection point load forecasts ...........................................................21 3.3 Sub-transmission feeder load forecasts .........................................................................................22 3.4 Primary distribution feeder load forecasts ......................................................................................22

3.4.1 Notes on STS and ZS load forecast tables ..............................................................................22 3.4.2 Notes on identified system limitations ......................................................................................23

3.5 Other factors having a material impact on the network ..................................................................23 3.5.1 Fault levels ...............................................................................................................................23 3.5.2 Voltage levels ...........................................................................................................................24 3.5.3 Other power system security requirements ..............................................................................24 3.5.4 Quality of supply .......................................................................................................................24 3.5.5 Embedded generation ..............................................................................................................24

3.6 Additional notes .............................................................................................................................25 3.6.1 National Transmission Network Development Plan ..................................................................25 3.6.2 Requests for proposal ..............................................................................................................25

4 DISTRIBUTION LOAD AREAS ..................................................................................................................26 4.1 Camperdown and Blackwattle Bay load area.................................................................................26

4.1.1 Description of Camperdown and Blackwattle Bay load area ....................................................26 4.1.2 STS and ZS load forecast ........................................................................................................27 4.1.3 Sub-transmission feeder load forecast .....................................................................................27 4.1.4 Identified system limitations......................................................................................................27 4.1.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................27

4.2 Canterbury Bankstown load area ...................................................................................................28 4.2.1 Description of Canterbury Bankstown load area ......................................................................28 4.2.2 STS and ZS load forecast ........................................................................................................28 4.2.3 Sub-transmission feeder load forecast .....................................................................................28 4.2.4 Identified system limitations......................................................................................................28 4.2.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................31

4.3 Carlingford load area .....................................................................................................................31 4.3.1 Description of Carlingford load area .........................................................................................31 4.3.2 STS and ZS load forecast ........................................................................................................32 4.3.3 Sub-transmission feeder load forecast .....................................................................................32 4.3.4 Identified system limitations......................................................................................................32 4.3.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................32

4.4 Eastern Suburbs load area ............................................................................................................33 4.4.1 Description of Eastern Suburbs load area ................................................................................33

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4.4.2 STS and ZS load forecast ........................................................................................................33 4.4.3 Sub-transmission feeder load forecast .....................................................................................34 4.4.4 Identified system limitations......................................................................................................34 4.4.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................37

4.5 Greater Cessnock load area ..........................................................................................................37 4.5.1 Description of Greater Cessnock load area ..............................................................................37 4.5.2 STS and ZS load forecast ........................................................................................................38 4.5.3 Sub-transmission feeder load forecast .....................................................................................38 4.5.4 Identified system limitations......................................................................................................38 4.5.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................38

4.6 Inner West load area ......................................................................................................................39 4.6.1 Description of Inner West load area .........................................................................................39 4.6.2 STS and ZS load forecast ........................................................................................................39 4.6.3 Sub-transmission feeder load forecast .....................................................................................39 4.6.4 Identified system limitations......................................................................................................40 4.6.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................41

4.7 Lower Central Coast load area ......................................................................................................41 4.7.1 Description of Lower Central Coast load area ..........................................................................41 4.7.2 STS and ZS load forecast ........................................................................................................42 4.7.3 Sub-transmission feeder load forecast .....................................................................................42 4.7.4 Identified system limitations......................................................................................................42 4.7.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................42

4.8 Lower North Shore load area .........................................................................................................43 4.8.1 Description of Lower North Shore load area ............................................................................43 4.8.2 STS and ZS load forecast ........................................................................................................44 4.8.3 Sub-transmission feeder load forecast .....................................................................................44 4.8.4 Identified system limitations......................................................................................................44 4.8.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................45

4.9 Maitland load area .........................................................................................................................45 4.9.1 Description of Maitland load area .............................................................................................45 4.9.2 STS and ZS load forecast ........................................................................................................46 4.9.3 Sub-transmission feeder load forecast .....................................................................................46 4.9.4 Identified system limitations......................................................................................................46 4.9.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................46

4.10 Manly Warringah load area ............................................................................................................47 4.10.1 Manly Warringah load area ......................................................................................................47 4.10.2 STS and ZS load forecast ........................................................................................................47 4.10.3 Sub-transmission feeder load forecast .....................................................................................47 4.10.4 Identified system limitations......................................................................................................47 4.10.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................48

4.11 Newcastle Inner City load area ......................................................................................................48 4.11.1 Newcastle Inner City load area .................................................................................................48 4.11.2 STS and ZS load forecast ........................................................................................................49 4.11.3 Sub-transmission feeder load forecast .....................................................................................49 4.11.4 Identified system limitations......................................................................................................49 4.11.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................50

4.12 Newcastle Ports load area .............................................................................................................50 4.12.1 Description of Newcastle Ports load area .................................................................................50 4.12.2 STS and ZS load forecast ........................................................................................................51 4.12.3 Sub-transmission feeder load forecast .....................................................................................51 4.12.4 Identified system limitations......................................................................................................51 4.12.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................51

4.13 Newcastle Western Corridor load area ..........................................................................................52 4.13.1 Description of Newcastle Western Corridor load area ..............................................................52 4.13.2 STS and ZS load forecast ........................................................................................................52 4.13.3 Sub-transmission feeder load forecast .....................................................................................52 4.13.4 Identified system limitations......................................................................................................52

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4.13.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................53

4.14 North East Lake Macquarie load area ............................................................................................53 4.14.1 Description of North East Lake Macquarie load area ...............................................................53 4.14.2 STS and ZS load forecast ........................................................................................................54 4.14.3 Sub-transmission feeder load forecast .....................................................................................54 4.14.4 Identified system limitations......................................................................................................54 4.14.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................55

4.15 North West Sydney load area ........................................................................................................55 4.15.1 Description of North West Sydney load area ............................................................................55 4.15.2 STS and ZS load forecast ........................................................................................................56 4.15.3 Sub-transmission feeder load forecast .....................................................................................56 4.15.4 Identified system limitations......................................................................................................56 4.15.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................56

4.16 Pittwater and Terrey Hills load area ...............................................................................................56 4.16.1 Description of Pittwater and Terrey Hills load area ...................................................................57 4.16.2 STS and ZS load forecast ........................................................................................................57 4.16.3 Sub-transmission feeder load forecast .....................................................................................57 4.16.4 Identified system limitations......................................................................................................57 4.16.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................58

4.17 Port Stephens load area ................................................................................................................58 4.17.1 Description of Port Stephens load area ....................................................................................58 4.17.2 STS and ZS load forecast ........................................................................................................59 4.17.3 Sub-transmission feeder load forecast .....................................................................................59 4.17.4 Identified system limitations......................................................................................................59 4.17.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................60

4.18 Singleton Load load area ...............................................................................................................60 4.18.1 Description of Singleton load area ............................................................................................60 4.18.2 STS and ZS load forecast ........................................................................................................61 4.18.3 Sub-transmission feeder load forecast .....................................................................................61 4.18.4 Identified system limitations......................................................................................................61 4.18.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................62

4.19 St George load area .......................................................................................................................62 4.19.1 Description of St George load area ..........................................................................................62 4.19.2 STS and ZS load forecast ........................................................................................................63 4.19.3 Sub-transmission feeder load forecast .....................................................................................63 4.19.4 Identified system limitations......................................................................................................63 4.19.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................64

4.20 Sutherland load area ......................................................................................................................64 4.20.1 Description of Sutherland load area .........................................................................................64 4.20.2 STS and ZS load forecast ........................................................................................................65 4.20.3 Sub-transmission feeder load forecast .....................................................................................65 4.20.4 Identified system limitations......................................................................................................65 4.20.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................66

4.21 Sydney CBD Load Area .................................................................................................................66 4.21.1 Description of Sydney CBD load area ......................................................................................66 4.21.2 STS and ZS load forecast ........................................................................................................67 4.21.3 Sub-transmission feeder load forecast .....................................................................................67 4.21.4 Identified system limitations......................................................................................................67 4.21.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................68

4.22 Upper Central Coast load area ......................................................................................................68 4.22.1 Description of Upper Central Coast load area ..........................................................................68 4.22.2 STS and ZS load forecast ........................................................................................................69 4.22.3 Sub-transmission feeder load forecast .....................................................................................69 4.22.4 Identified system limitations......................................................................................................69 4.22.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................69

4.23 Upper Hunter load area .................................................................................................................69 4.23.1 Description of Upper Hunter load area .....................................................................................70

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4.23.2 STS and ZS load forecast ........................................................................................................70 4.23.3 Sub-transmission feeder load forecast .....................................................................................70 4.23.4 Identified system limitations......................................................................................................71 4.23.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................72

4.24 Upper North Shore load area .........................................................................................................72 4.24.1 Description of Upper North Shore load area ............................................................................72 4.24.2 STS and ZS load forecast ........................................................................................................73 4.24.3 Sub-transmission feeder load forecast .....................................................................................73 4.24.4 Identified system limitations......................................................................................................73 4.24.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................73

4.25 West Lake Macquarie load area ....................................................................................................73 4.25.1 Description of West Lake Macquarie load area ........................................................................74 4.25.2 STS and ZS load forecast ........................................................................................................74 4.25.3 Sub-transmission feeder load forecast .....................................................................................75 4.25.4 Identified system limitations......................................................................................................75 4.25.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects .................................................................................................................................................75

4.26 Primary distribution feeder limitations ............................................................................................75

5 TRANSMISSION LOAD AREAS ................................................................................................................76 5.1 Preliminary notes ...........................................................................................................................76

5.1.1 Changes in dual function asset status ......................................................................................76 5.1.2 Dual function connection points................................................................................................76 5.1.3 Inter-Network Impact ................................................................................................................76

5.2 Ausgrid System Total Maximum Demand Forecasts .....................................................................76 5.2.1 Dual function substation demand forecasts ..............................................................................78

5.3 Transmission load area - Central Coast .........................................................................................82 5.3.1 Description of Central Coast transmission load area ................................................................82 5.3.2 Sub-transmission feeder load forecast .....................................................................................83 5.3.3 STS and ZS load forecast ........................................................................................................83 5.3.4 Identified system limitations......................................................................................................83 5.3.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects83 5.3.6 Changes in dual function asset status ......................................................................................84 5.3.7 Dual function connection points................................................................................................84

5.4 Transmission load area – Lower Hunter ........................................................................................84 5.4.1 Description of Lower Hunter 132kV transmission load area .....................................................84 5.4.2 Sub-transmission feeder load forecast .....................................................................................85 5.4.3 STS and ZS load forecast ........................................................................................................85 5.4.4 Identified system limitations......................................................................................................86 5.4.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects86 5.4.6 Changes in dual function asset status ......................................................................................87 5.4.7 Dual function connection points................................................................................................87

5.5 Sydney Inner Metropolitan transmission load area ........................................................................87 5.5.1 Description of Sydney Inner Metropolitan transmission load area ............................................87 5.5.2 Sub-transmission feeder load forecast .....................................................................................90 5.5.3 STS and ZS load forecast ........................................................................................................90 5.5.4 Identified system limitations......................................................................................................90 5.5.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects93 5.5.6 Changes in dual function asset status ......................................................................................94 5.5.7 Dual function connection points................................................................................................94

6 PLANNING PROPOSALS FOR FUTURE NEEDS ....................................................................................95 6.1 Proposed future transmission-distribution connection points .........................................................95 6.2 Proposed future sub-transmission STS and zone substations .......................................................95 6.3 Proposed future sub-transmission lines .........................................................................................95

6.3.1 Changes to proposed future sub-transmission feeders ............................................................96 6.4 Future sub-transmission and zone substations loading levels .......................................................96

6.4.1 Proposed future sub-transmission substation loading levels ....................................................96 6.5 Proposed future dual function connection points ...........................................................................97

7 NETWORK INVESTMENTS ......................................................................................................................98 7.1 Regulatory investment tests ...........................................................................................................98

7.1.1 completed during the year ........................................................................................................98 7.1.2 in progress during the year .......................................................................................................98 7.1.3 For the forward planning period - Distribution ..........................................................................99

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7.1.4 For the forward planning period – Dual Function......................................................................99 7.1.5 Not proceeding .......................................................................................................................100 7.1.6 For previously planned augmentations ...................................................................................101 7.1.7 Proposed dual function replacement projects.........................................................................101

7.2 Completed or cancelled investments ...........................................................................................106 7.2.1 Refurbishment and replacement - Distribution .......................................................................106 7.2.2 Refurbishment and replacement – Dual Function ..................................................................108 7.2.3 Augmentations – Dual Function .............................................................................................108

7.3 Commited investments - ..............................................................................................................108 7.3.1 Refurbishment and replacement investments - Distribution ...................................................108 7.3.2 Refurbishment and replacement investments – Dual function ...............................................112 7.3.3 Committed dual function augmentations ................................................................................115

7.4 Urgent and unforseen investments ..............................................................................................116

8 JOINT PLANNING ...................................................................................................................................117 8.1 Joint planning with TransGrid TNSP ............................................................................................117

8.1.1 Process and methodology ......................................................................................................117 8.1.2 Joint TransGrid - Ausgrid planning completed in 2016 ...........................................................118 8.1.3 Planned joint TransGrid-Ausgrid network investments ...........................................................119

8.2 Joint planning with other DNSPs ..................................................................................................120 8.2.1 Process and methodology ......................................................................................................120 8.2.2 Joint Ausgrid and other DNSP planning completed in preceding year ...................................120 8.2.3 Planned DNSP joint network investments ..............................................................................120 8.2.4 Additional information .............................................................................................................120

9 NETWORK PERFORMANCE ..................................................................................................................121 9.1 Reliability measures and standards .............................................................................................121

9.1.1 Supply reliability standards .....................................................................................................121 9.1.2 Supply reliability in the preceding year ...................................................................................122 9.1.3 Service Target Performance Incentive Scheme (STPIS) .......................................................123 9.1.4 Forecast of network reliability performance ............................................................................124 9.1.5 Compliance with network reliability standards ........................................................................125

9.2 Quality of supply standards ..........................................................................................................125 9.2.1 Voltage range for supplied electricity ......................................................................................126 9.2.2 Harmonics and total harmonic distortion ................................................................................126 9.2.3 Voltage fluctuations (Flicker) – Applicable quality of supply codes, standards and guidelines127 9.2.4 Voltage unbalance – Applicable quality of supply codes, standards and guidelines ..............127

9.3 Quality of supply performance for preceding year ........................................................................127 9.3.1 Supply voltage performance ...................................................................................................128 9.3.2 Harmonic content of supply voltage waveform .......................................................................128 9.3.3 Voltage fluctuations (Flicker) performance .............................................................................128 9.3.4 Voltage unbalance performance.............................................................................................129

9.4 Corrective action planned to meet quality of supply standards ....................................................129 9.4.1 Supply voltage ........................................................................................................................129 9.4.2 Harmonics ..............................................................................................................................129 9.4.3 Flicker .....................................................................................................................................129

9.5 Compliance with quality of supply standards ...............................................................................129

10 ASSET MANAGEMENT...........................................................................................................................131 10.1 Ausgrid’s asset management approach .......................................................................................131 10.2 Risk management strategies........................................................................................................131 10.3 Sub-transmission underground cables replacement strategy ......................................................131 10.4 11kV switchgear asset management strategy..............................................................................132 10.5 Distribution network losses ..........................................................................................................133 10.6 Obtaining further information on asset management ...................................................................133

11 DEMAND MANAGEMENT .......................................................................................................................134 11.1 Demand management .................................................................................................................134 11.2 Demand management considerations in 2015-16 ........................................................................134 11.3 Demand management activities in 2015-16 .................................................................................135

11.3.2 Demand management innovation ...........................................................................................135 11.4 Forecast demand management projects ......................................................................................139 11.5 Demand side engagement ...........................................................................................................139 11.6 Embedded generator enquiries and connection applications .......................................................140

12 INVESTMENTS IN METERING AND INFORMATION TECHNOLOGY ..................................................141 12.1 Metering .......................................................................................................................................141 12.2 Information and communication technology .................................................................................142

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12.2.1 Ausgrid’s ICT plan ..................................................................................................................142 12.2.2 Description of key network related ICT systems.....................................................................143

ANNEXURE A – GLOSSARY ............................................................................................................................ A

ANNEXURE B – RELIABILITY AND PERFORMANCE LICENCE CONDITIONS ............................................. B

ANNEXURE C – STS AND ZS LOAD FORECAST ........................................................................................... C

ANNEXURE D – FEEDER LOAD FORECAST .................................................................................................. D

ANNEXURE E – COMPLIANCE CHECKLISTS ................................................................................................. E

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1 Executive Summary

Ausgrid is both a registered Distribution Network Service Provider and a Transmission Network Service Provider, and is required to produce a Distribution Annual Planning Report (DAPR) covering its distribution network and a Transmission Annual Planning Report (TAPR) covering its transmission (dual function asset) network. To align the publication of the DAPR and TAPR, the National Electricity Rules (NER) permit the publication of both documents in a combined annual planning report.

This Distribution and Transmission Annual Planning Report (DTAPR) presents the results of Ausgrid’s annual planning review of both its distribution and transmission (dual function asset) network conducted since the publication of the previous DTAPR in December 2015. The 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 sub-transmission substation (STS), zone substation (ZS) and sub-transmission 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

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, and

Describe significant changes to identified network limitations including capacity, asset condition and other limitations on the network assets; changes to potential credible solutions, and project deferrals and cancellations.

A revised version of the licence conditions which repealed Schedule 1 of the former Design, Reliability and Performance Licence conditions came into effect on 1 July, 2014. Ausgrid has developed a planning methodology comprising the update of existing planning standards and creation of a suite of new standards based on capacity requirements and cost benefit analysis to replace the previous Design, Reliability and Performance Licence conditions Schedule 1 design planning criteria.

The DAPR section covers a minimum five year forward planning period and the TAPR section covers a ten year forward planning period from December 2015.

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2 Introduction

This Distribution and Transmission Annual Planning Report (DTAPR) 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). Version 82 of the NER has been used.

Ausgrid has prepared this DTAPR with a five year forward planning horizon. It reflects the outcomes of the annual planning review of Ausgrid’s electricity network since the publication of the December 2015 DTAPR. The purpose of this document is to inform Registered Participants, stakeholder groups and interested parties of the identified future network needs, 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 DTAPR 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 and 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 with other Network Service Providers, covering a minimum five year forward planning period for distribution assets

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 transmission 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 main NSW transmission network. Ausgrid is therefore also registered as a TNSP and is required to publish a Transmission Annual Planning Report (TAPR) covering our dual function assets. The NER permit Ausgrid to publish its TAPR as part of the DAPR to align the publication of both reports each year. Ausgrid has combined the two reports into one Distribution and Transmission Annual Planning Report.

2.1 About Ausgrid The key electricity network infrastructure assets of the Ausgrid business are leased from the State of NSW by the Ausgrid Asset Partnership (AAP). Those network infrastructure assets are then on-leased to the Ausgrid Operator Partnership (AOP). Both AOP and AAP have the same board of directors and operate as complementary “stapled” entities.

The AOP and AAP are unincorporated partnerships between the State of NSW (49.6%), and private partners Australian Super and IFM Investors (jointly owning 50.4%).

The Ausgrid business is managed on a day to day basis by Ausgrid Management Pty Ltd (ACN 615 449 548) (Ausgrid Management) which is wholly owned by the AOP.

Ausgrid Management employs the employees of the Ausgrid business and will enter into most business contracts for the Ausgrid business, either in its own name or as agent for the AAP or AOP. 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.

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2.1.1 Our purpose and vision Ausgrid’s purpose is to be of service to our communities by providing a safe and reliable electricity supply to our customers in an efficient and sustainable way. Our values guide the standard of ethical behaviour expected of us and our employees. These following values form the basis for everything we do at Ausgrid:

Safety excellence

Respect for people

Customer and community focus

Continuous improvement, and

Act with integrity.

Our key drivers are improving safety performance, maintaining the reliability of our network and containing average electricity network costs for our customers.

2.1.2 Our principal activities Ausgrid is a business that is managed as a Network Asset & Operator Partnership under a long-term lease from the NSW State Government with the majority share (50.4%) share held by Australian Super & IFM Investors . Ausgrid’s main activities are the safe management and operation 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.

On 4 June 2015, the Electricity Network Assets (Authorised Transactions) Act 2015 and the Electricity Retained Interest Corporations Act 2015 were enacted. The legislation allowed the NSW Government to deliver its policy to lease 49 percent of the state's electricity networks and to use the proceeds from those transactions to build new infrastructure. This lease agreement was completed on 1 December 2016.

Ausgrid’s operations remain focused on the objectives of :

Operating a safe, reliable and sustainable network

Operating efficiently;

Maximising the value of the company to shareholders, and

Balancing commercial, social, environmental and customer expectations

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.

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2.1.4 Ausgrid customer, demand and energy supply statistics Table 2.1: Ausgrid distribution network customers, maximum demand and energy

Customers, Maximum Demand and Energy Number at

end of 2014/15

Number at end of

2015/16

Distribution Customer Numbers (Total) 1,679,151 1,697,604

Distribution Customer Numbers – Sydney East Region 335,555 338,724

Distribution Customer Numbers – Sydney South Region 497,816 504,999

Distribution Customer Numbers – Sydney North Region 396,684 400,354

Distribution Customer Numbers – Newcastle Region 203,014 204,816

Distribution Customer Numbers – Central Coast Region 159,734 161,262

Distribution Customer Numbers – Lower Hunter Region 55,827 57,077

Distribution Customer Numbers – Upper Hunter Region 30,521 30,331

Maximum Demand (Aggregated System MW) 4,912 5,488

Energy Received by Dist Network to Year End (GWh) 26,700 26,699

Energy Distributed to Year End (Residential) (GWh) 8,521 8,514

Energy Distributed to Year End (Non-Residential including un-metered supplies) (GWh)

17,110 17,103

Energy Distributed to Year End (GWh) 25,630 25,618

System Loss Factor (%) 4.01% 4.05%

NOTES: Distribution Customer Numbers (Total)’ includes a small number of customers that could not be assigned to a region.

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.

December 2016 12

2.2 Ausgrid’s network In 2015/16, Ausgrid’s network supplied more than 25,000 GWh of electricity to more than 1.69 million network customers. Our distribution area (Figure 2.1) 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.

Figure 2.1: 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 (these are transmission assets which support the main TransGrid transmission system);

A sub-transmission system of 33kV, 66kV and 132kV assets;

A high voltage distribution system of predominantly 11kV, with some 5kV, 22kV and 33kV and 12.7kV Single Earth Wire Return assets, and

A low voltage distribution system of 400V assets (230V single phase).

Dual function assets are regulated by the 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).

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Table 2.2: Ausgrid network statistics

Network Asset 2014/15 2015/16

Dual function (Transmission) System – 132kV (km) 930 931

Sub-transmission System - 33kV, 66kV and 132kV (km) 3,180 3,162

Substations - Sub-transmission (STS) 46 46

Substations - Zone (ZS) 191 188

Substations - Distribution 31,235 31,525

High Voltage Overhead (km) 10,061 10,049

High Voltage Underground (km) 8,096 8,176

Low Voltage Overhead (km) 19,466 19,269

Low Voltage Underground (km) 7,221 7,329

Feeder Numbers CBD 56 56

Feeder Numbers Urban 1,759 1,742

Feeder Numbers Short Rural 335 379

Feeder Numbers Long Rural 4 5

Pole (number) 509,189 509,236

Streetlights (number) 255,957 256,583

NOTES:

Distances for overhead and underground lines are circuit km.

Asset counts and lengths do not include private assets.

Low voltage overhead and underground lengths also includes streetlighting. For the 2014/15 financial year, length of OH streetlighting mains is 6,387km, and length of UG streetlighting mains is 1,302km. For the 2015/16 financial year, length of OH streetlighting mains is 6,180km, length of UG streetlighting mains is 1,283km.

Figure 2.2: Typical components of an electricity network

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2.3 Annual planning review

2.3.1 Distribution 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 distribution annual planning review is to identify possible future issues over a minimum five year planning horizon 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 document 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.

2.3.2 Transmission 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.

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.

1

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 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.

2.3.3 Distribution and Transmission Annual Planning Review and Reporting Reporting of both planning reviews have been merged into one document. The information that the NER requires Ausgrid to report for both distribution and transmission is covered throughout the various sections of the DTAPR

2.4 Ausgrid’s planning approach The network planning and development process for both the distribution and transmission networks is carried out in accordance with the 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 NER 5.12.1 -Transmission annual planning review for dual function assets.

Ausgrid has developed and implemented a planning methodology comprising the update of existing planning standards and creation of a suite of standards based on capacity requirements and cost benefit analysis to replace the previous Design, Reliability and Performance Licence conditions Schedule 1 design planning criteria.

2.4.1 Investment objectives and decision criteria Ausgrid’s investments objectives respond to one or more of three key policy directives:

1 Planning Standard INV-STD-10033: Classification of Dual-Function Assets

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Comply with its obligations under Chapter 5 of the NER; the Reliability and Performance Licence conditions for Electricity Distributors

2 which repealed the Design, Reliability and Performance Licence

conditions on 1 July, 2014, 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, unserved energy, 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 NEM. Network investments options are selected where they deliver the highest Net Present Value (NPV), taking into account the costs, risks and anticipated benefits.

Ausgrid’s investment processes are designed to 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.

A sustainable investment profile over the long term, to minimise peaks and troughs that can lead to instability in electricity prices.

2.4.2 Network planning process Ausgrid follows a structured planning process that can be summarised by the following diagram from our Network Investment Policy. The planning phase involves identifying the investment needs and risks; developing one or more options to address these needs; assessing costs and benefits associated with those options to select the preferred option and initiating the preferred option.

2 Refer to Annexure B - Reliability and Performance Licence conditions for Electricity Distributors

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Planning Phase

Existing

Network

Forecast

Investment

Objectives

Identify

Needs &

Risks

Develop

Options

Investment

AppraisalInitiate

Design &

BuildManage

Plans

Retire

Figure 2.3: Ausgrid planning process

The timeframe and complexity of this process varies according to network level, 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 major sub-transmission investments designed to meet the various needs of the network, in particular demand growth, voltage, power quality, fault duty, stability and asset renewal requirements. Investment options are identified by a cost-benefit analysis within an Area Planning process to meet the requirements of large geographic areas over a 20 year planning period. Given that these projects are generally of significant value, this process involves detailed analysis of a number of alternatives.

Asset replacement and network risk

These investments are designed to manage risks associated with asset conditions and the safe and reliable operation of the network. Investment is either to meet specific obligations and standards; or justified based on an assessment of cost and benefits, in terms of risk mitigated (e.g. determined from condition assessments and historical performance). Investments usually involve programmes of work that generally comprise larger volume of smaller projects designed to address the risks associated with assets of a simlar type.

Distribution (generally 11kV)

These investments address the needs of the distribution network, in particular demand growth, voltage, power quality and fault duty requirements. These investments are planned to meet the requirements of the distribution network over a five year planning horizon. The level of analysis depends on the scale and complexity of individual projects.

Customer connections

These investments are for the reinforcement of the up-stream portion of the shared network associated with connections that are not customer funded. Investments are initiated by customer connection applications. Investment requiremetns are forecast on the basis of historical expenditure trends adjusted for changes in Ausgrid’s connection policy.

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.

2.4.3 Network area plans To ensure Ausgrid’s investment is prudent and efficient, our 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 NER and other applicable regulatory instruments in a holistic manner

December 2016 17

considers identified needs over a twenty year planning horizon to allow for the development of a long term strategy that addresses various 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 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 determined by cost-benefit analysis and 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 five 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 RIT-D.

2.5 Significant changes from previous DTAPR Significant changes from the previous DTAPR report are covered in the various sections of the DTAPR and explain the reasons for project cancellations or deferment beyond the 5 year planning horizon for ditribution and 10 years for transmission.

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3 Forecasts for the forward planning period

3.1 Zone and subtransmission substation load forecasting methodology This section describes the maximum demand base forecasting methodology (the forecast) used by Ausgrid for zone substations and sub-transmission substations.

The forecasts of peak demand are prepared at the zone substation level and at the sub-transmission substation level. These spatial forecasts form a key input into the planning of Ausgrid’s capital expenditure program.

The forecast is constructed from two components; a near term forecast that is based on the statistically derived trend line of the weather corrected historical customer electricity demand, and a medium to long term forecast that is based on an econometric model. This recognises the need for the forecast model to consider the short term trend and long term macro econometric factors.

Both components are adjusted for impacts from embedded generation, energy storage and energy efficiency. The forecast is prepared seasonally for summer and winter.

Adjustments to the forecast are also made at a spatial level to account for planned new large customer connections and planned changes to the network architecture such as load transfers.

3.1.1 Near term component of forecast The near term component of the forecast is based upon the local historical trend in total customer demand from both grid supplied electricity and customer embedded generation. The process for deriving the local substation forecast is as follows:

a) Raw metered electricity demand data is obtained for zone substations and sub-transmission substations for 7 years at 15min intervals.

b) 10 years of weather data is obtained from the Bureau of Meteorology for weather stations across Ausgrid’s network area. Each zone and sub-transmission substation is assigned a representative Bureau of Meteorology weather station.

c) Network configuration data is obtained from Ausgrid’s planning and customer connections groups.

d) The metered electricity demand data is cleansed to remove abnormal loads (generally resulting from temporary network switching and abnormal configurations). This prevents abnormally switched loads from distorting historical trends.

e) The total customer electricity demand is then weather corrected based on the variable of “average ambient temperature”, and subjected to Monte Carlo simulation analysis. This enables calculation of probability of exceedance (POE) levels.

f) Embedded generation demand for all 30 min intervals is modelled from a representative sample of customer interval meter data (gross metered systems) for customer solar power systems.

g) Historical non-dispatchable embedded generation (30 min intervals) at each zone substation is then estimated from the embedded generation demand model and historical customer connection information.

h) The weather corrected loads are then adjusted to remove the effect of step changes in demand that would distort the calculation of the trend. This reveals the underlying trend in the metered electricity demand from customers for each substation.

i) Regression of the adjusted weather correction calculates the underlying rate of growth using a line of best fit at each zone and sub-transmission substation. Any step changes in demand (solar, historical spots and transfers) are then reinserted to arrive at the starting point.

j) This local substation trend forms the basis for the first 2 years of the forecast for each substation.

3.1.2 Medium to long term component of forecast The medium to long term component of the forecast is based upon an econometric model. The econometric model is derived from key drivers at the local and system total level for both residential and non-residential elements. The process for deriving the medium to long term component of the forecast is as follows:

a) The residential and non-residential components of the econometric model includes both price and income response elements. The residential component includes drivers for the change in real retail residential electricity prices and the change in real average household disposable income. The non-residential component includes drivers for the change in real retail non-residential electricity prices and the change in NSW Gross State Product. The residential component also includes impacts from any forecast changes in air conditioner penetration rate and population growth.

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b) Forecast variation in real retail residential electricity prices, real average household disposable income, real retail non-residential electricity prices and NSW Gross State Product are obtained. For the 2016 forecast, this data was obtained from the Australian Energy Market Operator (AEMO) and is the data used for AEMO’s 2016 National Electricity Forecast Report (NEFR).

c) Due to the collinearity of the historical customer price response with historical impacts from energy efficiency improvement, the model is based upon the total ‘electricity services‘ to customers. The ‘electricity services’ includes the total metered demand (grid supply), the historical demand impacts from embedded generation and the historical demand impacts from Commonwealth and New South Wales government energy efficiency programs.

d) The total metered electricity demand (grid supply) is obtained for all 30 min intervals from the bulk supply point meter data for Ausgrid’s network.

e) From the interval metered data for over 500,000 customers and the total system metered electricity demand data from the bulk supply point meters, a regression model is used to calculate a separate metered electricity demand for residential customers and non-residential customers.

f) The historical demand impacts from non-dispatchable embedded generation are obtained as per items f-g in the description of the near term forecast above. These are allocated separately for residential and non-residential customers.

g) The historical and forecast demand impacts from Commonwealth and New South Wales government energy efficiency programs are obtained for three key programs:

i. the Minimum Energy Performance Standards (MEPS) program which sets national minimum energy performance standards for electrical appliances such as air conditioners, motors, televisions and refrigerators;

ii. the Building Code of Australia (BCA) which sets minimum energy performance standards for buildings; and

iii. the NSW Energy Savings Scheme (ESS) which encourages customers to invest in energy efficiency improvements in their homes and businesses.

Ausgrid obtains the historical and forecast demand impacts for these energy efficiency programs from external expert advice. The demand impacts are allocated separately for residential and non-residential customers. The peak demand contribution is derived from the seasonal daily load factor on day of system peak.

h) The historical ‘electricity services’ for residential customers and the ‘electricity services’ for non-residential customers are then regressed against the separate independent variables of price and income. The econometric model determines the elasticities for both income and price for each of the residential and non-residential customer sectors.

i) The impact from household energy (battery) storage is included in the medium to long term forecast model. The forecast household energy storage model assumes a standard S-type technology adoption curve and an energy storage price trajectory of 7% reduction per annum (similar to scenarios outlined by the CSIRO – Future Energy Storage Trends 2015 report and the Bloomberg New Energy Finance – New Energy Outlook 2016 report). The forecast assumes that the adoption of energy storage is allocated spatially based on the current penetration of rooftop solar.

j) The residential component impacts from forecast changes in air conditioner penetration rate are based upon an assessment of the trend in the data from the Australian Bureau of Statistics (ABS). For the 2016 forecast, the forecast change in the air conditioner penetration rate are minor since presently, air conditioning penetration rates are close to the 65% saturation level given by the ABS..

k) The residential component impacts from forecast changes in population growth are based upon data from the NSW Department of Planning. For example, for the Sydney region the data is derived from ‘A Plan for a Growing Sydney’ dated Dec 2014.

l) The final forecast grid supplied electricity demand is determined by netting out the forecast impacts from embedded generation, energy efficiency and energy storage, and adjusting for changes in population.

m) Each component is allocated at a zone substation level. Allocation of embedded generation and energy storage is based upon the current penetration of rooftop solar. Allocation of energy efficiency impacts is based upon each substation’s share of annual metered electricity volume. Allocation of impacts due to population changes is based upon the NSW Department of Planning data at the Local Government area level, adjusted for the substation service boundaries.

n) This econometric model forms the basis for years five and beyond of the forecast for each substation.

A transition period applies to years 3 and 4 of the forecast where the short term forecast trend is blended with the econometric model forecast.

3.1.3 Assumptions applied to substation load forecasts 3.1.3.1 Endeavour supplied substations

December 2016 20

There are three Ausgrid zone substations not connected at 132kV within Ausgrid’s network, but supplied from Endeavour Energy at 66kV and 33kV. These zone substations are Epping 66/11kV, Leightonfield 33/11kV and Hunters Hill 66/11kV. Demand from these zone substations is included in the aggregate data.

3.1.3.2 Customer negotiated capacity

Where a customer has negotiated a higher standard of service than the default planning standard 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.

3.1.3.3 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 non-dispatchable 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:

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.

3.1.3.4 Capacitors for power factor correction

Reactive compensation for locations with known capacitor installations is modelled according to the following guidelines:

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 nameplate step size and maximum available MVAr capacity and the application of 2 adjustment factors, the voltage adjustment factor and the operational adjustment factor.

The voltage adjustment factor calculated at 0.84 accounts for the difference between the nameplate rated voltage and the operational voltage at the corresponding substation. The voltage adjustment is the square of the ratio of nominal operational secondary voltage at the substation over the nameplate rated voltage of the capacity ie (11/12kV)² or (33/36kV)².

The operational factor accounts for the fact that caps are not necessarily switched in to maximise power factor. In determining the operational factor, historical patterns of cap switching are used.

3.1.3.5 Weather correction

Historical loads are weather corrected, to enable statistical trend line calculation of growth rates and the determination of probabilistic forecast loads. The weather correction 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 is applied according to the following rules:

Maximum demands are weather corrected with a probability of exceedance of 50% (POE50) which forms the basis for planning decision-making.

Each substation uses 10 years of Bureau of Meteorology (BOM) data from the geographically closest BOM weather station;

Ambient temperature is used; and

Weather correction 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.

3.1.3.6 Exceptions for weather correction

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Weather correction 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 is not applied to dedicated large customer loads (connected at the sub-transmission level).

3.1.3.7 Rate of growth

The rate of growth, which may be negative, is calculated according to the following process:

the historical spot loads, load transfers, and small scale solar generation 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 growth rate of zero is applied to dedicated customer loads (connected at the sub-transmission level).

3.1.3.8 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. When applying spot loads in the forecast, there is a need to distinguish between natural load growth and increases arising from spot loads. Depending on the nature of spot loads activity, some spot loads may be individually small or there may be numerous small spot loads occurring around the same time at a given substation.

To account for these possibilities, the sum of spot loads for each year for each substation is compared to a threshold of 50A (approx 1MVA @ 11kV). Where the sum is less than the threshold, the growth is considered to be organic and not included as a spot load adjustment in the forecast.

A scaling factor of 73% 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 connected at 33kV or above.

3.1.4 Explanation of substation forecast outcomes Although the 2014 and 2015 forecasts were projecting a continuation of declining demand in the short term followed by a gradual recovery, recent analysis of demand trends has indicated that the declines have abated with a return to demand growth predicted. Analysis by Ausgrid and others indicates that the significant step change decline in energy demand which occurred between 2009 and 2013 was substantially price driven. This change was in addition to the increasing but steady impact from improvements in the energy efficiency of appliances and buildings. With electricity prices projected to remain relatively stable over the forecast horizon, this forecast absence of future price growth removes a significant suppression of future customer demand.

A significant increase in new customer connections and an expectation of relatively stable economic growth are key contributors to rising electricity demand. Based on NSW Department of Planning projections, Ausgrids network is expected to serve more than 300,000 additional households by 2031. The demand for new customer connections, as reflected in the committed spot loads included in the near term forecast, has also increased substantially with around a 90% increase from the 2015 to the 2016 forecast.

Forecast impacts from energy efficiency remain a material impact on final forecast demand and are included as adjustments that suppress demand. A recent update to the expert advice Ausgrid receives on these energy efficiency impacts shows a modest decline in the impact from future standards and programs.

The forecast for rooftop solar power installations is for steady growth, albeit at a slightly lower rate than was forecast last year. The rate of rooftop solar power installations in 2015/16 was below the 2015 forecast (85% of forecast) and the rate of solar power installations has moderated. The 2016 forecast includes an estimated 440 MW of new rooftop solar power systems by 2026.

The 2016 forecast also includes projected impacts from the customer take-up of battery storage, with an estimated 7 MW of peak demand reduction in 2025 and 174 MW reduction in 2035.

3.2 Transmission - distribution connection point load forecasts 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 Section 5.2.1 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

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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.

3.3 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. A revised version of the licence conditions which repealed Schedule 1 of the former Design, Reliability and Performance Licence conditions came into effect on 1 July, 2014. Ausgrid has developed an interim planning standard, and is in the process of finalising an appropriate planning standard based on cost benefit analysis to replace the previous Schedule 1 design planning criteria.

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, and

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.

3.4 Primary distribution feeder load forecasts Ausgrid’s primary distribution feeder forecast contains peak load values that are selected seasonally and adjusted to account for temperature variation and abnormal switching on the distribution network.

The summer and winter peak day and night loads are identified by comparing the 15 minute interval load data for the primary distribution feeders to the associated zone substation historic peak load data. Any inconsistencies between the primary distribution feeder and zone substation interval 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 any evidence of abnormal switching, it is investigated and the load value is adjusted accordingly to compensate.

The weather correction applied to the associated zone substation load is also applied to the primary distribution feeder if appropriate.

The associated zone substation forecast load rate of growth (ROG) and known network changes (spot loads and transfers) are applied to the previously adjusted load value for a forward planning period covering the next 6 years.

There are no primary distribution feeders that exceeded their rating in the past year or are forecast to exceed it in the next two years.

3.4.1 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.

As mentioned in section 2.4, Ausgrid was required to be as compliant as is “reasonably practicable” with the former Licence Cconditions in relation to all existing network elements. However, the release of the new Licence Conditions in January 2014 which took effect in July 2014 removed the deterministic design criteria for planning. Ausgrid is currently assessing the need to consider growth related projects with zone capacity threshold. The former licence capacity of N-2 for the Sydney CBD area and N-1 for the rest of the areas except Inner Metro Transmission is treated as a threshold for investigation.

December 2016 23

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 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 consistent with the information used in the forecast and is current as at March 2016 and includes all known systems under 100kW. Solar generation systems over 100kW are included with the “Other” embedded generation. 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, waste heat recovery generating units and Solar PV systems larger than 100kW known to Ausgrid. Not all of these units export to the grid as they are not capable of operating in parallel with the Ausgrid network 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 15 minute demand interval data. For each location the number of 15 minute occurrences that exceeded the 95th percentile value of maximum demand was summed and divided by four to determine the "hours within 95% of peak" value.

3.4.1.1 Load transfer capacities of zone substations

Load transfer capacity is the amount of load that can be restored in the event of a whole zone outage by switching the distribution network. The transfer capacities presented in Appendix C assume that a single zone is rendered out of service and the rest of the network is in system normal configuration.

Load transfers are considered to be temporary as transferring load to neighbouring zone substations will increases the utilisation of the destination zone and feeders. This has an adverse impact on the operability of the network as the remaining distribution network is more highly utilised than planned and further restoration of subsequent contingencies may not be possible.

Transfer capacities as presented in this document are based on the existing 11kV network. Installation of additional 11kV interconnection and transfer capacity is typically a further consideration where it might provide a cost effective alternative to other capital investment associated with zone substations or the subtransmission network.

Load transfer impacts are assessed on a case by case basis (typically in a load flow program) to ensure that the overall impact of load transfers does not overload assets in the distribution network.

Additionally, a load transfer changes the configuration of the distribution network which may impact the capacity of subsequence load transfers. Therefore, the presented transfer capacities assume that no other load transfers have occurred.

3.4.2 Notes on identified system limitations Consideration of remedial action is required when network elements exceed secure capacity. Identified limitations 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 has been identified causing a significant risk of unserved energy. “Asset condition” refers to either a need to refurbish an asset due its condition or approaching the end of service life.

3.5 Other factors having a material impact on the network

3.5.1 Fault levels Fault levels at TransGrid’s Beaconsfield BSP exceed 40kA under some operating arrangements. TransGrid has installed new 50kA rated switchgear at Beaconsfield BSP (condition-driven replacement) and Ausgrid is now using equipment rated at this level for potential future Ausgrid developments in the area. Nearby existing substations with 40kA rated switchgear, under certain operating scenarios, operate very close to their limits and this restricts some operating arrangements. There are numerous open points on the 132kV meshed

December 2016 24

transmission system due to these fault level limitations. These open points create more complicated switching arrangements and limit network flexibility.

132kV series reactors have been 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 is also a program designed to overcome fault level issues in the 11kV network. These issues can be for both high and low fault levels. Feeders that have high fault levels can result in damage to equipment. Feeders with low fault levels may have protection that cannot see or discriminate between fault locations which leads to increased clearing times or excessive customers being interrupted. Typical solutions to these issues are to upgrade the feeder, modify the protection settings or alter the network configuration.

3.5.2 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 were installed during the 2009-14 regulatory period at Beaconsfield BSP and Peakhurst STS. Additional capacitors have been installed at Bunnerong STS since, and shunt reactors at Rookwood Rd BSP to help manage the 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.

3.5.3 Other power system security requirements Ausgrid’s under frequency load shedding capabilities are assessed on a bi annual basis to ensure compliance with NER requirements. Projects are created where compliance is no longer met due to network topology rearrangements or at the request of AEMO.

3.5.4 Quality of supply 3.5.4.1 Supply Voltage

Measurements on the LV network indicate that a number of sites exceed the V99% value when measured to AS 61000.3.100, which is a consequence of the network being historically designed for a nominal 240V range. Ausgrid is currently undertaking a 230V migration program comprising of zone substation voltage regulation settings to lower the 11kV distribution supply that is now substantially complete, and adjustment of tap changer settings at the distribution substations to lower the voltage on the low voltage distributors to achieve network functional compliance. This is an ongoing activity and is not expected to be completed until the next regulatory period.

3.5.4.2 Harmonics

Measurements on the LV network indicate that a number of sites exceed the limit for the 15th and 21st harmonics. The 15th and 21st harmonics are close to the Customer Load Control (“Ripple Signal”) transmission frequency used for off peak hot water control, resulting in high readings for these harmonics. The absolute levels of these harmonics were low and were not seen to be a significant issue in terms of causing trouble for equipment operation.

3.5.4.3 Flicker

Measurements on the LV network indicate that a number of sites exceed the limit for Plt (Long Term Flicker). Inspection of the results showed that a larger number of the randomly selected sites were in proximity to either Electric Arc Furnaces (EAF) or construction sites, which are known to inject high levels of Flicker onto the network. Review of the customer complaints database for FY2016 showed a number of recorded complaints from customers about Flicker, further investigations and measurements showed that all but three sites were compliant to AS61000.2.2 for Flicker and voltage fluctuations.

3.5.5 Embedded generation Ausgrid Ausgrid has published on its website, guidance for proponents seeking to connect an embedded generating system under Chapter 5 or Chapter 5A of the NER. The information includes guidelines, Network Standards, Electrical Standards and Connection Application forms. A register of completed generator connections is also maintained in accordance with the NER requirements.

December 2016 25

Ausgrid provides standard connection offers for embedded generation up to 5MW (three phase). Beyond the 5MW limit the connection offer is negotiated.

Ausgrid continues to work with industry partners including the Clean Energy Council, ENA and other DNSPs to better understand the current and future network impacts of embedded generation and the emerging battery storage market.

3.6 Additional notes

3.6.1 National Transmission Network Development Plan The National Transmission Network Development Plan (NTNDP) 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 NTNDP includes a review of the:

National transmission flow paths

Identification of forecast constraints on the national transmission flow paths, and

Options that are technically capable of relieving forecast constraints on national transmission flow paths.

A copy of the annual NTNDP is available on AEMO’s website at www.aemo.com.au

3.6.1.1 NSW responsibility

In the NTNDP, 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 the NTNDP.

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

3.6.2 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 non-network 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 DTAPR chapter 11 - 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

December 2016 26

4 Distribution Load Areas

4.1 Camperdown and Blackwattle Bay load area

4.1.1 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, 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, and conversion to 11kV is in progress.

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 three major customers: Barangaroo South, Sydney Train 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;

After the implementation of the committed project, Camperdown ZS will be supplied via three 33kV cables from 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 4.1: Camperdown load area

December 2016 27

4.1.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.1.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.1.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission -Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.Pyrmont STS Sep-17 Capacity 3.8 None Credible solutions include:

1. Installation of Auto-closing on Transformer 3;

2. Paralleling the three transformers; or

3. Defer the installation of auto-closing on

Transformer 3 via Demand Management.

Assessment for non-network solutions, completed for

the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

2.Blackwattle

Bay ZS

Dec-18 Asset

Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Decommission Blackwattle Bay ZS by

transferring load to Camperdown and Darling

Harbour ZS;

2. Refurbishment of Blackwattle Bay ZS;

3. New Blackwattle Bay ZS; or

4. Defer the retirement of Blackwattle Bay ZS via

demand management.

A preliminary assessment for non-network solutions

concluded that it is not probable there is a potential

opportunity for demand management to form part of

the least cost solution. As the assessment was

based upon preliminary assumptions for project

costs, unserved energy and other benefits, a more

detailed assessment will be conducted to fully

assess the viability of the option.

3.Feeders 527

& 559 -

Pyrmont STS

to Blackwattle

Bay ZS

2015-19 Condition NA None

4.1.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

December 2016 28

4.2 Canterbury Bankstown load area

4.2.1 Description of Canterbury Bankstown load 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.

The area contains substantial industrial precincts at Chullora, Leightonfield, Milperra and Padstow. The Department of Planning views Bankstown airport at Milperra as a key economic driver for the central western area of Sydney, providing opportunities for reasonable expansion to serve a wider commercial purpose. 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 Sydney Trains and the M5 motorway

includes six zone 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 92C, 92X, 91X2, 91Y2, 910, and 911.

Figure 4.2: Canterbury Bankstown load area

4.2.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.2.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.2.4 Identified system limitations

December 2016 29

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Dulwich Hills

ZS

Jun-20 Asset Condition

(11kV

Switchgear)

NA None Credible solutions include:

1. Repl. Dulwich Hill ZS with new Summer Hill ZS;

2. Refurbish Dulwich Hill ZS;

3. Decommission Dulwich Hill ZS via load transfer;

or

4. Defer the retirement of Dulwich Hill ZS via

demand management

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.Note: The 33KV Feeder and 11kV

switchgear condition to be considered concurrently

to identify any opportunities to reduce overall

project cost.

2. Feeders 643, 644 & 645 - Canterbury STS to Dulwich Hill

ZS

Dec-17 Asset Condition NA None

3.Enfield ZS Jun-17 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace Enfield ZS with a new Strathfield

South ZS;

2. Refurbish Enfield ZS;

3. Decommission Enfield ZS via load transfer; or

4. Defer the retirement of Enfield ZS via demand

management

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

Note: The 33KV Feeder and 11kV switchgear

condition to be considered concurrently to identify

any opportunities to reduce overall project cost.

4.Feeders 639,

640 & 641 –

Canterbury STS

to Enfield ZS

Dec-16 Asset Condition NA None

5.Greenacre

Park ZS

Dec-17 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. New Greenacre Park ZS with reconfiguration of

132kV feeder supply from Bankstown STS;

2. Refurbish Greenacre Park ZS;

December 2016 30

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

6.Feeders 291/1

& 292 –

Greenacre Park

to Potts Hill ZS

Sep-17 Asset Condition NA None 3.Decommission Greenacre Park ZS by

transferring load to Bankstown ZS by installing

additional transformer

and 11kV switchgear at Bankstown ZS; or

4. Defer the retirement of Greenacre Park ZS via

demand management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

7.Leightonfield

ZS

Jun-18 Asset Condition

(11kV

switchgear)

NA None Credible solution include: 1. New Leightonfield ZS; 3. Refurbish and reconfigure Leightonfield ZS; 4. Decommission Leightonfield; or 5. Defer the retirement of Leightonfield ZS via demand management. A preliminary assessment for non-network solutions concluded that it is not probable there is a potential opportunity for demand management to form part of the least cost solution. As the assessment was based upon preliminary assumptions for project costs, unserved energy and other benefits, a more detailed assessment will be conducted to fully assess the viability of the option.

8.Bass Hill ZS Nov-19 Capacity 0.2 None Credible solutions include: 1. Load transfer to Milperra or Sefton ZS via open point switching. Due to the very low cost of the preferred network

solution (switching operation – no network

augmentation investment required), an

assessment for non-network solutions was not

conducted.

December 2016 31

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

9.Campsie ZS Mar-21 Asset Condition

(50% of the

11kV

switchgear)

NA None Credible solutions include:

1. Decommission 50% of the Campsie zone by

transferring load to the adjacent zones;

2. Refurbishment of Campsie ZS in a staged

manner;

3. New Campsie ZS; or

4. Defer retirement of Campsie ZS via demand

management.

A preliminary assessment for non-network solutions concluded that it is not probable there is a potential opportunity for demand management to form part of the least cost solution. As the assessment was based upon preliminary assumptions for project costs, unserved energy and other benefits, a more detailed assessment will be conducted to fully assess the viability of the option.

4.2.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.3 Carlingford load area

4.3.1 Description of Carlingford load 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

Top Ryde shopping centre, and

North Ryde Station precinct.

Significant commercial developments are expected to continue in this area as a result of the 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 Park, 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.

The area adjoins Endeavour Energy so the new developments can be supplied via Endeavour Energy.

December 2016 32

Figure 4.3: Carlingford load area

4.3.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast.

4.3.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.3.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.3.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

December 2016 33

4.4 Eastern Suburbs load area

4.4.1 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. The area encompasses a broad spectrum of load types from medium-density residential through to large commercial and industrial customers.

The area contains substantial industrial precincts at Botany, Mascot and Alexandria, as well as major customers such as Sydney’s major domestic and international airport, the Garden Island Naval base, the University of New South Wales and the Sydney Cricket Ground/Football Stadium. The Department of Planning views Alexandria as a corridor for major commercial and industrial growth in the medium-term 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;

includes 132/11kV and 33/11kV zone substations, as well as 132kV and 33kV gas, oil and HSL feeders;

supplies high voltage customers including Sydney Trains (Surry Hills), Sydney Airport, AMCOR, and a chemical plant directly at 33kV;

will supply Equinix data centre in Bourke Road, Alexandria;

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 are under development. Information from town planning cites Alexandria as an area for major future development. These developments provide an opportunity to efficiently replace existing assets at the same time as providing additional capacity.

Figure 4.4: Eastern Suburbs load area

4.4.2 STS and ZS load forecast

December 2016 34

Refer to Annexure C – STS and ZS Load Forecast.

4.4.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.4.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Clovelly ZS Dec-17 Asset condition

(11kV

switchgear

Group1)

NA None Credible solutions include: 1. Retirement of Group 1 switchgear and transfer all loads to surrounding zones; 2. Refurbish Group 1 switchgear; or 3. Defer retirement of Clovelly ZS via demand management. A preliminary assessment for non-network solutions concluded that it is not probable that there is a potential opportunity for demand management to form part of the least cost solution. As the assessment was based upon preliminary assumptions for project costs, unserved energy and other benefits, a more detailed assessment will be conducted to fully assess the viability of the option.

2. Matraville ZS Dec-18 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Refurbish Matraville ZS;

2. Retire Matraville via new zone substation;

3. Retire Matraville ZS via load transfer; or

4. Defer the retirement of Matraville ZS via

demand management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

3. Sydney

Airport ZS

Dec-18 Asset Condition

(33kV

switchgear)

NA None Credible solutions include:

1. Reconfigure Sydney Airport ZS and replace

33kV feeders from the new Alexandria STS;

2. Retire Sydney Airport via a new 132/11kV zone;

3. Retire Sydney Airport ZS via load transfer;

4. Reconfigure Sydney Airport zone and replace

33kV feeders from Bunnerong STS; or

5. Defer the retirement of feeders via demand

management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

4. Feeders 331,

352 & 356 –

Bunnerong STS

to Sydney

Airport ZS

Dec-18 Asset Condition NA None

December 2016 35

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

network system limitation.

5. Darlinghurst

ZS

Dec-20 Asset condition

(11kV

switchgear)

NA None Credible solutions include:

1. Refurbish Darlinghurst ZS;

2. Retire Darlinghurst via new zone substation;

3. Retire Darlinghurst ZS via load transfer; or

4. Defer retirement of Darlinghurst ZS via demand

management.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

Note: The 33KV Feeder and 11kV switchgear condition to be considered concurrently to identify any opportunities to reduce overall project cost.

6. Feeders 386,

388 & 389 -

Surry Hills STS

to Darlinghurst

ZS

2016-19 Asset Condition NA None

7. Campbell St

ZS

Dec-20 Capacity (due to

Darlinghurst ZS

condition)

10.3 None Credible solutions include:

1. Load transfer from Campbell St to Surry Hills

ZS;

2. Installation of third transformer and associated

11kV switchgear at Campbell St ZS; or

3. Capacity constraint addressed via demand

management. This project is driven by Darlinghurst ZS condition issues, and therefore demand management assessment for this project has been completed as part of the Darlinghurst project.

8. Feeders

260/2 and

261/2-Zetland to

Clovelly ZS

Dec-20 Asset condition NA None Credible solutions include: 1. Retirement of feeder by transferring all Clovelly ZS loads to surrounding zones; 2. Replace feeder with a new feeder from Clovelly to Kingford ZS ; 3. Like-Like for replacement of feeders; or 4. Defer retirement of 132kV feeders via demand management. This project is bundled up with retirement of Clovelly Zone Substation & associated Clovelly group1 and 2 11kV switchgear load transfer and retirement, therefore demand management assessment for this project was considered as part of the Clovelly project.

December 2016 36

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

9. Mascot ZS Dec-20 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Refurbish existing Mascot ZS;

2. Retire Mascot via new 33/11kV ZS;

3. Retire Mascot via new 132/11kV ZS. The

possible solution for the 132kV supply is to loop in

new replaced feeder 264 and 91M/3 (advanced)

and also need to advance the replacement of

feeder 265;

4. Retire Mascot ZS via load transfer; or

5. Defer retirement of Mascot ZS via demand

management.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

10. Feeders

327, 328, 332,

337, 341 & 360

– Bunnerong

STS to Mascot

ZS

Dec-20 Asset Condition NA None

11.Feeder 265 –

Bunnerong STS

to Maroubra ZS

Dec-22 Asset Condition NA None

12.Feeder

91M/3 – Section

between

Bunnerong STS

and Mill Pond

Rd

Sep-26 Asset Condition NA None

13. Feeders

380, 381 & 382

– Surry Hills

STS to

Paddington ZS

Dec-20 Asset condition NA None Credible solutions include: 1. Retirement of feeder by transferring Paddington ZS loads to surrounding zones; 2. Like-Like for replacement of feeders; or 3. Defer retirement of 33kV feeders via demand management. A preliminary assessment for non-network solutions concluded that it is probable there is a potential opportunity for demand management to form part of the least cost solution. As the assessment was based upon preliminary assumptions for project costs, unserved energy and other benefits, a more detailed assessment will be conducted to fully assess the viability of the option.

14.Feeder 264 –

Beconsfield

BSP to

Kingsford ZS

Dec-20 Asset Condition NA None Credible solutions include: 1. Retirement of feeder by transferring Maroubra and Kingsford ZS loads to surrounding zones; 2. Like-Like for replacement of feeders; 3. Replacement of feeder via proposed new 132/11kV zone in the Mascot area; or 4. Defer retirement of feeder 264 via demand management of Maroubra and Kingsford zone loads. A preliminary assessment for non-network solutions concluded that it is probable there is a potential opportunity for demand management to form part of the least cost solution. As the assessment was based upon preliminary assumptions for project costs, unserved energy and other benefits, a more detailed assessment

December 2016 37

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

will be conducted to fully assess the viability of the option.

15. Zetland ZS Dec-2022 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Refurbish Zetland ZS and replace feeders;

2. Retire Zetland via new zone substation and

replace feeders;

3. Retire Zetland ZS via load transfer; or

4. Defer retirement of Zetland ZS via demand

management.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

Note: The 33KV Feeder and 11kV switchgear

condition to be considered concurrently to identify

any opportunities to reduce overall project cost.

16. Feeders

260/1 & 261/1 –

Beaconsfield

BSP to Zetland

ZS

Dec-21 Asset Condition NA None

4.4.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Botany ZS Dec-18 Asset Condition (11kV switchgear)

Committed.

Surry Hills ZS Oct-20 Asset Condition (11kV switchgear)

Committed.

4.5 Greater Cessnock load area

4.5.1 Description of Greater Cessnock load 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

December 2016 38

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 4.5: Greater Cessnock load area

4.5.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast.

4.5.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.5.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.5.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

December 2016 39

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Cessnock ZS Nov-17 Asset Condition (building)

Committed.

4.6 Inner West load area

4.6.1 Description of Inner West load 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 Bulk Supply Points.

includes 132/33kV sub-transmission substations at Homebush, Strathfield and Rozelle

includes four 132/11kV zone substations at Burwood, Drummoyne, Flemington and Homebush Bay, supplied via Mason Park sub-transmission switching station, and

includes four 33/11kV zone substations at Auburn, Concord, Five Dock and Lidcombe, supplied via Homebush sub-transmission substation, and Leichhardt zone substation, which is supplied via Strathfield and Rozelle sub-transmission substations.

includes planned new Transport of NSW infrastructure projects that may add to load in the area.

Figure 4.6: Inner West load area

4.6.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.6.3 Sub-transmission feeder load forecast

December 2016 40

Refer to Annexure D – Feeder Load Forecast

4.6.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.Lidcombe ZS Sep-16 Asset condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replacement of Auburn and Lidcombe 33kV

feeders with new feeders from Endeavour Energy

owned Camellia TS;

2. Replacement of Auburn and Lidcombe ZS with

a new 132/11kV zone substation adjacent to

Lidcombe ZS;

3. Replacement of 33kV feeders from Homebush

STS to Auburn and Lidcombe ZS and refurbish

Lidcombe ZS;

4. Replacement of 33kV feeders from Homebush

STS to Auburn and Lidcombe ZS and reconfigure

Lidcombe ZS or retirement of Lidcombe ZS and

uprate Auburn ZS; or

5. Defer the retirement of 33kV feeders and 11kV

switchgear via demand management.

Note: From the strategic solution point of view

Auburn & Lidcombe ZS identified needs are

addressed together.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

2.Feeders 614 &

615 –

Homebush STS

to Auburn ZS

Jun-17 Asset condition NA None

3.Feeders 602,

604 & 605 –

Homebush STS

to Lidcombe ZS

Jun-17 Asset condition NA None

4.Strathfield

STS

Dec-16 Asset condition

(33kV

switchgear )

NA None Credible solutions include:

1. Retire Strathfield STS, supply Sydney Trains

load from Homebush STS ;

2. Refurbish Strathfield STS; or

3. Defer retirement of Strathfield STS via demand

management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

5. Flemington

ZS

Sep-17 Asset condition

(11kV

switchgear

Group1 )

NA None Credible solutions include: 1. Retirement of Group 1 switchgear and transfer all loads to surrounding zones; 2. Refurbish Group 1 switchgear; or 3. Defer retirement of Flemington ZS via demand

management.

A preliminary assessment for non-network

December 2016 41

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

6.Drummoyne

ZS

Sep-19 Capacity 0.8 None Credible solutions include:

1. Load transfer to Croydon or Leichhardt ZS via

open point switching.

Due to the very low cost of the preferred network

solution (switching operation – no network

augmentation investment required), an

assessment for non-network solutions was not

conducted.

7. Feeder 90A &

90L – Mason

park STSS to

Homebush STS

Dec-20 Asset Condition NA None Credible solutions include: 1. Retirement of feeder by transferring Homebush STS loads; 2. Like-Like for replacement of feeders; or 3. Defer retirement of 132kV feeders via demand

management of Homebush STS load.

A preliminary demand management assessment

has been conducted, and the result has shown

that it is not probable that there is a potential

opportunity for non-network solution. Further

Demand Management investigation will be

conducted during the project initiation and

development stage.

4.6.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.7 Lower Central Coast load area

4.7.1 Description of Lower Central Coast load 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 network in the Lower Central Coast area:

December 2016 42

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

supplies Sydney Trains at 66kV via the Ourimbah sub-transmission substation, and

provides two 33kV supplies at Mangrove Creek and Bangalow Creek for water pumping.

Figure 4.7: Lower Central Coast load area

4.7.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.7.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.7.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Nil

4.7.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred

December 2016 43

or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Lisarow ZS Mar-17 Asset Condition (33kV switchgear)

Committed.

Umina ZS Apr-17 Asset Condition (11kV switchgear)

Committed

4.8 Lower North Shore load area

4.8.1 Description of Lower North Shore load 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 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, North Sydney 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 and Gore Hill, which are supplied radially at 33kV from Willoughby sub-transmission substation

includes substantial lengths of 33kV gas-pressure and oil filled cables, which are an obsolete technology, the replacement or retirement is in progress

supplies high rise commercial load in Chatswood and North Sydney

predominantly serves residential and commercial load, and

includes the 33kV supplies to three major customers, the Lane Cove Tunnel, Sydney Trains and Gore Hill Technology Park.

includes planned new Transport of NSW infrastructure projects that may add to load in the area.

December 2016 44

Figure 4.8: Lower North Shore load area

4.8.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.8.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.8.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.Feeders 9Y7/2

and 9Y9/2 (ex

925/4 & 9E4/4)-

castle Cove to

Mosman ZS

Dec-16

Asset condition NA None Credible solutions include:

1. Like for like replacement;

2. Retire the feeder by decommissioning Mosman

ZS via load transfer to adjacent zones; or

3. Replacement of feeder with new feeder from

Willoughby STS to Mosman ZS; or

4.Defer the retirement of the 132kV feeders via

demand management of Mosman ZS load.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

December 2016 45

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

will be conducted to fully assess the viability of the

option.

4.8.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.9 Maitland load area

4.9.1 Description of Maitland load 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

one 132/11kV zone substation located at Brandy Hill

six 33/11kV zone substations, three supplied from the 33kV network from Kurri STS, and three 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 backup 33kV supply to the Essential Energy network supplying Martin’s Creek and Gresford.

December 2016 46

Figure 4.9: Maitland load area

4.9.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.9.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.9.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.9.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Telarah ZS Dec-24 Asset Condition (11kV switchgear)

Life of switchboard extended due to revised condition assessment. No further limitations are identified within the next 5 years.

December 2016 47

4.10 Manly Warringah load area

4.10.1 Manly Warringah load 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.

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 4.10: Manly Warringah load area

4.10.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.10.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.10.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

December 2016 48

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.10.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.11 Newcastle Inner City load area

4.11.1 Newcastle Inner City load 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 seven zone substations of which five are currently supplied from the 33kV network originating from Merewether STS and two 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.

December 2016 49

Figure 4.11: Newcastle Inner City load area

4.11.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.11.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.11.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Kotara ZS Dec-18 Asset Condition

(33kV

Switchgear)

NA None Credible solutions include:

1. Retire 33kV switchgear and transformer-

end 33kV feeders

2. Replace 33kV switchgear

3. Defer retirement or replacement of 33kV

switchgear via demand management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

December 2016 50

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

2. Feeders 773,

775 -

Merewether

STS to Kotara

ZS

Jul-19 Condition (fluid-

filled cable)

NA None Credible solutions include:

1. Augment 33kV network and re-use retired

33kV assets (previously to Adamstown

and Charlestown)

2. Replace with new cables (100% feeder

length)

3. Defer retirement or replacement of 33kV

feeders via demand management.

This project is bundled up with retirement of Kotara

33kV switchgear; therefore demand management

assessment for this project has been completed as

part of the Kotara project.

4.11.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.12 Newcastle Ports load area

4.12.1 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 now retired 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 have been some proposals and enquiries for further heavy industrial development in these areas, including one additional coal-loader proposed on Kooragang Island. 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 – Newcastle Western Corridor and Newcastle Inner City, and

December 2016 51

there is also one major customer (Onesteel) that is supplied from the 132kV network.

Figure 4.12: Newcastle Ports load area

4.12.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.12.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.12.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.12.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Waratah STS Jan-19 Asset Condition (33kV switchgear)

Committed.

December 2016 52

4.13 Newcastle Western Corridor load area

4.13.1 Description of Newcastle Western Corridor load 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 M1 Pacific Motorway 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 33/11kV zone substations at Cardiff and Edgeworth

includes two 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 4.13: Newcastle Western Corridor load area

4.13.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.13.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.13.4 Identified system limitations

December 2016 53

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Edgeworth

ZS

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)

4. Defer replacement of 11kV switchgear at

Edgeworth ZS via demand management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

4.13.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.14 North East Lake Macquarie load area

4.14.1 Description of North East Lake Macquarie load 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 six 33/11kV zone substations, of which four are supplied from the 33kV network originating from Merewether STS, and two (Mt Hutton and Croudace Bay) are supplied from the 33kV network from Argenton STS

consists of one 132/11kV zone substation at Charlestown

is a predominantly overhead 33kV feeder network with a combined total length of more than 110 km, and

December 2016 54

is traversed on its northern boundary by a double circuit 132kV tower line from Newcastle 330kV substation to Merewether STS.

Figure 4.14: North East Lake Macquarie load area

4.14.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.14.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.14.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Swansea ZS Dec-20 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace 11kV switchgear

2. Build replacement zone substation

3. Defer replacement of 11kV switchgear at

Swansea via demand management.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

December 2016 55

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

4.14.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Feeder 760 Merewether STS to Jewells

Jul-18 Asset Condition (fluid-filled cable)

committed

Feeder 766 Merewether STS to Gateshead

Jul-18 Asset Condition (fluid-filled cable)

committed

4.15 North West Sydney load area

4.15.1 Description of North West Sydney load area The North West network area includes the area from Sydney North Bulk Supply Point 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.

The network in the North West area:

is supplied from TransGrid’s transmission system at Sydney North Bulk Supply Point

consists of three 132/11kV zone substations at Berowra, Hornsby, Pennant Hills supplied on a 132kV ring from Sydney North BSP, and Galston zone substation supplied from Sydney North BSP.

includes a 66kV supply to Sydney Trains from Berowra zone substation.

December 2016 56

Figure 4.15: North West Sydney load area

4.15.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.15.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.15.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.15.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.16 Pittwater and Terrey Hills load area

December 2016 57

4.16.1 Description of Pittwater and Terrey Hills load area The Pittwater & Terrey Hills 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 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 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 Sydney East sub-transmission substation 33kV busbar supplying the network.

Figure 4.16: Pittwater and Terrey Hills load area

4.16.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.16.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.16.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

December 2016 58

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.Narrabeen ZS Dec-18 Replacement 12.6 None Credible solutions include:

1. Removal of 33kV busbar and replacement of

feeder 33kV oil circuit breakers;

2. 33kV steel structure like-to-like replacement;

3.Retirement of Narrabeen ZS via loadd transfer to

adjacent ZS; or

4. Defer retirement of Narrabeen ZS via demand

management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

4.16.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.17 Port Stephens load area

4.17.1 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 eight 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 a back-up 33kV supply to Tea Gardens for Essential Energy, and

consists of approximately 195km of predominantly overhead 33kV feeder network.

December 2016 59

Figure 4.17: Port Stephens load area

4.17.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.17.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.17.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Stockton ZS Dec-20 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace 11kV switchgear

2. Build replacement ZS

3. Defer replacement of switchgear via

demand management.

A preliminary assessment for non-network

solutions concluded that it is not probable there is

a potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

December 2016 60

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

option.

4.17.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nelson Bay ZS Jun-24 Asset Condition (11kV switchgear)

Service life extended due to revised condition assessment. No further limitations have been identified within the next 5 years.

4.18 Singleton Load load area

4.18.1 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 seven 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.

December 2016 61

Figure 4.18: Singleton load area

4.18.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.18.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.18.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Newdell ZS Jul-18 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace 11kV switchgear

2. Build replacement ZS

3. Defer the replacement of 11kV

switchgear at Newdell via demand

management.

Assessment for non-network solutions had

previously determined that it was not considered

reasonable for demand management to offer a

cost effective option for this network system

December 2016 62

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

limitation.

4.18.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Branxton ZS Dec-17 Asset Condition (11kV switchgear)

Committed.

Singleton ZS Dec-18 Asset Condition (11kV switchgear)

Committed.

4.19 St George load area

4.19.1 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 construction of two new zone substations in the area allows for 11kV load transfers to facilitate retirement of three zone substations to address asset condition issues.

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 BSP.

December 2016 63

Figure 4.19: St George load area

4.19.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.19.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.19.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.Arncliffe ZS Dec-16 Asset condition

(11kV

switchgear)

NA None Credible solutions include:

1. Retire Arncliffe ZS by transferring load to

proposed new Rockdale 132/11kV ZS;

2. Refurbishment of Arncliffe ZS or replacement of

Arncliffe ZS with a new zone substation; or

3. Defer retirement of Arncliffe ZS via demand

management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

December 2016 64

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

Note: Retirement of Arncliffe via load transfer is

dependent on proposed new Rockdale 132/11kV

ZS (due for completion in 2018)

2.Peakhurst

STS

Sep-18 Asset condition

(33kV

switchgear)

NA None Credible solutions include:

1. Replace or repair 33kV switchgear building and

roof in situ;

2. Construct a new 33kV switchgear building retire

the existing building; or

3. Retirement of 33kV portion at Peakhurst STS.

4. Defer retirement of 33kV portion at Peakhurst

STS via demand management

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

3.Blakehurst ZS Dec-19 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Retire Blakehurst ZS by transferring load to

Kogarah and Hurstville North ZS and

rearrangement of 33kV supply to Sans Souci; or

2. Refurbishment of Blakehurst ZS;

3. Replacement of Blakehurst ZS with a new zone

substation; or

4. Defer retirement of Blakehurst ZS via demand

management.

A preliminary assessment for non-network

solutions concluded that it is probable there is a

potential opportunity for demand management to

form part of the least cost solution. As the

assessment was based upon preliminary

assumptions for project costs, unserved energy

and other benefits, a more detailed assessment

will be conducted to fully assess the viability of the

option.

4. Feeder 769 and 770 -Peakhurst STS to Blakehurst ZS

Dec-19 Asset condition NA None

4.19.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Arncliffe ZS – 11kV Pre-work Dec-16 Asset Condition Committed.

4.20 Sutherland load area

4.20.1 Description of Sutherland load area

December 2016 65

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 4.20: Sutherland load area

4.20.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.20.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.20.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

December 2016 66

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.20.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Kurnell STS Jun-17 Asset Condition Committed.

4.21 Sydney CBD Load Area

4.21.1 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.

A reduction in forecast CBD load has allowed for the deferral of Bligh St zone substation, with asset condition issues now able to be addressed by 11kV load transfers in the shorter term.

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 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 triplex3 construction and provides an N-1

distribution supply.

3 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.

December 2016 67

Figure 4.21: Sydney CBD load area

4.21.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.21.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.21.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1.City East ZS Dec-21 Asset condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace City East ZS with a new Bligh St ZS;

2. Refurbish the existing City East ZS;

3. Retire existing City East ZS via 11kV load

transfers to Belmore Park ZS; or

4.Defer the retirement of City East via demand

management

Assessment for non-network solutions, completed

as part of the Sydney CBD area planning process,

had previously determined that it was not

considered reasonable for demand management

to offer a cost effective option for this network

system limitation.

December 2016 68

4.21.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Dalley St ZS Sep-18 Asset Condition Need date deferred to Dec-23.

4.22 Upper Central Coast load area

4.22.1 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 , 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 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.

December 2016 69

Figure 4.22: Upper Central Coast load area

4.22.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.22.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.22.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.22.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.23 Upper Hunter load area

December 2016 70

4.23.1 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 dwellings. 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. Future connection of generation in this area is considered to be possible, but has significant uncertainty.

The network in the Upper Hunter area:

is supplied from both Mitchell Line 132/66kV sub-transmission substation (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 four supplied at 66kV and the rest at 33kV

includes five 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 4.23: Upper Hunter load area

4.23.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.23.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

December 2016 71

4.23.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Denman ZS Dec-19 Asset Condition

(11kV

switchgear)

NA None Credible solutions include:

1. Replace 11kV switchgear

2. Build replacement substation

3. Defer the replacement of 11kV

switchgear at Denman ZS via demand

management.

Assessment for non-network solutions, completed

for the 2015 Distribution & Transmission Annual

Planning Report, had previously determined that it

was not considered reasonable for demand

management to offer a cost effective option for this

network system limitation.

Note the need and timing of this project is currently

being reviewed on the basis of revised probabilistic

planning criteria and cost/benefit analysis.

2. Muswellbrook

STS

Jul-20 Asset Condition

(33kV

switchgear)

NA None Credible solutions include:

1. Refurbish substation and consolidate

assets

2. Build replacement substation

3. Defer the refurbishment or replacement of

Muswellbrook STS/ZS via demand

management.

A Demand Management analysis was carried out.

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

non-network solution. Hence, the project has been

initiated without any further Demand Management

investigation.

3. Muswellbrook

ZS

Jul-20 Asset Condition

(33kV

switchgear)

NA None Credible solutions include:

1. Refurbish substation (and replace assets

like for like)

2. Build replacement substation

3. Defer the refurbishment or replacement of

Muswellbrook ZS via demand

management.

This project is bundled up with Muswellbrook

STS, therefore demand management assessment

December 2016 72

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

for this project has been considered as part of the

Muswellbrook STS project.

4.23.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.24 Upper North Shore load area

4.24.1 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 via a radial 33kV underground network. Kuring-gai STS is supplied from TransGrid’s transmission system at Sydney East Bulk Supply Point via two 132kV feeders, 9E1 and 9E2, which predominantly comprise a single double circuit tower line

consists of Pymble, Lindfield, St Ives and Turramurra zone substations supplied from Kuring-gai STS

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.

December 2016 73

Figure 4.24: Upper North Shore load area

4.24.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

4.24.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.24.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.24.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil

4.25 West Lake Macquarie load area

December 2016 74

4.25.1 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 centre 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 M1 Pacific Motorway 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, Rathmines ZS and Morisset ZS.

Figure 4.25: West Lake Macquarie load area

4.25.2 STS and ZS load forecast Refer to Annexure C – STS and ZS Load Forecast

December 2016 75

4.25.3 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

4.25.4 Identified system limitations

Substation/ Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

4.25.5 Identified Substation and Feeder limitations changes from last year’s DAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Myuna ZS Dec-17 Asset Condition (11kV switchgear)

Committed.

Cooranbong Dec-17 Asset Condition (11kV switchgear)

Committed

4.26 Primary distribution feeder limitations There were no distribution feeder trunk section ratings exceeded in the preceding year, or expected to be exceeded over the next two years.

Distribution feeders are proactively planned to not exceed their ratings by performing regular assessment of the existing feeder network and the proposed network within a 6-year horizon. Additionally, distribution feeders are assessed for every new HV connection to ensure that there is enough capacity and the new connection does not cause an overload. An augmentation project is initiated if a future overload is expected to occur.

A final assessment of every distribution feeder is performed prior to onset of summer to identify if any feeders will exceed their trunk section rating in its normal configuration. Any feeder expected to exceed its rating will, where possible, have action taken to address the constraint before the summer peak.

This occurs because the resultant configuration of the distribution network has a reduced ability to restore supply in the event of a subsequent contingency compared to the planned ability.

December 2016 76

5 Transmission Load Areas

5.1 Preliminary notes

5.1.1 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

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.

5.1.2 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.

5.1.3 Inter-Network Impact The Augmentation proposals described in this report are reliability projects and do not have a detrimental material inter-network impact.

5.2 Ausgrid System Total Maximum Demand Forecasts This section presents forecasts of maximum demand for the Ausgrid network. The System total summer maximum demand and the System total winter maximum demand are illustrated below. Each display the actual and weather corrected actual maximum demand to 2015/16 and the 50% Probability of Exceedence (PoE) forecast maximum demand from 2016/17 in megawatts (MW).

December 2016 77

Figure 5.1: Summer Global Peak Forecast

Figure 5.2: Winter Global Peak Forecast

December 2016 78

5.2.1 Dual function substation demand forecasts 5.2.1.1 Sydney region winter peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast winter peak demand (MW and MVAr) is:

Actual Forecast

2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026

MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr

Belmore Park ZS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Bunnerong North STS

186 4 174 2 179 4 183 1 185 1 187 2 188 2 190 3 193 3 195 4 197 0 199 1

Campbell St ZS 34 7 32 7 31 7 31 7 32 7 32 7 33 7 34 7 35 7 36 7 36 8 37 8

Canterbury STS 133 18 129 18 133 18 134 18 136 19 139 19 142 19 145 20 148 0 151 1 155 1 158 1

Green Square ZS 34 19 33 19 35 19 33 18 34 19 34 19 35 19 36 20 37 20 37 21 38 21 39 21

Homebush Bay ZS 39 4 38 4 42 5 45 5 44 5 45 5 46 5 46 5 47 6 48 6 49 6 50 6

Hurstville North ZS 16 8 15 2 16 0 17 0 17 1 17 1 18 1 18 1 19 1 19 2 19 2 20 2

Kingsford ZS 49 24 48 23 48 23 48 23 49 24 50 24 51 25 52 25 53 26 55 26 56 27 57 28

Kogarah ZS 52 41 54 42 55 43 55 43 56 44 57 45 59 46 60 47 62 48 63 49 65 51 66 52

Kurnell STS 24 11 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Kurnell South ZS 6 3 6 3 6 3 6 3 6 3 7 3 7 3 7 3 7 3 7 3 7 3 7 4

Macquarie Park ZS 53 12 53 12 57 13 67 15 66 15 67 15 68 16 69 16 70 16 71 16 71 16 72 17

Maroubra ZS 44 21 42 21 41 20 41 20 41 20 42 20 42 21 43 21 45 22 46 22 46 22 48 23

Marrickville ZS 49 13 50 13 55 14 55 14 56 14 57 15 58 15 59 15 61 16 62 16 63 16 65 17

Meadowbank ZS 59 10 60 11 62 11 61 11 62 11 64 11 66 12 68 12 71 13 73 13 75 13 78 14

Peakhurst STS 126 28 126 29 134 31 135 32 121 26 124 28 127 29 130 30 134 31 137 32 140 33 144 35

Potts Hill ZS 28 18 27 17 27 17 28 18 28 18 29 18 30 19 31 19 31 20 32 20 33 21 34 21

Rose Bay ZS 37 18 36 17 36 18 36 17 36 17 37 18 37 18 38 18 39 19 40 19 40 19 41 20

St Peters ZS 40 34 39 33 46 38 46 38 46 39 47 40 48 40 49 41 51 42 52 43 53 44 54 45

Top Ryde ZS 40 5 40 5 42 5 42 5 43 5 43 6 44 6 45 6 46 6 46 6 47 6 48 6

Waverley ZS 26 13 26 12 26 13 27 13 28 13 28 14 29 14 29 14 30 14 30 15 31 15 32 15

Rockdale 132/11kV ZS

0 0 0 0 0 0 0 0 17 5 17 5 18 5 18 5 19 5 19 6 19 6 20 6

Alexandria STS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Only committed spots and transfers are included in the base forecast. At the time of base forecast being published there were no committed transfers to either Belmore Park 132/11kV or Alexandria 132/33kV and therefore zero load forecasted for the duration of the forecast period. Future load for these substations are incorporated into the forecast of other substations within adjacent areas which is proposed to be transferred to these new substations in the future.

December 2016 79

5.2.1.2 Sydney region summer peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast summer peak demand (MW and MVAr) is:

Actual Forecast

2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25 2025/26 2026/27

MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr MW MVAr

Belmore Park ZS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Bunnerong North STS

210 32 195 26 198 27 201 28 203 29 204 30 206 30 207 31 209 32 211 32 212 33 214 34

Campbell St ZS 39 12 37 12 37 12 37 12 37 12 37 12 38 12 39 12 40 13 40 13 41 13 42 13

Canterbury STS 132 12 128 12 135 13 138 14 141 15 143 15 145 16 147 17 150 17 152 18 154 18 157 19

Green Square ZS 42 24 43 25 41 23 41 23 41 24 42 24 42 24 43 25 44 25 44 25 45 26 46 26

Homebush Bay ZS 48 11 47 11 52 12 55 13 54 13 55 13 55 13 56 14 57 14 57 14 58 14 59 14

Hurstville North ZS 27 13 25 2 26 2 26 3 27 3 27 3 27 3 28 3 28 3 28 4 29 4 29 4

Kingsford ZS 39 19 37 18 37 18 37 18 38 18 38 19 39 19 40 20 41 20 42 20 43 21 44 21

Kogarah ZS 67 27 65 26 64 26 64 26 65 26 66 26 67 27 69 28 70 28 71 28 72 29 74 30

Kurnell STS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

KurnellSouth ZS 6 3 6 3 6 3 6 3 6 3 6 3 6 3 6 3 6 3 7 3 7 3 7 3

Macquarie Park ZS 74 18 78 19 82 20 92 23 92 23 93 23 94 23 95 24 96 24 97 24 98 24 99 25

Maroubra ZS 44 11 44 11 43 11 42 11 42 11 43 11 44 11 45 12 46 12 46 12 47 12 49 13

Marrickville ZS 48 18 51 19 51 19 51 19 51 19 52 19 52 19 53 19 53 20 54 20 54 20 55 20

Meadowbank ZS 68 22 69 22 71 23 71 23 72 23 74 24 75 24 77 25 79 26 80 26 82 27 84 27

Peakhurst STS 134 22 128 23 130 24 114 18 116 19 119 20 121 21 123 22 126 22 128 23 130 24 133 26

Potts Hill ZS 35 23 35 22 35 23 36 23 37 24 37 24 38 24 38 25 39 25 39 25 40 26 40 26

Rose Bay ZS 29 14 30 15 30 15 31 15 31 15 32 15 32 16 33 16 33 16 34 16 34 17 35 17

St Peters ZS 48 40 53 44 54 45 54 45 54 45 55 46 56 46 57 47 57 48 58 48 59 49 60 50

Top Ryde ZS 48 11 48 10 50 11 50 11 50 11 51 11 51 11 52 11 53 12 53 12 54 12 55 12

Waverley ZS 20 10 20 10 21 10 22 11 22 11 23 11 23 11 24 12 24 12 25 12 25 12 26 12

Rockdale 132/11kV ZS

0 0 0 0 0 0 17 9 17 9 17 9 17 10 18 10 18 10 18 10 18 10 19 10

Alexandria STS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Only committed spots and transfers are included in the base forecast. At the time of base forecast being published there were no committed transfers to either Belmore Park 132/11kV or Alexandria

132/33kV and therefore zero load forecasted for the duration of the forecast period. Future load for these substations are incorporated into the forecast of other substations within adjacent areas which is

proposed to be transferred to these new substations in the future.

December 2016 80

5.2.1.3 Central Coast Region winter peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast winter peak demand (MW and MVAr) is:

Actual Forecast

2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026

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 34 6 37 6 34 6 35 6 36 6 36 6 37 6 38 6 39 6 40 7 41 7 42 7

Gosford STS (33kV) 20 4 20 4 21 4 21 4 21 4 21 4 22 4 22 5 23 5 23 5 23 5 24 5

Gosford STS (66kV) 112 21 118 14 119 14 121 14 122 14 124 15 126 15 128 16 131 16 133 16 135 0 137 1

Ourimbah STS (33kV)

11 4 11 4 11 4 11 4 11 4 11 4 11 4 11 4 11 4 11 4 11 4 11 4

Ourimbah STS (66kV)

47 11 50 11 50 11 51 11 52 11 53 11 54 12 55 12 57 12 58 13 59 13 60 13

Somersby ZS 17 3 16 3 15 3 16 3 16 3 16 3 16 3 16 3 17 3 17 3 17 3 17 3

West Gosford ZS 42 13 39 2 39 2 40 2 41 3 42 3 42 3 43 3 44 4 45 4 46 4 47 5

Wyong ZS 27 7 28 7 28 7 28 7 29 7 30 7 31 8 32 8 33 8 34 9 36 9 37 9

Munmorah STS 0 0 0 0 27 13 27 13 27 13 27 13 27 13 27 13 27 13 27 13 27 13 27 13

5.2.1.4 Central Coast region summer peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast summer peak demand (MW and MVAr) is:

Actual Forecast

2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25 2025/26 2026/27

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 12 39 11 39 11 40 11 40 11 41 11 41 11 42 11 42 12 43 12 43 12 44 12

Gosford STS (33kV) 22 7 21 7 21 7 21 7 21 7 21 7 22 7 22 7 22 7 22 7 23 8 23 8

Gosford STS (66kV) 124 36 112 8 111 7 112 8 113 8 114 8 115 0 117 1 118 1 119 1 121 2 122 2

Ourimbah STS (33kV)

14 8 15 8 15 8 15 8 15 8 15 8 15 8 15 8 15 8 15 8 15 8 15 8

Ourimbah STS (66kV)

44 14 39 14 39 14 39 14 40 14 41 14 41 14 42 15 43 15 44 15 44 15 45 15

Somersby ZS 17 6 16 6 17 6 17 6 17 6 17 6 17 6 17 6 17 6 17 6 17 6 17 6

West Gosford ZS 47 23 45 12 45 12 45 12 45 12 46 12 46 12 47 12 47 13 47 13 48 13 48 13

Wyong ZS 35 12 35 12 36 12 36 12 37 12 38 12 38 13 39 13 40 13 40 13 41 14 42 14

Munmorah STS 0 0 0 0 20 10 20 10 20 10 20 10 20 10 20 10 20 10 20 10 20 10 20 10

December 2016 81

5.2.1.5 Hunter region winter peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast winter peak demand (MW and MVAr) is:

Actual Forecast

2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026

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 ZS 19 4 21 4 21 4 21 4 22 4 22 4 22 4 23 5 23 5 24 5 24 5 25 5

Kurri STS 86 14 89 15 91 15 92 15 93 16 94 16 96 16 98 16 100 17 102 17 104 17 106 18

Muswellbrook STS

14 2 14 2 13 1 13 1 13 1 13 1 13 1 14 1 14 1 14 2 14 2 15 2

Mitchell Line STS

69 22 67 22 68 22 68 22 68 22 69 23 69 23 70 23 71 23 71 23 72 23 72 24

Singleton STS 130 63 137 36 137 36 137 36 138 37 138 37 139 37 140 37 140 38 141 38 142 38 142 39

Rothbury ZS 6 0 6 0 6 0 6 0 6 0 7 0 7 0 7 0 8 0 8 0 8 1 9 1

Brandy Hill ZS 5 2 5 2 5 2 5 3 5 3 6 3 6 3 6 3 7 3 7 3 7 3 8 4

5.2.1.6 Hunter Region summer peak demand

The following Ausgrid 132kV substations are classified as dual function network assets. Their actual 2015 and forecast summer peak demand (MW and MVAr) is:

Actual Forecast

2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25 2025/26 2026/27

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 ZS 28 6 29 2 29 2 29 2 29 2 29 2 30 2 30 2 30 2 31 2 31 2 31 2

Kurri STS 117 1 129 1 130 1 131 1 132 1 133 1 134 1 136 1 137 1 138 1 139 1 141 1

Muswellbrook STS

14 9 13 9 14 9 14 9 14 9 14 9 14 9 15 9 15 9 15 9 15 10 15 10

Mitchell Line STS

70 23 77 24 78 24 78 24 78 24 79 24 79 25 80 25 80 25 80 25 81 25 81 25

Singleton STS 138 67 144 40 144 40 144 40 145 40 145 40 146 40 146 41 147 41 147 41 148 41 148 42

Rothbury ZS 9 1 10 2 10 1 10 1 10 1 10 1 10 2 10 2 10 2 11 2 11 2 11 2

Brandy Hill ZS 8 4 8 4 8 4 8 4 8 4 8 4 8 4 9 4 9 4 9 4 9 4 9 5

December 2016 82

5.3 Transmission load area - Central Coast

5.3.1 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 motorway. 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

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.

December 2016 83

Figure 5.3: Identified system limitations in Central Coast 132kV load area

5.3.2 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

5.3.3 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:

4.7 Lower Central Coast load area, and

4.22 Upper Central Coast load area.

Refer to Annexure C – STS and ZS Load Forecast

5.3.4 Identified system limitations

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Nil

5.3.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

December 2016 84

Timing Driver

Nil

5.3.6 Changes in dual function asset status No changes since the publication of the December 2015 TAPR

5.3.7 Dual function connection points 5.3.7.1 Augmentation of existing dual function connection points

Ausgrid has not identified any constraints to the capacity of existing dual function connection points in the next 10 years.

5.3.7.2 Committed new dual function connection points

Ausgrid has identified committed new dual function network connection points as tabulated below.

Region Proposal Purpose Timing

Central Coast

New Munmorah 132/33kV STS

Due to the termination of connection agreement between Delta Electricity and Ausgrid, Ausgrid has to replace the existing 330/33kV supply to Noraville and Vales Point, with a new 132/33kV STS solution.

Jan-17

5.4 Transmission load area – Lower Hunter

5.4.1 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

December 2016 85

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 (which recently ceased operations), and

includes nine 132/33kV sub-transmission substations and twelve 132/11kV zone substations.

Figure 5.4: Identified system limitations in Lower Hunter transmission area

5.4.2 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

5.4.3 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:

4.5 Greater Cessnock load area

4.9 Maitland load area

4.11 Newcastle Inner City load area

4.12 Newcastle Ports load area

4.13 Newcastle Western Corridor load area

4.14 North-East Lake Macquarie load area

4.17 Port Stephens

4.25 West Lake Macquarie load area.

Refer to Annexure C – STS and ZS Load Forecast

December 2016 86

5.4.4 Identified system limitations

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Awaba STS Dec-14 Asset Condition

(33kV

switchgear)

NA None Credible solutions include:

1. Retire substation and augment 33kV

network (33kV load transfers to

Argenton STS)

2. Refurbish Awaba STS

3. Convert Awaba STS to 33kV switching

station (and retire 132kV busbar)

4. Defer retirement or refurbishment of

Awaba STS via demand management

Assessment for non-network solutions,

completed for the 2015 Distribution &

Transmission Annual Planning Report, had

previously determined that it was not considered

reasonable for demand management to offer a

cost effective option for this network system

limitation.

2. Feeder 961

Newcastle BSP

to Merewether

STS

Dec -21 Asset Condition

(fluid-filled

cable)

NA None Credible solutions include:

1. Replace oil-filled cable section (5%

feeder length)

2. Build new feeder

3. Defer the replacement or retirement of

feeder 961 via demand management.

A preliminary assessment for non-network

solutions concluded that it is not probable there

is a potential opportunity for demand

management to form part of the least cost

solution. As the assessment was based upon

preliminary assumptions for project costs,

unserved energy and other benefits, a more

detailed assessment will be conducted to fully

assess the viability of the option.

5.4.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Nil Dec-15 Asset Condition Committed.

December 2016 87

5.4.6 Changes in dual function asset status No changes since the publication of the December 2015 DTAPR

5.4.7 Dual function connection points

5.4.7.1 Augmentation of existing dual function connection points

Ausgrid has not identified any constraints to the capacity of existing dual function connection points in the next 10 years.

5.4.7.2 Committed new dual function connection points

No committed projects since the publication of the December 2015 DTAPR

5.5 Sydney Inner Metropolitan transmission load area

5.5.1 Description of Sydney Inner Metropolitan transmission load area Ausgrid prepares a Sydney Inner Metropolitan 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 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. Joint planning activities with Transgrid are discussed in greater detail in Section 8.1 of this report.

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, 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.

December 2016 88

Following the commissioning of Rookwood Road BSP, 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 between the northern and southern 132kV networks via these open points.

December 2016 89

Figure 5.5: Identified limitations in Sydney Inner Metropolitan transmission load area

December 2016 90

5.5.2 Sub-transmission feeder load forecast Refer to Annexure D – Feeder Load Forecast

5.5.3 STS and ZS load forecast The forecast loads for the STS and Zone sub-transmission substations in the Inner Metropolitan Transmission area are described in the following load areas, as detailed in in DTAPR Section 4 – Distribution Load Areas:

4.1 Camperdown and Blackwattle Bay load area

4.2 Canterbury Bankstown load area

4.3 Carlingford load area

4.4 Eastern Suburbs load area

4.6 Inner West load area

4.8 Lower North Shore load area

4.10 Manly Warringah load area

4.15 North West Sydney load area

4.16 Pittwater and Terrey Hills load area

4.19 St George load area

4.20 Sutherland load area

4.21 Sydney CBD load area

4.24 Upper North Shore load area

Refer to Annexure C – STS and ZS Load Forecast

5.5.4 Identified system limitations

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

1. Feeder 260/1

and 261/1 –

Beaconsfield

BSP to Zetland

Nov-21 Asset Condition NA None Credible solutions include:

1. Like-for-like replacement;

2. Retirement of 260/1 and 261/1

feeder along with retirement of

Zetland ZS by transferring 11kV

load to neighbouring zone

substations;

3. Defer retirement or replacement of

260/1 and 261/1 via demand

management.

This project is bundled up with retirement of

Zetland ZS project. Please refer to “Section

4.4 – Eastern Suburbs Load Area” for more

detail.

2. Feeder 928/3

and 929/1 –

Lane Cove STS

to Dalley St ZS

Mar-19 Asset Condition NA None Credible solutions include:

1. Like-for-like replacement by

replacing oil-filled cables with

XLPE;

2. Retirement of 928/3 and 929/1

feeder along with retirement of

December 2016 91

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Dalley St ZS;

3. Defer retirement or replacement of

feeder 928/3 & 929/1 via demand

management.

Assessment for non-network solutions was

completed as part of the joint planning

process with Transgrid for the Inner Metro

Transmission network. A consultation paper

seeking expressions of interest from non-

network providers to address the

transmission needs in the Inner Sydney

area has been published at

www.transgrid.com.au. Submissions to the

expression of interest close 13 January

2017.

3. Feeder 91X

and 91Y –

Beaconsfield

BSP to Chullora

STSS via

Marrickville ZS

Post

2021

Asset Condition NA Yes Credible solutions include:

1. Like-for-like replacement by

replacing oil-filled cables with

XLPE;

2. Retirement of 91X and 91Y feeder

– part of Powering Sydney Future

Strategy (PSF), please refer to

PSF for more detail;

3. Defer retirement and replacement

of feeder 91X and 91Y via demand

management.

Assessment for non-network solutions was

completed as part of the joint planning

process with Transgrid for the Inner Metro

Transmission network. A consultation paper

seeking expressions of interest from non-

network providers to address the

transmission needs in the Inner Sydney

area has been published at

www.transgrid.com.au. Submissions to the

expression of interest close 13 January

2017..

4. Feeder 92C

(Formerly

known as:

91A/2) and 92X

(Formerly

91B/2) – St

Peters to

Post

2021

Asset Condition NA None Credible solutions include:

1. Like-for-like replacement by

replacing oil-filled cables with

XLPE;

2. Retirement of 92C and 92X feeder

– part of Powering Sydney Future

December 2016 92

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

Chullora STSS Strategy (PSF), please refer to

PSF for more detail;

3. Defer retirement or replacement of

feeder 92C and 92X via demand

management.

Assessment for non-network solutions was

completed as part of the joint planning

process with Transgrid for the Inner Metro

Transmission network. A consultation paper

seeking expressions of interest from non-

network providers to address the

transmission needs in the Inner Sydney

area has been published at

www.transgrid.com.au. Submissions to the

expression of interest close 13 January

2017.

5. Feeders 92G

and 92J – Lane

Cove STSS to

Top Ryde and

Meadowbank

ZS

Sep-19 Asset Condition NA None Credible solutions include:

1. Like-for-like replacement by

replacing oil-filled cables with

XLPE;

2. Retirement of 92G and 92J feeder

, and transfer approximately 50%

of Top Ryde and Meadowbank

load to neighbouring zone

substations;

3. Replacement with a single circuits;

4. Defer retirement or replacement of

feeder 92G & 92J via demand

management.

Assessment for non-network solutions, had

previously determined that it was not

considered reasonable for demand

management to offer a cost effective option

for this network system limitation.

6. Feeder 264 –

Beaconsfield

BSP to

Kingsford ZS

Dec-20 Asset Condition NA None Credible solutions include:

1. Retirement of feeder 264 by transferring Maroubra and Kingsford ZS loads to surrounding zones;

2. Like-for-like replacement by replacing oil-filled cables with XLPE;

December 2016 93

Substation/Feeder name

System limitation Load reduction for 1 year deferral (MVA)

Impact on Transmission-Distribution Connection Points

Discussion of Potential Credible Solutions

Timing Driver

3. Replacement of feeder via proposed new zone in Mascot area;

4. Defer replacement or retirement of

feeder 264 via demand management of Maroubra and Kingsford zone loads.

Note this project is also included in the list of

Eastern Suburbs load area projects. As

noted in Section 4.4.4, a preliminary

assessment for non-network solutions

concluded that it is probable there is a

potential opportunity for demand

management to form part of the least cost

solution. As the assessment was based

upon preliminary assumptions for project

costs, unserved energy and other benefits,

a more detailed assessment will be

conducted to fully assess the viability of the

option.

7. Feeder 265 –

Bunnerong STS

to Maroubra ZS

Dec-20 Asset Condition NA None Credible solutions include:

1. Retirement of feeder 265 by transferring Maroubra ZS loads to surrounding zones;

2. Like-for-like replacement by replacing oil-filled cables with XLPE;

3. Defer replacement or retirement of

132kV feeder via demand management of Maroubra loads.

Note this project is assessed as part of the

Eastern Suburbs load. Please refer to

Section 4.4.4.

5.5.5 Identified Feeder limitations changes from last year’s DTAPR - deferred or committed projects

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Feeders 9SA and 92P – Beaconsfield BSP to Campbell St ZS and Belmore Park ZS

Post 2026

Asset Condition Change in assessment methodology

Feeders 92L/3 and 92M/1 – Lane Cove STSS to Dalley St ZS

Jun-18 Asset Condition Committed

Feeders 9S6/1 and 9S9/1 – Haymarket BSP to Pyrmont STS

Post 2026

Asset Condition Change in assessment methodology

December 2016 94

Substation/Feeder Name System Limitation Reason for Deferral

Timing Driver

Feeders 90X and 92F – Mason Park STSS to Meadowbank ZS and Top Ryde ZS

Mar-18 Asset Condition Committed

New feeder 90Y – Beaconsfield BSP to Belmore Park ZS

Sep - 16 Capacity/Asset Condition

Committed

5.5.6 Changes in dual function asset status No changes since publication of the December 2015 DTAPR.

5.5.7 Dual function connection points The following section details dual function projects that are driven by network constraints.

5.5.7.1 Completed new dual function connection points

This section This section describes augmentations that have been completed since the publication of 2015 DTAPR.

Belmore Park 132/11kV zone substation

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 energisation of the high voltage busbar, switchgear and feeder connections were completed in December 2014, energisation of power transformers were completed in early 2015 and final commissioning was completed in April 2016.

5.5.7.2 Proposed augmentation of existing dual function connection points

Ausgrid has not identified any constraints to the capacity of existing dual function connection points in the next 10 years.

5.5.7.3 Committed new dual function connection points

Ausgrid has identified committed new dual function network connection points as tabulated below.

Region Proposal Purpose Timing

Sydney Belmore Park 132/11kV Zone Substation

Licence condition N-2 security standard

Dec-15

Sydney Alexandria 132/33kV STS

Replacement of 33kV feeder to Mascot ZS and Sydney Airport, and new spot loads from major customer Equinix data centre.

Dec-17

Sydney Rockdale 132/11kV Zone Substation

Replace existing 33kV (distribution) infrastructure

Mar-18

December 2016 95

6 Planning proposals for future needs

6.1 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 2015 to 2019.

Planning proposal for future Transmission-Distribution Connection Point

Location Transmission – Distribution Connection Point

Voltage

(kV) Identified Need

Proposed

Commissioning Date

Nil

6.2 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

Location Transmission – Distribution Connection Point

Voltage

(kV) Identified Need

Proposed

Commissioning Date

Canterbury Bankstown

New Strathfield South ZS 132/11

33kV feeders and

11kV switchgear

condition issues

at Enfield ZS

Sep-19

New Summer Hills ZS 33/11

33kV feeders and

11kV switchgear

condition issues

at Dulwich Hill ZS

Jan-21

New Greenacre ZS 132/11

132kV feeder and

11kV switchgear

at Greenacre

Park ZS

Oct-20

Eastern Suburbs New Mascot ZS 132/11

33kV feeders and

11kV switchgear

condition issues

at Mascot ZS, as

well as 132kV

feeders 264, 265

and 91M/3

Dec-20

6.2.1 Changes to proposed future sub-transmission STS and zone substations The following table presents the proposed future sub-transmission substations projects reported in last year’s DAPR which have been cancelled.

Changed planning proposal for future STS and ZS

Location Transmission – Distribution Connection Point

Voltage

(kV) Identified Need

Proposed

Commissioning Date

Nil

6.3 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.

December 2016 96

Planning proposal for future Subtransmission feeders

Location Transmission – Distribution Connection Point

Voltage

(kV) Identified Need

Proposed

Commissioning Date

Canterbury Bankstown

Looping in Strathfield South ZS in to existing feeder 911

132

33kV feeders

and 11kV

switchgear

condition

issues at

Enfield ZS

Sep-19

Three feeders from Canterbury STS to Summer Hills ZS

33

33kV feeders

and 11kV

switchgear

condition

issues at

Dulwich Hill ZS

Jan-21

Eastern Suburbs

New Airport feeders from proposed Alexandria STS

33

Sydney Airport

33kV feeders

condition

issues

Dec-18

New International Terminal feeders from Alexandria STS

33

International

Terminal 33kV

feeders

condition

issues

Dec-18

Inner West New 33kV feeders to Auburn and Lidcombe ZS from Endeavour Energy Camellia TS

33

33kV feeder

condition

issues at

Auburn and

Lidcombe ZS

Sep-19

Lower North Shore New 132kV feeders from Willoughby STS to Mosman ZS

132

132kV feeder

9Y7/2 and

9Y9/2 condition

issue

Sep-22

6.3.1 Changes to proposed future sub-transmission feeders The following table presents the proposed future sub-transmission feeder projects reported in last year’s DAPR which have been cancelled.

Changed planning proposal for future Subtransmission feeders

Location Transmission – Distribution Connection Point

Voltage

(kV) Identified Need

Proposed

Commissioning Date

Nil

6.4 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.

6.4.1 Proposed future sub-transmission substation loading levels 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

Location Sub-transmission Forecast Summer Load

December 2016 97

substation 2015/16 2016/17 2017/18 2018/19 2019/20

Canterbury Bankstown

Strathfield South ZS MVA - - - - 20.8

PF - - - - 0.93

Summer Hill ZS MVA - - - - -

PF - - - - -

Greenacre ZS MVA - - - - -

PF - - - - -

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

Location Sub-transmission

substation

Forecast Summer Load

2015 2016 2017 2018 2019

Canterbury Bankstown

Strathfield South ZS MVA - - - - -

PF - - - - -

Summer Hill ZS MVA - - - - -

PF - - - - -

Greenacre ZS MVA - - - - -

PF - - - - -

6.5 Proposed future dual function connection points Ausgrid has identified proposed new dual function network connection points as tabulated below.

Region Proposal Purpose Timing

Sydney Strathfield South 132/11kV Zone Substation (previously known as Enfield)

Replace existing 33/11kV Enfield ZS (distribution) infrastructure

Sep-19

December 2016 98

7 Network investments

7.1 Regulatory investment tests

7.1.1 completed during the year The installation of a new 132kV feeder from Beaconsfiled Bulk Supply Point to Belmore Park Zone Substation was a Regulatory Test completed during the year. A regulatory Test Final Report was published on 09 May 2016. This regulatory test commenced prior to 31 December 2013.

The primary driver for the installation of a new 132kV feeder is asset condition requiring asset replacement. In the past there was a capacity need as presented in the Consultation Paper published on December 2013. The project was driven by system capacity limitations on circuits 9SA and 92P (formerly 9SB/1) from Beaconsfield to Haymarket Bulk Supply Points (BSPs). Recent reductions in load in the Inner Metropolitan load area has altered the primary driver of this project to be the condition of 132kV circuits 92L/3 and 92M/1 from Lane Cove Sub-transmission Switching Station (STSS) to Dalley St Zone Substation (ZS). Due to the proposed changes in the topology of the network, Ausgrid considered it prudent to issue a Final Report. The proposed 132kV feeder 90Y from Beaconsfield BSP to Belmore Park ZS is considered to be a dual function asset.

The Final Report outlines the possible asset replacement options to address the issues affecting the supply network. The following options were identified:

Option 1: Installation of a new 132kV circuit from Beaconsfield to Belmore Park and partial remediation of circuits 9SA and 92P, at a net present cost of $106 million;

Option 2: Full remediation of circuits 9SA and 92P and Demand Management, at a net present cost of $145 million;

Option 3: Early replacement of circuits 9SA and 92P and Demand Management, at a net present cost of $165 million; and

Option 4: Replacement of circuits 92L and 92M and Demand Management, at a net present cost of $343 million.

The recommended action is to proceed with Option 1 – Installation of a new 132 feeder 90Y from Beaconsfield BSP to Belmore Park ZS. This option includes the installation of the new feeder 90Y utilising a spare duct and Ausgrid and TransGrid tunnels, and the partial remediation of circuits 9SA and 92P .

The construction of the new feeder 90Y and the retirement of 132kV circuits 92L/3 and 92M/1 from Lane Cove STSS to Dalley St ZS obtained Gate 3 approval (final project approval) in March 2016. The estimated cost for these works is $21 million. These works are expected to be finalised in 2018/19.

The partial remediation of circuits 9SA and 92P is at development stage. Since these circuits have been recommended for replacement by mid 2020s, their like-for-like replacement is also considered as part of the preferred option

7.1.2 in progress during the year This section describes the Regulatory Investment Test (RIT) that were commenced in 2016 as well as the Regulatory Tests that were commenced prior to 31 December 2013 that remain in progress.

7.1.2.1 System limitations in the Inner Sydney Transmission Area

A Project Specification Consultation Report (PSCR) has been jointly published by TransGrid and Ausgrid on 13 October 2016 to initiate the Regulatory Investment Tests –Transmission process for options to address capacity constraints and asset condition issues in the Inner Sydney area.

The specific issues driving the need for a solution in the Inned Sydney Transmission network are:

The deteriorating condition and reduced capability of TransGrid 330kV cable 41, which was de-rated from 663MVA to 575MVA in 2011 and also from 575MVA to 426MVA in 2016;

The deteriorating condition of several Ausgrid 132kV oil-filled circuits installed in the 1960s and 70s:

o 928/3 and 929/1 between Lane Cove STSS and Dalley St ZS;

o 92C and 92X (formerly 91A/2 and 91B/2) between Chullora STSS and St Peters ZS;

o 91X and 91Y between Chullora STSS and Beaconsfield BSP via Marrickvilles ZS;

o 90T/1 between Haymarket BSP and GreenSquare ZS; and

o 9S2 between Beaconsfield BSP and Haymarket BSP.

December 2016 99

Taking into account the asset condition issues listed above and the latest available demand forecast, a solution is required to meet Inner Sydney Transmission network constraints by 2021/22. A total of six credible options have been identified as part of the PSCR, all of which involve building new 330kV cables between TransGrid’s Rookwood Road and Beaconsfield BSPs:

Option 1: install two 330kV cables in stages, retire cable 41 and retire Ausgrid cables in two stages (indicative capital cost of $435 million);

Option 2: operate cable 41 at 132kV, install two 330kV cables in stages and retire Ausgrid cables in two stages (indicative capital cost of $443 million);

Option 3: install two 330kV cables at once, retire cable 41 and retire Ausgrid cables in one stage (indicative capital cost of $417 million);

Option 4: remediate cable 41, install two 330kV cables in stages and retire Ausgrid cables in one stage (indicative capital cost of $560 million);

Option 5: remediate cable 41, install two 330kV cables at once (initially operating at 132kV) and retire Ausgrid cables in two stages (indicative capital cost of $555 million);

Option 6: remediate cable 41, install two 330kV cables at once and retire Ausgrid cables in one stage (indicative capital cost of $542 million).

A Project Assessment Draft Report (PADR), including the complete economic evaluation of credible options and consideration of non-network solutions, is expected to be published by March 2017.

7.1.2.2 Top Ryde additional 132/11kV transformer and switchgear

DTAPR 2013 reported that a Regulatory Test Final Report would be published by June 2014. Reductions in the Top Ryde / Macquarie Park load forecast have deferred the need for an additional transformer and 11kV switchgear to 2027. This project will not proceed within the next ten years therefore a Regulatory Test Final Report is no longer required.

7.1.3 For the forward planning period - Distribution There is no proposed distribution asset identified that is subject to the RIT-D economic evaluation and no consulation is anticipated within 12 months.

7.1.3.1 Longer term constraints and indicative developments

The following section provides an overview of dual function network constraints that are expected to arise over a time frame that is longer than 5 years. Estimated costs are in nominal dollars.

Region Constraint Indicative Development Expected Completion

Estimated Cost ($million)

Sydney Load Growth Pymble ZS additional 33/11kV transformer and associated equipment

Sep-25 17.4

Pymble ZS additional 33/11kV Transformer and associated equipment

Potential load growth in the Upper North Shore area is expected to result in a capacity constraint at Pymble ZS. Options to address this issue included:

Installation of a fourth 33/11kV transformer and associated 11kV switchgear at Pymble ZS, as well as a new 33kV feeder between Kuringai STS and Pymble Zone Substation by September 2025

11kV load transfers to nearby zone substations (i.e. St Ives or Turramurra)

Demand management and/or local generation.

The most likely network option to address the constraint is the installation of a fourth 33/11kV transformer at Pymble ZS and asscoiated equipment to be completed by September 2025.

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.

7.1.4 For the forward planning period – Dual Function 7.1.4.1 Constraints emerging within 5 years – consultation anticipated within 12 months

The table below shows the dual function assets for which a RIT-D economic evaluation is anticipated within 12 months.

Project Name Identified need date

Identified Need Estimated Cost ($million)

December 2016 100

Project Name Identified need date

Identified Need Estimated Cost ($million)

New 132/11kV Transformer at Kingsford ZS

Jun-2019 Capacity constraints due to uncommitted spot loads.

5.7

In the event the spot loads are committed, it is expected that initial project development investigations and the RIT-D economic evaluation will be initiated by Jan 2017.

7.1.4.2 Constraints emerging within 5 years – consultation anticipated beyond 12 months

There is no proposed dual function asset identified that is subject to the new RIT-D economic evaluation and no consultation is anticipated beyond 12 months.

7.1.4.3 Longer term constraints and indicative developments

The following section provides an overview of dual function network constraints that are expected to arise over a time frame that is longer than 5 years. Estimated costs are in nominal dollars.

Region Constraint Indicative Development Expected Completion

Estimated Cost ($million)

Sydney Load Growth Warnervale 132/11kV ZS Sep-21 31.7

Warnervale 132/11kV zone substation

Potential 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 2020

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 to be completed by September 2021.

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.

This project has not yet been committed, as it is driven by major customers. If committed, initial project development investigations and the RIT-D economic evaluation will be initiated by December 2017.

7.1.5 Not proceeding The table below shows the RIT-D projects with distribution assets identified in the preceding DTAPR which are now not expected to proceed to the RIT-D consultation and assessment process in the next five years.

Project Name Previous Identified need date

Previous Proposed RIT-D date

Reason for not proceeding

Kurri STS – Rutherford ZS 33kV Feeders KU8 and KU13 upgrade

Jan-2020 No date

proposed

Due to a reduced demand forecast, the proposed upgrade is no longer required for feeder KU8, while for feeder KU13 it has been deferred to Nov-2026.

Telarah ZS – Rutherford ZS 33kV Feeder 30012 upgrade

Jan-2020 No date

proposed

Due to a reduced demand forecast, the proposed upgrade has been deferred to Nov-2030.

Maitland ZS – Metford ZS 33kV Feeder 30028 upgrade

Jan-2020 No date

proposed

Due to a reduced demand forecast, the proposed upgrade to a higher capacity conductor is no longer required.

December 2016 101

The following dual function asset augmentations or replacement projects described in DTAPR 2015 have either been deferred beyond the ten year forward planning period or cancelled.

Region Project Need Date Reason for cancellation/deferral

Sydney Top Ryde ZS additional 132/11kV transformer and 11kV switchgear

Deferred to 2027

Reductions to Top Ryde/Macquarie Park load forecast has extended the need date for the project

Sydney Campbell St ZS 132kV additional transformer

Deferred to 2030

Reduced load forecast in Campbell St / Surry Hills area.

Sydney 132kV feeder development from Lane Cove STSS to Pyrmont STS

Cancelled

Change of strategy, Due to de-rating of TransGrid cable 41, and change of joint planning strategy from 132kV Lane Cove - Pyrmont option, to 330kV Rookwood Road - Beaconsfield BSP option

7.1.6 For previously planned augmentations Ausgrid conducts a review of feasible options to relieve the emerging network constraint, including non-network 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 test or RIT-D.

There is no proposed augmentation that has been identified and subject to the new RIT-D economic since the publication of DTAPR 2015.

7.1.7 Proposed 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.

Estimated costs are in nominal dollars.

Region Refurbishment Completion Date

Estimated Cost ($m)

Sydney Replacement of 132kV Feeders 92GA/B between Lane Cove STSS and Top Ryde, and Feeders 92JA/B between Lane Cove STSS and Meadowbank ZS

Jun-19 18.9

Sydney New Strathfield South 132/11kV ZS, associated 132kV feeder connections and decommissioning of Enfield 33/11kV ZS

Sep-19 28.2

Sydney Remediation of 132kV Feeders 9SA and 92P between Beaconsfield BSP and Campbell St ZS and Belmore Park ZS

Sep-19 1.6

Hunter Refurbishment of Muswellbrook 132/33kV STS Jun-20 5.4

Sydney Waverley ZS additional 132/11kV transformer Jun-20 12.0

Hunter Replacement of 132kV Feeder 961 (oil section) between Merewether STS and Glebe STSS

Dec-20 4.9

Sydney Replacement of 132kV Feeder 91M/3 (Sumutomo oil section) between Beaconsfield BSP and Bunnerong North STS

Sep-21 19.8

Sydney New Mascot East 132/11kV ZS, associated 132kV connections and decommissioning of Mascot 33/11kV ZS

Dec-21 36.1

December 2016 102

Region Refurbishment Completion Date

Estimated Cost ($m)

Sydney Replacement of 132kV Feeder 264 between Beaconsfield BSP and Kingsford ZS

Dec-21 21.1

Sydney Decommissioning 132kV Feeders 928/3 & 929/1 between Lane Cove STSS and Dalley St ZS

Sep-22 3.5

Sydney Decommissioning 132kV Feeder 90T/1 between Beaconsfield BSP and Green Square

Sep-22 0.7

Sydney

Decommissioning of 132kV Feeders 92C & 92X (formerly 91A/2 & 91B/2) between Chullora STSS and St Peters ZS, as well as 91X & 91Y between Chullora STSS and Beaconsfield BSP via Marrickvilles ZS

Sep-22 9.3

Sydney Replacement of 132kV Feeder 265 between Maroubra ZS and Bunnerong North STS

Dec-22 19.4

Sydney Replacement of 33kV oil-filled reactors at Bunnerong North STS Dec-23 5.6

Sydney Decommissioning 132kV Feeder 9S2 between Beaconsfield BSP and Haymarket BSP

Sep-24 1.0

Hunter Replacement of 132kV Feeder 960 (oil section) between Merewether STS and Glebe STSS

Sep-24 5.4

Sydney Replacement of 132kV Feeders 9S6/1 & 9S9/1 from Pyrmont STS to Haymarket BSP

Sep-26 64.3

Sydney Replacement of 132kV Feeders 9SA & 92P between Beaconsfield BSP and Campbell St ZS and Belmore Park ZS

Sep-26 88.7

Sydney Replacement of 11kV Switchgear St Peters ZS Dec-26 37.5

Sydney Replacement of 132kV Feeders 91A/1 & 91B/1 between Beaconsfield BSP and St Peters ZS

Dec-27 8.9

Sydney Replacement of 132kV Feeder 9SE between Beaconsfield BSP and Green Square ZS

Sep-28 7.5

Sydney Replacement of 132kV Feeder 270 between Kingsford ZS and Maroubra ZS

Dec-28 11.6

Sydney Replacement of 11kV Switchgear Marrickville ZS Dec-29 33.0

7.1.7.1 Lane Cove STS to Top Ryde 132kV feeder 92G, and Lane Cove STS to Meadowbank ZS 132kV feeder 92J replacement

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 1970’s. 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 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. The expected completion date for this project is June 2019.

7.1.7.2 New Strathfield South 132/11kV ZS

There are emerging asset condition issues in the Enfield 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. The 33kV gas filled feeders supplying Enfield have also been prioritised for replacement in the period 2014-2019.

Potential credible options identified to address this issue include:

A new Strathfield South 132/11kV ZS (previously referred to as Enfield 132/11kV ZS)

A new Enfield 33/11kV ZS, and

Demand management and/or local generation.

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The most likely network option is to develop the new Strathfield South 132/11kV ZS. Investigation of non-network options will continue to be pursued. This project is expected to be completed by September 2019.

7.1.7.3 Remediation of 132kV Feeders 9SA and 92P between Beaconsfield BSP and Campbell St ZS and Belmore Park ZS

These feeders connect Beaconsfield Bulk Supply Point to Campbell St Zone Substation (Feeder 9SA) and to Belmore Park Zone Substation (Feeder 92P - formerly known as 9SB/1). They form part of the major transmission supply to the Sydney CBD and Eastern Suburbs network areas. A review of the installation conditions in these feeders identified previously unknown limitations with the thermal properties of the backfill material around the cables. To prevent damages in the feeders, their ratings were reduced from 250MVA to 135MVA each.

A network solution is proposed to improve thermal properties of native soil/ backfill material and increase current rating of 132kV fluid filled Feeders 9SA and 92P.

Potential credible options include partial replacement of backfill material on critical sections of the feeders, complete replacement of backfill material along the entire length of the feeders, or bring forward the replacement of the oil-filled cables. Demand Management solutions are required in combination with some of the remediation options. As reported in section 7.1.1, the preferred option is to undertake partial remediation of the feeders. The expected completion date for this project is September 2019.

7.1.7.4 Refurbishment of Muswellbrook 132/33kV STS

Muswellbrook STS was commissioned in 1964, utilising the switchyard of the old Muswellbrook Power Station that operated adjacent to the site. The 33kV switchgear remains original since its installation date and is recommended to be removed or replaced. The substation control room is a structure with no fire rating or air conditioning systems, and the control and protection is distributed throughout the substation in large metal boxes (protection huts), which do not provide a suitable environment for modern relays.

Potential credible options to address the issues above are:

Establishment of a new Muswellbrook 132/11kV ZS to replace the existing Muswellbrook STS and Muswllbrook 33/11kV ZS; and

Refubishment of the existing Muswellbrook STS and Muswellbrook ZS.

All options including demand management are still under consideration. The most likely network option is to refurbish the existing assets. This project is expected to be completed by June 2020.

7.1.7.5 Waverley ZS additional 132/11kV transformer

There are emerging asset condition issues in the Clovelly network area. The 11kV compound insulated switchgear (switchgroup 1) at Clovelly 132/11kV ZS is aproaching end of its service life and is prioritised for replacement in the period 2017-19. The 11kV air insulated switchgear (switchgroup 2) is recommended for replacement 10 years later. In addition, a risk assessment of the three 132kV oil-filled feeders supplying Clovelly ZS recommends the replacement of feeders 260/2 and 261/2 between Zetland ZS and Clovelly ZS (approximately 4.5km long) by 2020 and the remaining feeder 262 between Double Bay ZS and Clovelly ZS (approximately 3.1km long) by 2028.

Potential credible options to address the issues above are:

Establishment of a new 132/11kV zone substation at Clovelly to replace the existing Clovelly ZS and associated 132kV feeder connections;

Staged replacement/retirement works, which involve the transfer of load to neighbouring substations to allow retirement of the 11kV compound insulated switchgear in 2019, and the replacement of the 11kV air insulated switchgear by 2027. This option would also include the replacement of 132kV feeders 260/2 and 261/2 by 2020 and the replacement of feeder 262 by 2028; and

Retirement of Clovelly ZS and associated 132kV feeder connections by transferring most of the load to Waverley ZS, which will require the installation of an additional third 132/11kV transformer. This option may include a demand management solution to defer the installation of the 132/11kV transformer.

All these options are still under consideration, however the most likely network option is to retire Clovelly ZS by transferring most of the load to Waverley ZS. This project is expected to be completed by June 2020.

7.1.7.6 Replacement of 132kV Feeder 961 (oil section) between Merewether STS and Glebe STSS

Feeder 961 is approximately 900 metres long and was installed in 1967. It comprises two parallel oil-filled underground cables that are approaching the end of their service life. An updated risk assesment recommends the replacement of this feeder in the period 2019-24.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is December 2020.

7.1.7.7 Replacement of 132kV Feeder 91M/3 (Sumutomo oil section) between Beaconsfield BSP and Bunnerong North STS

Feeder 91M/3 is approximately 9.3km long and was installed in 1973. A section of this feeder is currently being replaced, between Bunnerong North STS and Mill Pond Rd, Botany. The remaining section, from Mill Pond Rd to Beaconsfield BSP, is recommended for replacement in the period 2024-29. However, sinergies between this feeder replacement and other projects in the area have been identified and it is considered advantageous to bring forward the replacement of feeder 91M/3 remaining section, in order to make it in conjunction with the project to replace the existing Mascot ZS and the replacement of feeder 264 between Beaconsfield BSP and Kingsford ZS.

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Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is September 2021.

7.1.7.8 New Mascot East 132/11kV ZS, associated 132kV connections and decommissioning of Mascot 33/11kV ZS

The existing Mascot 33/11kV ZS has asset condition issues associated with its 11kV switchgear and the 33kV feeders supplying the substation.

Of the five groups of 11kV switchgear at Mascot ZS, three of them are compound insulated and the remaining two groups are air insulated. A risk analysis has recommended implementing the replacement of the 11kV switchboard at Mascot zone substation as soon as possible, as it offers economic benefits that exceed the annualised project costs since the first year of the analysed period (2015-2034).

In addition, the 33kV paper insulated feeders 327, 328, 332, 337, 341 and 360, between Bunnerong North STS and Mascot ZS (approximately 8km long), are aged (some of them dates back to 1930) and have been prioritised for replacement in 2020.

Potential credible options to address the issues above are:

Establishment of a new Mascot 132/11kV ZS and associated 132kV feeder connections to replace the existing Mascot ZS and associated 33kV feeders;

Retirement of the existing Mascot ZS and associated 33kV feeders by transferring the 11kV load to neighbouring substations (i.e. Green Square ZS);

Refurbishment of the existing Mascot ZS and replacement of the existing 33kV feeders with new XLPE cables from Bunnerong North STS; and

Refurbishment of the existing Mascot ZS and replacement of the existing 33kV feeders with new XLPE cables from Alexandria STS (currently in construction).

All replacement options are currently under review. Given that three high capacity 132kV feeders crossing the Mascot network area have been shorlisted for replacement/retirement in the 2020s, the most cost effective solution is likely to be the new Mascot 132/11kV ZS, provided it is located at a site that best realise the network developments associated with the 132kV feeder replacement projects in the area.

The expected completion date for this project is December 2021, noting that a risk mitigation action is required earlier to address issued with the deteriorating 11kV switchgear at Mascot ZS. In this case, a significant transfer of 11kV load from Mascot to Green Square ZS in 2018 is proposed to mitigate the identified risk.

7.1.7.9 Replacement of 132kV Feeder 264 between Beaconsfield BSP and Kingsford ZS

Feeder 264 is an oil-filled underground cable, approximately 5.5km long, which was installed in 1977. The oil-filled cable have been identified as approaching the end of its service life. A risk assessment has confirmed the need to replace this cable in 2020.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. Sinergies between this feeder replacement and other projects in the area have been identified, and therefore it is considered advantageous to carry out these replacement works in co-ordination with the replacement of feeder 91M/3 remaining section (refer to section 7.1.7.7) and the project to replace the existing Mascot ZS (section 7.1.7.8).

As a result, the expected completion date for this project is December 2021.

7.1.7.10 Decommissioning 132kV Feeders 928/3 and 929/1 between Lane Cove STSS and Dalley St ZS

Feeders 928/3 and 929/1 are approximately 12km long, oil-filled cables installed in 1966 and 1963 respectively. These cables are aged and include a submarine section that traverse environmentally sensitive areas such as the Sydney Harbour.

Potential credible options to address identified condition issues include:

Install two 132kV feeders from Lane Cove STSS to a new Northern CBD STSS;

Install two 132kV feeders from Lane Cove STSS to Pyrmont STS; and

Install new 330kV cables in TransGrid’s network and retire Ausgrid’s feeders supporting the Sydney Inner Metro transmission area, among which feeders 928/3 and 929/1 are included.

Replacement options and potential use of non-netowrk solutions are still under consideration, however the most likely option is to build new 330kV cables between TransGrid’s Rookwood Road and Beaconsfield BSPs. As this solution is addressing capacity constraints and asset condition issues in the Inner Sydney area, a RIT-T process has been jointly initiated by Ausgrid and TransGrid (refer to section 7.1.2.1).

7.1.7.11 Powering Sydney’s Future project, replacing 91X/Y, 92C, 92X, 90T/1 and 9S2 with new 330kV feeders from Rookwood Road BSP to Beaconsfield BSP

Ausgrid transmission network incorporates a large number of aging, oil-filled 132kV cables, and the following feeders are planned to be retired between September 2022 and September 2024. These dual functional assets provide capacity support to the Transmission Network; after their retirements, there would be emerging capacity constraints on the Sydney Inner Metro Area. In order to resolve these issues, Ausgrid and TransGrid proposed a joint planning solution, to install new 330kV cables from Rookwood BSP to Beaconsfield BSP, with required 330kV GIS switchgear.

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Retirement of 132kV feeders 91X and 91Y

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, and it is recommended to decommission these cables in September 2022.

Retirement of 132kV feeder 92C (formerly 91A/2) and 92X (formerly 91B/2)

The existing 132kV feeder 92C and 92X consists of oil-filled underground cables commissioned in 1968, with an approximate length of 14.3km. Ausgrid has a policy to progressively remove aging oil-filled cables from the network to reduce risks of oil leaks and decreasing ability to maintain these cables. As part of this policy, feeder 92C has been prioritised for retirement in 2018.

However, due to emerging constraint from the retirement of 92C in 2018, Ausgrid is now considering if maintenance tasks can be carried out to reduce the risk associated with continued operation of 92C for four more years, and will retain 92C until September 2022, to aligh with the retirement of 92X.

Retirement of 132kV feeder 90T/1 (Oil section)

The existing 132kV feeder 90T consists of oil-filled cables, approximately 4.0km long, commissioned in 1981. It is recommended that this section of the cable will be retired in September 2022.

Retirement of 132kV feeder 9S2

The existing 132kV feeder 9S2 from Beaconsfield BSP to Haymarket BSP, consists of oil-filled underground cables, approximately 5.0km long, commissioned in 1988. It is recommended that the feeder will be retired in September 2024.

7.1.7.12 Replacement of 132kV Feeder 265 between Maroubra ZS and Bunnerong North STS

Feeder 265 is an oil-filled underground cable, approximately 3.8km long, installed in 1979. An updated risk assesment recommends the replacement of this feeder in the period 2019-24, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is December 2022.

7.1.7.13 Replacement of 33kV oil-filled reactors at Bunnerong North STS

Bunnerong North STS is a relatively new installation. However, the 33kV reactors at this substation will require replacement due to their age and deteriorating condition. They were originally installed at the Bunnerong Power Station in the 1940s, and then reutilised when the substation was rebuilt.

Only those reactors required for fault level limitation or current balancing between feeders that will remain connected to Bunnerong North STS need to be replaced. Due to the required timing of several 33kV feeder replacement projects for zone substations supplied from Bunnerong North STS (i.e. 2027 for the 33kV feeders supplying Matraville ZS, and 2029 for the 33kV feeders suplying Botany ZS), the replacement of the required 33kV reactors is proposed for the period 2024-29. The expected completion date for this project is December 2023.

7.1.7.14 Replacement of 132kV Feeder 960 (oil section) between Merewether STS and Glebe STSS

Feeder 960 is approximately 900 metres long and was installed in 1976. It comprises two parallel oil-filled underground cables that are approaching the end of their service life. An updated risk assesment recommends the replacement of this feeder in the period 2024-29.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is September 2024.

7.1.7.15 132kV feeder 9SA and 92P replacement

132kV feeder 9SA from Beaconsfield BSP to Campbell St ZS, and 132kV feeder 92P from Beaconsfield BSP to Belmore Park ZS are oil-filled underground cables commissioned in the 1970s. These cables are approximately 5.7km and 5.5km long respectively. An updated risk assesment recommends the replacement of these feeders in the period 2024-29, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is September 2026.

7.1.7.16 132kV feeder 9S6/1 & 9S9/1 replacement

The existing 132kV feeder 9S6/1 and 9S9/1 from Haymarket BSP to Pyrmont ZS, consists of oil-filled underground cables commissioned in 1980s. These cables are approximately 1.9k long. An updated risk assesment recommends the replacement of these feeders in the period 2024-29, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is September 2026.

7.1.7.17 Replacement of 11kV Switchgear St Peters ZS

The existing St Peters 132/11kV ZS has asset condition issues associated with its 11kV switchgear. An updated risk assesment recommends the replacement of the air insulated 11kV switchgear in 2026, due to age and condition issues.

Potential credible options to address the issues above are:

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Replacement of the existing 11kV switchgear at St Peters ZS with new switchgear in a new switchroon on a block of land adjacent to the existing substation;

Retirement of St Peters ZS via 11kV load transfers to surrounding substations (i.e. Marrickville ZS and Zetland ZS), provided there is sufficient capacity to accommodate this load; and

Establishment of a new St Peters 132/11kV ZS and associated 132kV connections in a nearby site to replace the existing St Peters ZS.

All these options are still under consideration, however the most likely network option is to replace the 11kV switchgear at St Peters ZS. This project is expected to be completed by December 2026.

7.1.7.18 Replacement of 132kV Feeders 91A/1 & 91B/1 between Beaconsfield BSP and St Peters ZS

Feeders 91A/1 and 91B/1 consists of oil-filled underground cables commissioned in 1968, with an approximate length of 1.5km. An updated risk assesment recommends the replacement of this feeder in the period 2024-29, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is December 2027.

7.1.7.19 Replacement of 132kV Feeder 9SE between Beaconsfield BSP and Green Square ZS

Feeder 9SE is an oil-filled underground cable, approximately 1.0km long, installed in 1988. An updated risk assesment recommends the replacement of this feeder in the period 2024-29, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is September 2028.

7.1.7.20 Replacement of 132kV Feeder 270 between Kingsford ZS and Maroubra ZS

Feeder 270 is an oil-filled underground cable, approximately 2.4km long, installed in 1979. An updated risk assesment recommends the replacement of this feeder in the period 2024-29, due to age and condition issues.

Replacement options are still under consideration, however the most likely option is to replace the oil-filled cable sections with XLPE cable. The expected completion date for this project is December 2028.

7.1.7.21 Replacement of 11kV Switchgear Marrickville ZS

The existing Marrickville 132/11kV ZS has asset condition issues associated with its 11kV switchgear. An updated risk assesment recommends the replacement of the air insulated 11kV switchgear in 2029, due to age and condition issues.

Potential credible options to address the issues above are:

Replacement of the existing 11kV switchgear at Marrickville ZS, by transferring an entire 11kV group load to St Peters ZS to allow staged replacement works; and

Establishment of a new St Peters 132/11kV ZS and associated 132kV connections in a nearby site to replace the existing St Peters ZS.

The option to retire Marrickville ZS via 11kV load transfers to neighbouring substation is not feasible as there is no spare capacity to accommodate the forecasted load. Replacement options are still under consideration, however the most likely network option is to replace the 11kV switchgear at Marrickville ZS. This project is expected to be completed by December 2029.

7.2 Completed or cancelled investments

7.2.1 Refurbishment and replacement - Distribution The following refurbishment or replacement projects described in DTAPR 2015 have either been completed or cancelled during the preceding year.

Load Area Completed or Cancelled Refurbishment or Replacement Investment - Distribution

Reason / comments

Camperdown-Blackwattle Bay

Camperdown 33kV Feeders Replacement Completed

Greater Cessnock New Paxton 33/11kV ZS Completed

Inner West New Olympic Park 132/11kV ZS Completed

Lower North Shore New North Sydney 132/11kV ZS Completed

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Load Area Completed or Cancelled Refurbishment or Replacement Investment - Distribution

Reason / comments

Lower North Shore North Sydney New 132KV Feeders Completed

Lower North Shore Lindfield to Willoughby 132kV Feeders 9E3(2) and 9E4/2 Replacement

Completed

Lower North Shore Lindfield to Castle Cove 132kV Feeders 925/3 and 9E4/3 Replacement

Completed

The following refurbishment or replacement projects were not described in DTAPR 2015 and have either been completed or cancelled during the preceding year.

Load Area Completed or Cancelled Refurbishment or Replacement Investment - Distribution

Reason / comments

Sydney CBD New Bligh St 132/11kV ZS Cancelled – change of preferred network strategy

Sydney CBD Bligh St Building Demolition Works Completed

Sydney CBD Dalley St ZS 11kV Emergency Switchgear Completed

Newcastle CBD New Broadmeadow 132/11kV ZS Completed

7.2.1.1 New Bligh St 132/11kV ZS (cancelled) and Bligh St building Demolition Works (completed)

There are emerging asset condition issues identified in the Sydney CBD network area. City East ZS 11kV compound insulated switchgear and 33kV feeders are at the end of servide life and require replacement. Dalley St ZS 11kV switchgear, 132kV switchgear, and 132kV oil-filled feeders are at the end of service life and require replacement.

Options considered to address the identified issues include:

1. Replace City East and Dalley St with a new Bligh St 132kV ZS. 2. Decommission City East and Dalley St by transferring load to City North and Belmore Park ZSs. 3. Refurbish existing City East ZS and decommission Dalley St ZS

The original preferred option was Option 1 – new Bligh St 132kV ZS. Works to demolish existing building on the Bligh St site commenced to prepare the site for constructing a new ZS. Since then, demand forecast has dropped significantly and recent review showed that Option 2 is the lower cost option and is now preferred.

The project is driven by the need to replace the assets at City East and Dalley St ZSs 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, and therefore demand management was not considered viable.

7.2.1.2 Dalley St ZS 11kV Emergency Switchgear

The condition of the 11kV switchgear at Dalley St ZS is such that it was required to be replaced as soon as practically possible. As credible options to replace this equipment resulted in solution that will take up to 5 years to complete, and the risk of equipment failure was significant, a decision was made in 2013 to implement a short term emergencu recovery strategy, in line with the long term strategy of decommissioning Dalley St ZS in the medium term.

As part of this project, 4 existing capacitors were removed and 20 panels of capacitor switchgear were relocated to create space for the emergency 11kV switchgear.

7.2.1.3 New Broadmeadow 132/11kV ZS

The old Broadmeadow 33/11kV ZS was commissioned in 1941. The majority of the equipment in the substation is at the end of its service life and a decision to replace this substation with a new 132/11kV zone substation.

The options considered to address the identified issues were the establishment of a new 132/11kV substation, or the establishment of a new 33/11kV substation. Given that the 33kV solution also required expenditure to

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upgrade the 33kV network in the Newcastle Inner City area at significantly higher costs, the preferred solution was the establishment of the new Broadmeadow 132/11kV ZS and the retirement of the existing 33/11kV zone substation.

7.2.2 Refurbishment and replacement – Dual Function No dual function asset replacement projects described in DTAPR 2015 have either been completed or cancelled during the preceding year.

7.2.3 Augmentations – Dual Function

The following dual function asset augmentation projects described in DTAPR 2015 have either been

completed or cancelled during the preceding year.

Load Area Completed or Cancelled Refurbishment or Replacement Investment – Dual Function

Reason / comments

Sydney CBD New Belmore Park 132/11kV ZS Completed

Sydney Inner Metro Rookwood Road Bulk Supply Point 132kV Connections

Completed

7.3 Commited 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 nominal dollars.

7.3.1 Refurbishment and replacement investments - Distribution

Load Area Committed Refurbishment or Replacement Investment – Distribution

Timing Estimated Cost ($m)

Camperdown and Blackwattle Bay

Camperdown ZS refurbishment Jan-17 39.7

Camperdown and Blackwattle Bay

Convert Camperdown load from 5kV to 11kV Dec-17 4.1

Canterbury – Bankstown

Punchbowl 11kV Switchgear Replacement Dec-18 23.2

Canterbury - Bankstown

Bass Hill 11kV Switchgear Replacement Apr-18 11.7

Canterbury - Bankstown

Bankstown STS 33kV Switchgear Replacement Jan-19 23.5

Carlingford Hunters Hill Refurbishment Apr-18 31.3

Eastern Suburbs Botany 11kV SG Group 2 & 3 Replacement Apr-2019 11.9

Eastern Suburbs Surry Hills 11kV SG Replacement Oct-20 16.6

Greater Cessnock New Cessnock 33/11kV Zone Nov-18 19.4

Inner West Leichhardt ZS 132kV conversion. May-19 26.9

Inner West New Croydon 132/11kV ZS Jan-18 30.6

Lower Central Coast Peats Ridge 33kV and 11kV Switchgear Replacement.

Apr-17 11.5

Lower Central Coast Umina 11kV SG Replacement May-17 2.3

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Load Area Committed Refurbishment or Replacement Investment – Distribution

Timing Estimated Cost ($m)

Lower North Shore Crows Nest ZS conversion to 132/11kV Jan-17 6.0

Maitland Metford zone substation (East Maitland ZS replacement)

Sep-17 26.8

Newcastle Inner City New Tighes Hill ZS Jan-18 23.9

Newcastle Inner City New Lambton 11kV Switchgear Replacement Jan-17 12.5

Newcastle Inner City Merewether to Newcastle CBD 33kV feeder 770 replacement

Aug-17 12.0

Newcastle Inner City Ex-City Main ZS retaining wall refurbishment Jan-17 6.2

Newcastle Ports Waratah 132/33kV STS refurbishment Feb-18 17.2

North East Lake Macquarie

Merewether to Dudley 33kV feeders 760 & 766 UG section replacement

Jul-18 7.9

Pittwater & Terrey Hills

Careel Bay 33kV and 11kV Switchgear Replacement Mar-17 8.8

Pittwater & Terrey Hills

Mona Vale 11kV Switchgear Replacement Apr-17 4.7

Singleton Branxton 11kV switchgear replacement Mar-17 7.7

Singleton Singleton 11kV switchgear replacement Jul-18 7.9

Upper Central Coast Vales Point 11kV Switchgear Replacement Apr-17 3.8

Upper North Shore Kuring-gai STS 33kV Switchgear Replacement Nov-18 33.3

West Lake Macquarie

New Toronto 132/11kV ZS Jan-18 22.9

West Lake Macquarie

Myuna & Cooranbong ZS 11kV SG replacement Jul-17 4.8

7.3.1.1 Camperdown ZS refurbishment

Most of the equipment at Camperdown has reached the end of its useful life and has been identified for replacement. This work forms part of the overall program to convert the remaining 5kV system to 11kV operation. No other alternative option was considered as this is an asset based replacement.

7.3.1.2 Convert Camperdown load from 5kV to 11kV

Please refer to “Camperdown ZS refurbishment” above for details.

7.3.1.3 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 are 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.

7.3.1.4 Hunters Hill 66/11kV ZS refurbishment

During 2004, 66kV switchgear at Hunters Hill ZS failed explosively with the roof of the building sustaining damage in the resulting blast. The 11kV switchgear is aged and approaching the end of service life.

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This project has two stages: stage 1 involves rebuilding the 66kV switchroom and is close to completion; while stage 2 involves replacement of the 11kV switchgear.

This replacement project is common across all strategies considered in the Carlingford Area Plan. Since this project is driven by asset condition requirements, there are no viable non-network alternatives for this project.

7.3.1.5 New Cessnock 33/11kV ZS

The 11kV switchgear and the 33kV outdoor bulk oil type circuit breakers at the existing Cessnock ZS is approaching their end of service lives, and are recommended to be replaced by 2019 and 2011 respectively.

New Cessnock 33/11kV ZS was common to all strategies considered for the Greater Cessnock Area Plan. No other alternative option was considered as this is an asset condition based replacement.

7.3.1.6 Leichhardt ZS 132kV conversion

The 11kV compound switchgear at Leichhardt ZS is approaching the end of its service life and has been prioritised for replacement. No other alternative option was considered as this is an asset condition based replacement.

7.3.1.7 New Croydon 132/11kV ZS

The existing Five Dock 33/11kV ZS equipment and associated 33kV feeders (distribution assets) are approaching the end of their service life.

The options considered include:

1. New Croydon 132/11kV ZS to decommission existing Five Dock 33/11kV ZS.

2. Retain 33kV in the Eastern Inner West load area - This option involves a like for like replacement of feeder 900 from Mason Park STSS to Rozelle STS. 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.

7.3.1.8 Peats Ridge ZS 33kV and 11kV switchgear replacement

Both the 33kV circuit breakers (bulk oil type) and the 11kV outdoor switchgear at Peats Ridge ZS are at the end of their lives, and are recommended for replacement in 2015. Options investigated included:

1. Peats Ridge ZS 33kV and 11kV switchgear replacement.

2. Retire Peats Ridge ZS - This option involves transferring all the existing 11kV loads from Peats Ridge to Somersby ZS and ultimately decommissioning the existing Peats Ridge 33/11kV ZS.

3. Demand Management - This option is not viable as the issues at Peats Ridge ZS are driven by condition and not capacity.

The preferred and committed option is Option 1 – Peats Ridge ZS 33kV and 11kV switchgear replacement.

7.3.1.9 Crows Nest ZS 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 ZS 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 ZS and retire the existing 33/11kV ZS. No non-network options were considered viable to this asset condition driven replacement project.

7.3.1.10 Metford ZS (East Maitland ZS replacement)

Aged 33kV assets and 11kV switchgear at East Maitland ZS have limited remaining service life.

Options considered include:

1. Metford 132/11kV ZS. The new ZS will increase the capacity of the area.

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.

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7.3.1.11 New Tighes Hill ZS

The 33kV indoor switchgear and 11kV indoor switchgear at Carrington ZS 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. This option 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.

7.3.1.12 Merewether to Newcastle CBD 33kV feeder 770 replacement

Oil-filled 33kV feeder 770 is approaching the end of service life and require replacement due to asset condition issues. The replacement of this feeder is a common requirement across all proposed strategies in the Newcastle Inner City Area Plan. No non-network alternatives were considered viable alternatives to this project.

7.3.1.13 Ex-City Main ZS retaining wall refurbishment

There were civil/structural integrity related issues identified at the decommissioned City Main ZS site. The original proposal of demolishing the ex-City Main ZS buildings was denied by the Newcastle City Council. Therefore the scopes of the project has been revised to reinforce the retaining wall between the ex-City Main ZS site and Newcastle CBD ZS, and some structural stabilisation works at the south western corner of the ex-City Main ZS site. No non-network alternatives were considered viable alternatives to this project.

7.3.1.14 Waratah 132/33kV STS refurbishment

The 33kV industrial busbar at Waratah STS is significantly aged and needs to be retired from service. The 33kV domestic busbar was refurbished in the 1980s but the oil circuit breakers now require replacement. Four out of seven of the 132/33kV transformers are a the end of their service lives.

Options considered include:

1. Waratah STS supply rearrangement and refurbishment. 2. Waratah STS replacement.

The preferred and committed option is to refurbish Waratah STS and rearrange existing 33kV supplies. No non-network options were considered viable to this asset condition driven replacement project.

7.3.1.15 Merewether to Dudley 33kV feeders 760 & 766 UG section replacement

Oil-filled 33kV feeders 760 and766 are approaching the end of their service life and require replacement due to asset condition issues. The replacement of these cables is a common requirement across all proposed strategies in the North East Lake Macquarie Area Plan. No non-network alternatives were considered viable alternatives to this project.

7.3.1.16 Careel Bay ZS 33kV and 11kV ZS switchgear replacement

The 11kV compound switchgear and the 33kV bulk oil type circuit breakers at Careel Bay ZS is approaching the end of its service life and has been prioritised for replacement.

No other alternative option was considered as this is an asset condition based replacement.

7.3.1.17 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.

7.3.1.18 New Toronto 132/11kV ZS

Toronto ZS comprises an outdoor 33kV (bulk oil type circuit breakers) switchyard and an indoor 11 kV busbar. The majority of equipment is approaching the end of its service life.

Options considered are:

1. Toronto 33/11kV ZS. A new 33/11kV substation is constructed in Toronto to replace the existing Toronto ZS. This will result in a net increased capacity and addresses the asset condition issues at Toronto ZS.

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2. Toronto 132/11kV ZS. A new 132/11kV substation is constructed in Toronto to replace the existing Toronto ZS. The new zone will result in a net increased capacity and addresses the asset condition issues at Toronto zone.

The preferred and committed option is Option 2 - Toronto 132/11kV ZS.

The project is driven by the need to replace the assets at Toronto ZS 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, and therefore demand management was not considered viable.

7.3.1.19 11kV switchgear replacement projects

Several Ausgrid zone substations have the 11kV switchgear approaching the end of their service lives.

In cases where there are also asset condition issues with the 132kV or 33kV switchgear and other assets, Ausgrid usually seeks to address the issues collaboratively by a single project, such as refurbishing the zone substation, or establishing a new zone substation and retiring the old one.

In cases where the 11kV switchgear is the sole and primary issue at the zone substation, replacing the 11kV switchgear is generally the most cost effective solution. (Alternate options such as establishing a new zone substation or transferring all load away and retire the zone substation were proved to be not economically feasible in most cases.) This type of 11kV switchgear replacement projects is generally common across all strategies considered in their respective Area Plans. Further, since they are driven by asset condition requirements, there are no viable non-network alternatives for this project.

Below is a list of the zone substations for which the recommended solution is to undertake 11kV switchgear replacement projects in situ:

Bass Hill

Botany

Branxton

Cooranbong

Mona Vale

Myuna

New Lambton

Punchbowl

Singleton

Surry Hills

Umina

Vales Point

7.3.2 Refurbishment and replacement investments – Dual function

Region Committed Refurbishment or Replacement Investment – Transmission

Timing Estimated Cost ($m)

Inner West 132kV feeder 900 Replacement (Mason Park to Rozelle) Dec-16 85.0

Central Coast Gosford STS Refurbishment Dec-16 4.6

Eastern Suburbs Marrickville ring main circuit breaker (RMCB) Jan-17 19.6

Central Coast New Munmorah 132/33kV STS Jan-17 21.9

Sydney Inner Metro

Beaconsfield BSP132kV Busbar Replacement – Feeder Reconnections Apr-17 31.0

Sutherland Kurnell STS 33kV network rearrangement and 33kV Busbar Retirement Jun-17 3.0

Sydney Inner Metro

Installation of New Wholesale Metering Points Jun-17 2.9

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Region Committed Refurbishment or Replacement Investment – Transmission

Timing Estimated Cost ($m)

Sydney Inner Metro

Ausgrid 132kV Sydney North BSP feeder protection & communication upgrade Jun-17 1.9

Sydney Inner Metro

Peakhurst STS to Bunnerong STS and Beaconsfield BSP 132kV Feeders 91L & 91M Replacement Jun-17 182.0

Eastern Suburbs New Alexandria 132/33kV STS Nov-17 33.4

Sydney Inner Metro

Mason Park STS to Top Ryde ZS and Meadowbank ZS Feeders 92F A/B & Feeder 90X A/B Replacement Mar-18 33.9

Canterbury-Bankstown

Canterbury STS 132kV Busbar Replacement and 33kV Switchgear Replacement Jul-18 53.2

St George New Rockdale 132/11kV ZS Oct-18 25.3

Sydney Inner Metro

New 132kV Feeder 90Y Beaconsfield BSP-Belmore Park ZS and decommissioning 132kV Feeders 92L/3 & 92M/1 Sep-19 18.0

7.3.2.1 Gosford STS 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. The expected completion date for this project is December 2016.

7.3.2.2 132kV feeder 900 Replacement

Feeder 900(Mason park to Rozelle) is over 40 years old and is one of Ausgrid’s oldest remaining oil filled 132kV cables. The route length of the feeder is approximately 11km and includes two water crossings of Sydney Harbour. Due to fault duty issues with this cable, and the environmental risks should a cable leak occur in a section of cable under or adjacent to the harbour, it has been decided to accelerate the replacement of this feeder.

No non-network options (demand management) were considered to be viable alternatives to this project. A Final Report was issued in September 2010. This project is committed and scheduled for completion in December 2016.

7.3.2.3 Marrickville ring main circuit breaker (RMCB)

The purpose of installating 3-way Ring Main Circuit Breakers (referred in this document as 3-way RMCB) is to increase system reliability, as the existing configuration is an obsolete four tansformer design, where the local transformer circuit breakers were not installed, this would cause unnecassary outages of associated transmission feeders if there is a transformer fault.

The project is divided in two stages. Stage 1 comprises commissioning of cables 906, 9F6, 91U & 91H/2 and 3-way RMCBs; and Stage 2 includes the connection of Marrickville busbar to 3-way RMCBs and comissioning of 91X and 91Y bypass circuits (for future 91X and 91Y retirement in 2023).

In July 2015, a Report – Completion of Marrickville 132kV Switchgear project is issued, and it purposes an alternative arrangement due to financial, transformers aging & condition issues, and the latest load forecast reasons. The purposed alternative arrangement in the report will ultimately have two new 50MVA 132/11kV transformers, which will be connected to the 3-way RMCBs, rather than retaining the existing transformers by connecting the 3-way RMCBs to the existing Marrickville 132kV busbar.

No non-network options were considered to be viable alternatives to this project. The expected date of completion is January 2017.

7.3.2.4 New Munmorah 132/33kV STS

Currently, the supply to two existing 33/11kV zone substations: Noraville and Vales Point is provided from 330/33kV auxiliary transformers at Munmorah power Station, owned by Delta Electricity.

Ausgrid has received a Termination Notice from Delta Electricity dated 23rd March 2012 advising of their plan to decommission the Munmorah Power Station, including the 330/33kV auxiliary transformers, implying the 33kV supply will be disconintued from 23rd March 2017. Due to the absence of 33kV supply from March 2017 onwards, it will be necessary for Ausgrid to construct a 132/33kV STS in the area to supply Ausgrid’s 33kV system.

No non-network alternatives were considered to be viable alternatives to this project. This project is committed and scheduled for completion in January 2017.

7.3.2.5 Beaconsfield BSP 132kV busbar replacement - Ausgrid feeder reconnections

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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 2016. 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. This project is committed and scheduled for completion in April 2017.

7.3.2.6 Kurnell STS 33kV network rearrangement and 33kV Busbar Retirement

Kurnell STS was established in the 1960s at the Kurnell Peninsula. Due to their proximity to the Pacific Ocean, most of its network assets are affected by corrosion from exposure to the marine environment. A project to replace the 132kV busbar at Kurnell STS was completed in 2010.

To address remaining issues at Kurnell STS, a strategy was proposed consisting of replacing the existing Kurnell 33/11kV ZS with a new 132/11kV ZS on the Kurnell STS site, and retiring the 33kV infrastructure at Kurnell STS.

The retirement of Kurnell STS 33kV busbar is treated as a separate project because it provides supply to Caringbah ZS, Gwawley Bay ZS and the Sydney Water Desalination Plant. A rearrangement of the 33kV feeders supplying these substations is required prior to retire Kurnell STS 33kV busbar.

Since the project to establish Kurnell South 132/11kV ZS is completed, there are no alternative options to the retirement of the 33kV busbar. This project is committed and scheduled for completion in June 2017.

7.3.2.7 Installation of New Wholesale Metering Points

Under the NER, network assets can be classified as Transmission, Distribution or Dual-Function. Ausgrid may operate both Distribution and Dual function assets. In preparation for the regulatory submission, Ausgrid has undertaken a review the classification of assets consistent with requirements in Chapter 6 – Economic Regulation of Distribution Services and definitions under Chapter 10 of the NER.

The review has resulted in changes to classification for a number of assets, both from Distribution to Dual-Function and from Dual-Function to Distribution. Ausgrid will install and register compliant Wholesale Metering Points at the boundary points of its Dual-Function assets, in accordance with the requirements of the NER.

This project is now committed and expected to be completed by June 2017.

7.3.2.8 Ausgrid 132kV Sydney North BSP feeder protection & communication upgrade

To allow TransGrid to replace the aged secondary systems at Sydney North Bulk Supply Point (BSP), Ausgrid is upgrading the protection and communication equipments on the 132kV feeders originating from Sydney North BSP. A letter of intent has been received from TransGrid, requesting to initiate a project to carry out the modification works on all affected Ausgrid feeders connected to Sydney North BSP 132kV busbar.

Options considered to resolve the identified issues were differentiated by the use of several routes to install the equired communication links. The option selected consider the most cost effective combination of fibre cable and optical ground wire to be installed from Berowra ZS.

This project is now committed and scheduled for completion in June 2017.

7.3.2.9 Peakhurst STS to Bunnerong STS and Beaconsfield BSP 132kV feeders 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.

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. This project is committed and scheduled for completion in June 2017.

7.3.2.10 New Alexandria 132/33kV STS

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Mascot ZS 33kV feeders and 11kV switchgear, Sydney Airport 33kV switchgear and 33kV cables are approaching the end of their service life and are due for replacement by January 2019 - 21.

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 that are supplied at 33kV.

A consultation paper was issued in August 2013. A demand management screening test was carried out in August 2013, based on this analysis, it is not considered reasonable to expect that Demand Management is a cost effectve way to postpone the supply side solution. A Final Report was issued in July 2015, details the outcomes of the economic assessment and the preferred solution. The expected completion for this project is November 2017.

7.3.2.11 Mason Park STS to Top Ryde ZS and Meadowbank ZS Feeders 92F A/B & Feeder 90X A/B Replacement

The 132kV feeder 92F from Mason Park STSS to Top Ryde ZS comprises a section of two parallel oil-filled underground cables, 92FA and 92FB, approximately 4.9km long which were commissioned in the 1970’s. The 132kV feeder 90X from Mason Park STSS to Meadowbank ZS comprises a section of two parallel oil-filled underground cables, 90XA and 90XB, approximately 2.7km long which were commissioned in the 1980’s.

These oil filled cables have been identified as approaching the end of their service life. Several replacement options were considered, such as the like for like replacement, the reconfiguration of the feeders to remove the crossing across the Parramatta River, and the replacement of the feeders via Rhodes Peninsula. The option selected will route the replacement XLPE cables via the Rhodes Peninsula, using the existing pedestrian/cycleway (John witton) bridge over the Parramatta River and a proposed footbridge across Homebush Bay to avoid the need of submarine crossings. This solution would also facilitate an option to connect a future Rhodes ZS.

This project is committed and scheduled for completion in March 2018.

7.3.2.12 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 and scheduled for completion in July 2018.

7.3.2.13 New Rockdale 132/11kV Zone 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. The expected date of completion is October 2018.

7.3.2.14 New 132kV Feeder 90Y Beaconsfield BSP-Belmore Park ZS and decommissioning 132kV Feeders 92L/3 & 92M/1

As mentioned in section 7.1.1, the primary driver for the installation of this new 132kV feeder is asset condition requiring asset replacement. In the past there was a capacity need as presented in the Consultation Paper published on December 2013. Recent reductions in load in the Inner Metropolitan load area has altered the primary driver of this project to be the condition of 132kV circuits 92L/3 and 92M/1 from Lane Cove STSS to Dalley St ZS.

The solution recommended in the Final Project Report is to proceed with the installation of a new 132 feeder from Beaconsfield BSP to Belmore Park ZS (Feeder 90Y), utilising a spare duct and Ausgrid and TransGrid tunnels, the partial remediation of circuits 9SA and 92P .

The construction of the new feeder 90Y and the retirement of 132kV circuits 92L/3 and 92M/1 from Lane Cove STSS to Dalley St ZS are now committed. These works are expected to be finalised in September 2019.

7.3.3 Committed dual function augmentations There are no identified network constraints requring dual function asset augmentations at this stage. As no projects have appeared in previous TAPR publications as proposed network augmentations, there cannot be committed projects.

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 Electricity Statement of Opportunities (SOO), as follows:

Board commitment has been achieved (this requires the appropriate planning approvals and licences to be in place)

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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

7.4 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.

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.

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8 Joint planning

8.1 Joint planning with TransGrid TNSP Joint Planning is carried out with other Network Service providers, in particular TransGrid, Endeavour Energy, Essential Energy and Sydney Trains.

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 joint planning 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, design 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 approved Joint Planning Reports for major milestones.

Joint Planning Report sign-offs range from Planning Manager level (Ausgrid L5) for more routine agreements up to Executive level. The more routine operational decisions and actions required are agreed on and recorded via the joint planning meeting minutes.

8.1.1 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 defined in the Transmission Network Design and Reliability Standard for NSW (December 2010) and 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

An outage of any section of 132kV busbar.

The NSW Government asked the Independent Pricing and Regulatory Tribunal (IPART) to review and recommend revised NSW transmission reliability standards, which would apply from 1 July 2018. On 31 May

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2016, IPART published its draft report with recommendations for most BSPs and on 29 September 2016, IPART published its draft supplementary report with recommendations for the remaining BSPs. The recommended standards include a level of redundancy and an annual unserved energy allowance at each BSP in NSW. They do not prescribe how to invest but instead, explicitly provide for the relevant network service provider to determine the combination of network and non-network solutions required to provide reliability. A supplementary final report and recommendations is expected to be provided to the Minister for Industry, Resources and Energy by the end of 2016 to allow for a decision in early 2017.

In anticipation of the new transmission reliability standard, Ausgrid and TransGrid have begun moving from a deterministic assessment of the network to a hybrid or probabilistic approach.

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:

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.

8.1.2 Joint TransGrid - Ausgrid planning completed in 2016 8.1.2.1 Sydney Inner Metropolitan transmission load area

Existing and future constraints on the Sydney Inner Metropolitan transmission network are centred on two critical areas:

Transmission supply into Beaconsfield BSP from Bulk Supply Points at the edge of the city, Sydney South, Sydney North, and Rookwood Rd BSP. This is known as Transmission Corridor 1 (‘TC1’).

Transmission supply into Haymarket BSP and surrounding Ausgrid 132kV zone substations from Sydney South BSP (Cable 42) and Ausgrid 132kV connections from Beaconsfield BSP and the meshed 132kV network. This is known as Transmission Corridor 2 (‘TC2’).

Both transmission corridors operate as meshed systems of 330kV and 132kV circuits, with significant interdependencies between both corridors. Both have limitations due to the age and condition of existing circuits, including significant reduction in capacity of cables where in-situ conditions are not adequate to support design ratings. The Inner Metropolitan Area Joint Planning strategy must resolve issues on both corridors.

Ausgrid’s Inner Metropolitan transmission (dual function) network incorporates a large number of aging, oil filled 132kV cables and a plan is in place to progressively remove these cables from service. The work has been prioritised based on the condition of the cables and the potential impacts of failures. A program for cable de-commissioning of key feeders has been prepared.

In 2011, the capacity of TransGrid’s 330kV Cable 41 was reduced from 663MVA to 575 MVA due to the degraded condition of the cable installation backfill. In particular, this rating was dependent on elevated moisture levels in the soil, which cannot be guaranteed long-term. Further investigations by TransGrid have identified that there is potential to remediate the backfill along the cable route, thus extending the cable life and maintaining the rating at 575 MVA over the longer term. Due to the high cost of remediation over the full length of the cable route, TransGrid is undertaking a more detailed investigation to determine the scope of works that would be required to achieve an acceptable cable rating.

In 2016, TransGrid’s 330kV Cable 41 was further de-rated to 426MVA from 575MVA as a result of testing the thermal resistivity of cable backfill and bedding materials. In addition, the 2015/16 maximum demand development forecast has been produced and reviewed against network needs over a 25 year planning horizon. This forecast is substantially higher than the previous forecast due to an unexpected increase in summer peak demand in summer 2015/16 and a material increase in customer connection requests, both in terms of size and quantity.

As a result, Ausgrid and TransGrid have launched the Regulatory Investment Test for Transmission (RIT-T) with the publication of the Project Specification Consultation Report (PSCR). As part of the RIT-T process, a range of network and non-network solutions are being investigated. All network options involve construction of new 330kV cables between Rookwood Road and Beaconsfield BSPs.

The Ausgrid – TransGrid Joint Planning strategy in the period before the RIT-T solution is implemented is to address constraints on the Sydney Inner Metropolitan transmission corridors 1 and 2 by implementing the following:

Decommission feeder 91M/1 by the end of 2016

Installation of a new 132kV feeder 90Y between Beaconsfield and Belmore Park by 2017

Decommission feeders 92L and 92M (to reduce the environmental risk of oil leakage to Sydney Harbour) in 2018

Partial remediation of Feeders 9SA and 9SB by 2019

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TransGrid and Ausgrid will determine short-term circuit ratings for relevant circuits, to provide additional flexibility for operational management of network security requirements, minimising the need for pre-contingent load shedding or radialising of load.

TransGrid and Ausgrid will investigate the use of SCADA based automatic load shedding schemes to maintain network security requirements, minimising the need for pre-contingent load shedding or radialising of load.

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 the end of 2016.

A new Bulk Supply Point at Rookwood Road was commissioned in September 2014. Three 132kV feeders 240, 241 and 296 were planned for the connections. The final two feeders were connected into the new Rookwood Road BSP in early 2016.

In preparation for the 2014-2019 Regulatory Submission, Ausgrid has reviewed the classification of Dual Function assets in line with the definitions in the National Electricity Rules. This has resulted in changes to the classification of a number of Ausgrid assets, both from Distribution to Dual Function and from Dual Function to Distribution. Changes in classification may result in the need for upgraded wholesale metering at the new boundary points between the Dual Function and Distribution assets. A project for the installation of new wholesale metering points was created for both Sydney and Hunter sites where the wholesale metering boundary points have changed. This project is anticipated to be completed by the end of 2016.

TransGrid owned Sydney North 330/132kV Bulk Supply Point substation was commissioned in 1963. The substation is a major interconnection point in the TransGrid 330kV network and provides supplies to a number of Ausgrid substations including Mason Park and Lane Cove STSS. A condition assessment of the existing Sydney North Substation identified that the Secondary Systems require replacement. On TransGrid’s request, Ausgrid has initiated a project to carry out the required protection and communication modification works on all affected Ausgrid feeders. Communication modifications are expected to be completed by the end of 2016. Protection upgrades will coincide with TransGrid’s program of works at Sydney North BSP which are scheduled for completion by the end of March 2018.

Ausgrid owns a parcel of land in Riley St Surry Hills. The size of the property is suitable for building a replacement substation for Haymarket. In addition, the property has immediate access to Ausgrid CBD 132kV cable tunnel ring. Joint Planning discussions were conducted regarding the provision of future Bulk Supply Capacity with Sydney CBD area. It was agreed and documented as Joint Planning Report that TransGrid proceeding strategic Land acquisition at Riley St site as a future replacement site for Haymarket 330/132kV BSP. This has now been completed.

TransGrid’s Beaconsfield 330/132kV substation has three transformers. Transformer number 3 was installed in 2012. Transformers 1 and 2 were installed in 1979 and are now approaching the end of their useful life. Joint planning in 2015 determined that one of the two older Beaconsfield transformers should be replaced and the second should be retired without replacement. Since this joint planning there has been an increase in the demand forecast and a reduction in capacity of the 330kV cable supplying Beaconsfield. Also in 2016 IPART have commenced a review in to the NSW Transmission Reliability Standard. The outcome of this review is expected to be known in 2017 in preparation for the commencement of the new standard on 1 July 2018. TransGrid and Ausgrid will review the need for a third transformer at Beaconsfield once the new transmission reliability standard is known.

8.1.2.2 Transmission load area – Central Coast

Following the retirement of the Munmorah power station, its generator connections to TransGrid Munmorah substation were removed in 2014. Joint planning was conducted and the outcome is for Ausgrid to build a new Munmorah 132/33kV STS in the area to supply Ausgrid local load. The new Munmorah STS is under construction and will be commissioned in 2017.

8.1.2.3 Transmission load area – Lower Hunter

No significant issues were identified in the Lower Hunter network. Ausgrid has received an enquiry from the new owner of Redbank generator to reconnect to the 132kV network (it was disconnected in 2014). However, the enquiry has not proceeded into a formal connection application but customer negotiations remain ongoing.

8.1.3 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:

Sydney South BSP feeders 282 and 283 protection replacement. TransGrid intend to replace the protection of 132kV feeders 282 and 283 at Sydney South BSP. Ausgrid has no plans to replace protection of these feeders at the other end so will facilitate TransGrid works to minimise and/or avoid

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future re-work at Sydney South BSP when Ausgrid replaces protection at the other end. This is due for completion in March 2017.

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.

Planning discussions including identified needs reviews and on-going feasibility studies to review and refine a range of supply options for the Inner Sydney Metropolitan transmission load area. This will include approaches to meet any supply shortfall with 330kV supply cables.

8.1.4 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. It is published on their website as well as AEMO’s website.

8.2 Joint planning with other DNSPs Ausgrid follows the same principles when joint planning with Endeavour Energy, Essential Energy and Sydney Trains. However due to the limited number of network dependencies between the organisations, joint planning meetings may only take place once per year, or less, unless a particular issue has been identified and needs to be progressed and monitored.

8.2.1 Process and 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. A formalised joint planning arrangement was established with Sydney Trains.

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.

8.2.2 Joint Ausgrid and other DNSP planning completed in preceding year A joint planning meeting was held with Essential Energy this year to review all the connection points on the 33kV and 11kV networks. Essential Energy did report demand growth at Clarencetown which may result in a requirement to increase the capacity of one 11kV connection. There were no other network issues identified affecting other connections.

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.

Two joint planning meetings were undertaken with Endeavour Energy in the preceding year, in relation to the planned supply of Lidcombe and Auburn zone substations from Endeavour Energy’s Camellia substation. There are no other identified network issues that affect either Endeavour Energy or Ausgrid.

A joint planning meeting was held with Sydney Trains, with a view to estabishing a joint planning charter and regular future meetings.

8.2.3 Planned DNSP joint network investments There were no jointly planned network investments with Essential Energy or Sydney Trains in the preceding year.

Joint planning with Endeavour Energy has resulted in Ausgrid’s Auburn and Lidcombe zone substations to be supplied from Endeavour Energy owned Camellia TS. This will address the condition issues of the existing 33kV feeders from Homebush STS to Auburn ZS and Lidcombe ZS. The identified need date is March 2016.

8.2.4 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 the 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.

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9 Network performance

9.1 Reliability measures and standards Ausgrid’s objective is to maintain reliability performance at current levels and comply with regulatory requirements at minimum cost, given the condition and utilisation of existing network assets and the funding available to maintain and augment the electricity network.

Under the NSW Reliability And Performance (R&P) Licence Conditions for Electricity Distributors4 Ausgrid is

required to comply with specific targets for reliability standards and individual feeder standards. The purpose of the licence conditions is to facilitate the delivery of a safe and reliable supply of electricity. Ausgrid is required to report to the Minister to ensure compliance with the R&P licence conditions.

Under the National Electricity Rules (NER), and the Service Target Performance Incentive Scheme (STPIS), Ausgrid is given financial incentives to improve the customer’s reliability performance compared to historic outcomes over time (as well as penalties if the performance level deteriorates).

Reliability measures used are SAIDI (System Average Interruption Duration Index or minutes off supply for the average customer) and SAIFI (System Average Interruption Frequency Index or number of interruptions experienced by the average customer). The reliability performance is monitored at distribution feeder level for unplanned interruptions (excluding major event days, planned interruptions and circumstances beyond the reasonable control of the electricity distributor).

The distribution feeders are categorised as CBD (Sydney), Urban, Short Rural and Long Rural based on feeder length and load density. Ausgrid distribution network consists of 56 CBD feeders, 1742 Urban feeders, 379 Short Rural feeders and 4 Long Rural feeders where over 80% customers are on Urban feeders.

Reliability reporting uses the methodology described in IEEE 1366 standard for defining Major Event Days as outlined in the R&P licence conditions and AER STPIS Definitions.

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.

9.1.1 Supply reliability standards 9.1.1.1 Average feeder category reliability standards

The purpose of the R&P licence condition Schedule 2 – “Network Overall 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

CBD Urban Short Rural Long Rural

SAIDI 45 80 300 700

SAIFI 0.30 1.20 3.20 6.00

9.1.1.2 Individual feeder standards

The purpose of the R&P 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.

4 Effective from 1

st July 2014, the Reliability and Performance Licence conditions for Electricity Distributors replaced the Design, Reliability

and Performance Licence conditions imposed on Distribution Network Service providers (2007). See:https://www.ipart.nsw.gov.au/Home/Industries/Energy/Energy-Networks-Safety-Reliability-and-Compliance/Electricity-networks/Licence-Conditions-and-Regulatory-Instruments

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Individual feeder standards

CBD Urban Short Rural Long Rural

SAIDI 100 350 1000 1400

SAIFI 1.4 4 8 10

9.1.2 Supply reliability in the preceding year 9.1.2.1 Performance of individual feeders against the Standard

The 2015/16 global unplanned SAIDI was 3rd best in the last 14 years.

Unplanned SAIFI was the 2nd best for that period.

The following graph depicts the SAIDI trend over the 14 year period 2002/3 to 2015/16:

Figure 9.1: Global unplanned SAIDI

There were eight Major Event Days for 2015/16:

Date Excluded SAIDI Cause of Major Event Day

14th August 2015 7.77 Equipment failure

10th September 2015 5.72 Third party excavation

9th December 2015 3.81 Electrical Storm

14th January 2016 19.55 Electrical Storm

29th January 2016 4.60 Electrical Storm

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Date Excluded SAIDI Cause of Major Event Day

30th January 2016 6.58 Electrical Storm

4th June 2016 3.00 Wind and Rain Storm

5th June 2016 16.77 Wind and Rain Storm

As required under the R&P 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. In the majority of affected feeders the exceedances were deemed to be random events and action was limited to monitoring ongoing reliability performance. A small number of feeders required remedial actions such as vegetation management and repairs to network assets.

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 that targets those feeders that have exceeded the Individual Feeder Standards as outlined in Schedule 3 of the R&P Licence Conditions. The individual feeder performance against the standard is given in the table below.

Individual feeder performance against the standard during 2015/16

CBD Urban Short Rural Long Rural

Feeders (Total Number) 56 1,742 379 4

Feeders that Exceeded the Standard

during the Year 0 69 10 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

Feeder Not having Identified

Operational Actions Completed by

Due Date

0 0 0 0

Feeders Not having a Project Plan

Completed by Due Date

0 0 0 0

9.1.2.2 Performance of feeder categories against the standard

All feeder category performances were compliant against the Reliability Standards for 2015/16.

Performance of feeder categories against the standard during 2015/16

System CBD Urban Short Rural Long Rural

SAIDI 76.01 9.42 65.36 131.72 590.40

SAIFI 0.70 0.02 0.62 1.15 3.19

9.1.3 Service Target Performance Incentive Scheme (STPIS) The Australian Energy Regulator's (AER) distribution Service Target Performance Incentive Scheme (STPIS) was applied to Ausgrid for the first time in the 2015-16 financial year. The Scheme provides a financial incentive for Ausgrid to maintain or improve its reliability and customer service performance over time.

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As part of the AER final determination for Ausgrid, the AER set elements of the STPIS for the 2015/16 – 2018/19 period including at-risk revenue caps, reliability targets, and customer service targets. The revenue at

risk for each regulatory year will be capped at 2.5 per cent with a 2.25 per cent cap for the reliability of

supply component and 0.25 per cent cap for the customer service component.

The SAIDI and SAIFI targets set by the AER in their final determination for each feeder category for the

reliability component of the STPIS are set out in the table below5.

Year 2015/16 2016/17 2017/18 2018/19

Unplanned SAIDI

CBD 16.58 16.58 16.58 16.58

Urban 62.41 62.41 62.41 62.41

Short Rural 157.28 157.28 157.28 157.28

Long Rural 436.53 436.53 436.53 436.53

Unplanned SAIFI

CBD 0.054 0.054 0.054 0.054

Urban 0.674 0.674 0.674 0.674

Short Rural 1.426 1.426 1.426 1.426

Long Rural 3.088 3.088 3.088 3.088

9.1.4 Forecast of network reliability performance Ausgrid’s Reliability Forecasting System (RFS) forecasts the reliability performance of each feeder category based on 5 years of historical performance and looking forward considers the impact of the following:

The aggregate performance change due to past and proposed investments

The aggregate performance reduction due to the general ageing of network assets and changes in demand.

There is a level of randomness that impacts on reliability outcomes from year to year. For this reason the

reliability forecast is provided at three confidence levels6 being a 10%, 50% and 90% probability of

exceedance. In the tables below the 50% probability of exceedance forecast (POE) is given for SAIDI and

SAIFI.

SAIDI (50% POE)

2016/17 2017/18 2018/19

System 76 77 76

CBD 14 14 14

Urban 63 64 63

Short Rural 163 165 162

Long Rural 490 492 489

(average minutes of supply interruption per customer)

SAIFI (50% POE)

2016/17 2017/18 2018/19

System 0.71 0.73 0.71

CBD 0.08 0.08 0.08

5 Table extracted from the AER’s Final Decision Ausgrid Determination 2015-16 to 2018-19 Attachment 11 – Service Target Performance

Incentive Scheme.

6 The confidence intervals reflect the range of historical variations of the random component of reliability performance of the network and are

an outcome of the Monte Carlo modelling process used in the Reliability Forecasting System

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SAIFI (50% POE)

2016/17 2017/18 2018/19

Urban 0.61 0.62 0.60

Short Rural 1.45 1.48 1.44

Long Rural 3.56 3.59 3.59

(average number of network interruptions per customer)

Where a shortfall in reliability is identified 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.

Project proposals within these three categories are short-listed and the anticipated cost benefit of each option is estimated. The cost estimates are based on standard unit costs and adjusted to reflect, to the extent practicable, the realities of implementing the solution.

9.1.5 Compliance with network reliability standards Ausgrid monitors feeder outages and records the duration of outage events into the Outage Management System (OMS). For reliability reporting purposes, the 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 feeder category (CBD, Urban, Short Rural and Long Rural).

Every quarter Ausgrid submits a report stating the business [erformance aginst the Reliability, Individual Feeder and Customer Service Standards to Ipart and the Minister administering the Electricity Supply Act 1995 within one month of the end of each quarter.

The report lists performance against the pro-rata SAIDI and SAIFI average standards, along with any reasons for non-compliance and Ausgrid’s plans to improve the feeder 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 and/or capital expenditure, or alternatively there is the option of a non-network solution.

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.

Non-network solutions may include energy storage systems to provide ride-through capability during outages.

9.2 Quality of supply standards 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. The NSW Code of Practice - Electricity Service Standards

7 provides a framework for

supplying electricity to customers on the Distribution Network. Ausgrid’s network standard NS 238 Supply

7http://www.resourcesandenergy.nsw.gov.au/energy-supply-industry/pipelines-electricity-gas-networks/network-

connections/electricity_connect_code_of_practice_electricity_service_standards.pdf

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Quality8 sets out Ausgrid’s standards for Quality of Supply which customers can expect from Ausgrid’s

network.

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.

9.2.1 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.

9.2.1.1 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 as defined in the relevant Australian Standard AS 61000.3.100, with a tolerance of +10%/- 6% to allow for voltage regulation on the mains between distribution substations and customers’ points of supply. The 99

th percentile (V99%) of the 10

minute average voltage readings for a 1 week survey should be less than 253V and the 1st percentile (V1%)

should be greater than 216V.

9.2.1.2 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.

9.2.1.3 Applicable quality of supply codes, standards and guidelines

Ausgrid relies on the following standards and/or guidelines when setting and assessing network voltage performance:

Network Standard: NS 238 Supply Quality

Australian Standards: AS/NZS 60038 and AS 61000.3.100

NER S5.1a.4 – Power Frequency Voltage

NSW Service and Installation Rules (SIR): Section 1.10.1 refers to AS/NZS 600038 & AS 61000.3.100.

9.2.2 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.

9.2.2.1 Applicable quality of supply codes, standards and guidelines

Ausgrid relies on the following standards and/or guidelines when limiting and assessing harmonic performance:

Network Standard: NS 238 Supply Quality

Australian Standards: TR IEC 61000.3.6:2012, AS 61000.2.2:2003, AS 61000.2.12:2003, 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 1.16.2.1 (b) refers to AS/NZS 61000.3.2, 61000.3.4, 61000.3.12.

8http://www.ausgrid.com.au/Common/Our-network/Standards-and-

Guidelines/~/media/Files/Network/Documents/NS%20and%20NUS/NS238.pdf

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9.2.3 Voltage fluctuations (Flicker) – Applicable quality of supply codes, standards and guidelines Ausgrid relies on the following standards and/or guidelines when limiting and assessing Voltage fluctuations performance:

Network Standard: NS 238 Supply Quality

Australian Standards: TR IEC 61000.3.7:2012, AS 61000.2.2:2003, AS 61000.2.12:2003, SA/SNZ TR IEC 61000.3.14:2013

NER S5.1a.5 – Voltage Fluctuations

NSW Service and Installation Rules (SIR): Section 1.16.2.1 (b) refers to AS/NZS 61000.3.3, 61000.3.5, 61000.3.11.

9.2.4 Voltage unbalance – Applicable quality of supply codes, standards and guidelines Ausgrid relies on the following standards and/or guidelines when limiting and assessing Voltage Unbalance performance:

Network Standard: NS 238 Supply Quality

Australian Standards: 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.

9.3 Quality of supply performance for preceding year At Ausgrid, monitoring for supply quality is undertaken by a number of means including fixed meters at Distribution Substations, random Power Quality (PQ) surveys at customer premises and participation in the Long Term National Power Quality Survey conducted by the University of Wollongong.

In 2015-16, under Ausgrid’s Low Voltage Network Power Quality Survey (LVPQS), approximately 200 randomly selected Low Voltage customer sites were monitored for one week with temporarily installed power quality meters. These meters meet the highest accuracy requirements (Class A) as specified in AS/NZS 61000.4.30.

The sites were evaluated for compliance 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.

The following graph shows the distribution of PQ parameters from all surveyed sites. The data has been scaled to 100% of the limit that each PQ parameter is assessed against. The green line shows the site performance (the 95

th percentile of the distribution of the PQ parameter for all sites surveyed). Performance

details of each parameter are discussed in the separate sections below.

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Figure 9.2: Ausgrid low voltage survey of PQ parameters

9.3.1 Supply voltage performance In the survey all sites met the V1% limit and 91% of sites met the V99% limit. The high V99% figure is a consequence of the network being historically designed for a nominal 240V range. As stated in the next section (Corrective Action) Ausgrid is currently undertaking a 230V migration program to manage this.

In addition, a set of data recorded in the first week in May 2016 for a sample set of over 1000 Distribution Substations was analysed for Voltage performance and compared to similar surveys carried out in previous years. The results indicate a steady decline for the median and 99th percentile values between 2012 and 2016. On average, the voltage median (50th percentile) dropped by 0.8 volts per year and the 99th percentile by 1.1 volts per year.

9.3.2 Harmonic content of supply voltage waveform The Total Harmonic Distortion (THD) measured to AS/NZS 61000.2.2 as a sum of the powers of all harmonic voltages present compared to the fundamental (50 Hz) voltage. The results of the survey show that the THD for all measured sites was within the compatibility level of 8%.

All individual harmonics met compatibility levels, with the exception of the 15th (750 Hz) and 21st (1050 Hz) harmonics. Exceeding the compatibility levels for these harmonics is not seen as significant issue, as these harmonics do not generally create issues for equipment operation. The 15th and 21st harmonics are close to the Customer Load Control (“Ripple Signal”) transmission frequency used for off peak hot water control, resulting in high readings for these harmonics.

9.3.3 Voltage fluctuations (Flicker) performance 9.3.3.1 Short term Flicker (Pst)

The results of the survey show that 94% of sites met the Short Term (Pst) compatibility level for flicker of 1.0.

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9.3.3.2 Long term Flicker (Plt)

The results of the survey show that 90% of sites met the Long Term compatibility level (Plt) for flicker of 0.8. The number of sites with higher flicker levels has reduced from previous surveys. Inspection of the results showed that a larger number of the randomly selected sites were in proximity to either Electric Arc Furnaces (EAF) or construction sites, which are known to inject high levels of Flicker onto the network.

There were a number of complaints in the reporting period related to the flicker or voltage fluctuations, of these, 3 were confirmed to be valid. All complaints are analysed and improvement actions undertaken where the supply is found to be non-compliant with the relevant Australian/New Zealand Standard.

9.3.4 Voltage unbalance performance The results of the survey show that voltage unbalance for all measured sites with three phase connections was within the compatibility level of 3% as specified in AS/NZS 61000.2.2.

9.4 Corrective action planned to meet quality of supply standards

9.4.1 Supply voltage Measurements on the LV network indicate that a number of sites exceed the V99% value when measured to AS 61000.3.100. Under the 230 Volt migration program 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). As tap setting changes are carried out in conjunction with other maintenance works to constrain costs, this project is expected to take in excess of 10 years to complete. Tap setting changes will be carried out earlier in the case of customer complaints that are identified to be due to higher voltages at the Distribution transformers.

9.4.2 Harmonics Measurements on the LV network indicate that a number of sites exceed the limit for the 15th and 21st harmonics. Exceeding these limits is not seen as significant issue, as these harmonics do not generally create issues for equipment operation.

9.4.3 Flicker Measurements on the LV network indicate that a number of sites exceed the limit for Plt. The sites so identified are referred to the regional field offices for identification of the source of the flicker. Where the source of flicker is identified, reasonable measures may be taken under the NER and/or the connection agreement(s) to limit the level of the flicker emitted onto the network.

9.5 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

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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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10 Asset management

10.1 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.

Ausgrid’s asset management strategy is to deliver the appropriate reliablity, performance and safety from our assets utilising a risk and evidence based approach. This approach balances our customer’s expectations, with prudent and efficient investment, in order to achieve Ausgrid’s organisational objectives.

The strategy leverages the capabilities, policies and standards that have been developed over the last fifteen years, in combination with the current state of the network, the improved network information available and the changes in context of the external environment. It is underpinned by a framework that ensures alignment from the leadership, management and culture of the organisation through to the achievement of the asset management outcomes. This is achieved through fit for purpose systems and processes, and a clear framework of governance and assurance.

Sound asset management processes 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 further enabled Ausgrid to transparently demonstrate to industry regulators the prudence and efficiency of our expenditure as it relates to specific assets.

The asset management strategies, models and processes adopted by Ausgrid are consistent with the elements of a total asset management system as identified in the NSW Government's Total Asset Management (TAM) Manual, and largely aligned with the requirements of AS ISO 55001:2014 Asset Management – Management Systems – Requirements.

10.2 Risk management strategies Risk management identification and strategies to manage the identified business risks are maintained in accordance with a Risk Management Board Policy and Ausgrid’s Risk Management framework.

Risk management strategies associated with the various asset categories are underpinned by Ausgrid's asset management strategy and system. Assets carry risk through all stages of their lifecycle. Ausgrid’s asset management approach utilises risk management techniques to assess and mitigate these risks to an appropriate level considering the principles of as low as reasonably practical (ALARP).

Ausgrid undertakes Failure Mode Effects and Criticality Analysis (FMECA) which is a structured method for assessing the likelihood, causes and consequences of asset failures. This in turn is utilised to determine asset risk , which informs asset stratgies and plans.

In determining preventative maintenance requirements, Ausgrid undertakes Maintenance Requirements Analysis (MRA) utilising FMECA / Reliability Centred Maintenance (RCM) to determine effective maintenance tasks and optimal intervals. The outputs from the MRA process form Ausgrid’s Technical Maintenance Plans (TMP).

Condition Based Maintenance (CBM) is undertaken to understand asset residual risk. Where conditional issues present an unacceptable risk, corrective action such as repair or renewal may be carried out. Where the residual risk cannot be effectively and efficiently mitigated, the asset is considered for re-design. Rectification of defects are prioritised and assisgned a rectification timeframe depending on the risk likelihood of failure and the potential consequence.

10.3 Sub-transmission underground cables replacement strategy Ausgrid’s sub-transmission cables are in continuous use and are an essential part of our supply network. 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 program for the retirement of sub-transmission cables due to asset risk 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 experiencing failures, have long repair times and have minimal

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technology support and are therefore considered to be superseded and resource intensive technologies for cables at these voltage levels. A condition based risk assessment of our sub-transmission underground cables was carried out 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 unavailability and defect related performance of individual feeders

The service risk associated with individual feeders, and

The environmental risk from individual cables, in particular those crossing major waterways.

Ausgrid has developed an asset risk probability model for SCFF cables which is used as an input into the organisation’s probabilistic planning approach. Cost benefit analysis (CBA) is undertaken to determine the optimal timeframe for cable retirement / replacement. All sub-transmission cables have been given a risk based retirement date to align with consideration of CBA. These risk based cable retirement dates are included as one of the inputs into the review of relevant Area Plans.

Due to the environmental risks posed by these cables, Ausgrid also consults with the Environmental Protection Agency (EPA) on the planned strategy to replace oil filled cables.

10.4 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). 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. From 2004, internal arc classified switchgear became the accepted industry standard for new installations. This progression of technology has resulted in a corresponding reduction in the risk of catastrophic failure (likelihood and consequence). This reduction in risk was traded off against a larger construction footprint in a typical urban style Zone Substation.

In rural and lower loaded areas, outdoor 11kV 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 in place a program for the retirement for poor condition and high risk 11kV switchgear. Due to the age and condition issues associated with 11kV compound switchboards, this technology is approaching end of life and has been targeted for retirement. The priority for compound switchboard retirement is designed around the following factors:

Individual 11kV 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; and

Ex-St. George County Council refurbished switchgear with non-capacitively graded spout bushings.

Switchgear risks are considered in conjunction with other planning needs and cost / benefit analysis to determine the optimal replacement timeframes.

Oil filled circuit breakers pose an additional risk to safety, reliability and secondary asset damage due to the catastrophic nature in which they fail. To mitigate this risk and defer retirement of older style air insulated switchboards, where practical, Ausgrid has a program to replace the remaining 11kV oil filled circuit breakers in zone substations with vacuum equivalents (VCBs) which do not present the same level of consequence risk.

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10.5 Distribution network losses Distribution network losses refer to the difference in energy obtained from the transmission network to that supplied to customers. Ausgrid’s distribution network losses as a percentage of total energy for the 2015/16 financial year was 4.05%.

Electrical energy losses represent a cost to those who produce, consume and transport electricity and therefore it is Ausgrid’s objective to minimise these losses, while maintaining a safe and reliable electricity supply, at minimum cost to the community. When considering potential network projects under the NER’s Regulatory Investment Test for Distribution, Ausgrid must consider changes in electrical energy losses if they are material or may alter the selection of a preferred investment option.

Ausgrid’s methodology for calculating losses is published on its website as part of the requirements of the NER to maintain a method for calculating Distribution Loss Factors (DLFs). This methodology is based on a report from consultants Evans & Peck entitled “Ausgrid – Evaluation of Losses in Project Evaluation” . 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 RIT-D.

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.

10.6 Obtaining further information on asset management Further information on asset management may be obtained in Ausgrid’s Electricity Network Performance Report available on the Ausgrid website.

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11 Demand management

11.1 Demand management Demand management solutions offer credible alternatives to investment in the network. Ausgrid is committed to supporting demand management activities. Effective use of demand management reduces the cost to maintain the network and helps lower electricity charges for the entire community. It can involve either the voluntary moderation of customer electricity demand at peak times or the supply of electricity from generators or storage batteries connected at customer’s premises or to the distribution network.

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;

Energy storage (e.g. batteries); and

Power factor correction.

When a review of a part of the network is initiated, an analysis of options that includes both reducing demand and building network assets is completed. The goal is to find the lowest cost solution that meets the required reliability standards.

When network reviews indicate that a network need for an asset replacement or network expansion investment is required, Ausgrid will investigate and where viable, develop and implement demand management options to maintain network reliability standards. The demand management investigation is comprised of five separate stages:

1. Identify network need for investment

2. Conduct demand management screening test for credible demand management solutions

3. Conduct demand management investigation including community consultation

4. Select preferred demand management option where viable and cost effective

5. Implement demand management solution

For all augmentation projects where the network expansion component of any credible network options have a capital cost in excess of $5 million, the Regulatory Investment Test for Distributors (RIT-D) process will be followed to assess demand management solutions.

For augmentation projects with a capital cost of between $1 million and $5 million, or for replacement projects with a capital cost of more than $2 million, Ausgrid also considers demand management options as an alternative to investing in the network. A simplified assessment process may be used for projects with lower capital costs.

11.2 Demand management considerations in 2015-16 There were 38 projects in the forward planning period 2015-16 to 2020-21 which met Ausgrid’s criteria for demand management consideration. Ausgrid assesses the viability of demand management alternatives for projects which are scheduled for the forward 5 year planning period and which meet minimum threshold costs. For augmentation projects, Ausgrid assesses non-network alternatives when the capital cost is greater than $1 million; and for replacement projects when the capital cost is greater than $2 million.

For 20 of these projects, assessment for non-network solutions, completed for the 2015 Annual Planning Report, had determined that it is was not considered reasonable for demand management to offer a cost effective option for these projects. No further assessment was undertaken. For a further 3 of these projects, assessment for non-network solutions was completed as part of the Area Plan Review process during 2015-16 or completed at an earlier date. The reviews determined that it is was not considered reasonable for demand management to offer a cost effective option for these projects.

For 14 projects, a preliminary demand management assessment was completed in 2015-16. Of these, there are 3 projects which are probable to offer a cost effective option for network deferral. For the remaining 11 projects, it is not considered probable that non-network alternatives offer a cost effective option for network deferral. These assessments were based upon preliminary assumptions for project costs, unserved energy and other benefits. More detailed planning and assessment of all projects in the forward planning period is scheduled to occur later in the 2016-17 year to more accurately assess the viabiity of demand management to defer or avoid the network investment. Where found to be potentially viable,

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demand management investigation and consultation will be conducted during the project initiation & development stage closer to the network need date.

There was 1 project where assessment for non-network solutions was completed as part of the joint planning process with Transgrid for the Inner Metro Transmission network. A consultation paper seeking expressions of interest from non-network

providers to address the transmission needs in the Inner Sydney area as been published at www.transgrid.com.au. Submissions to the expression of interest close 13 January 2017.

11.3 Demand management activities in 2015-16

11.3.1 Demand management projects implemented in 2015-16 There were no demand management projects initiated, or continued in 2015-16.

11.3.2 Demand management innovation As part of our efforts to explore alternative demand management solutions, Ausgrid investigates potential demand management solutions that may offer cost-effective alternatives to traditional network options. These research projects are funded through the Demand Management Innovation Allowance (DMIA) and approved by the Australian Energy Regulator.

A description of the projects is provided in the following table.

Table 11.1: Demand management innovation projects

Project Name

Project Description

1 CoolSaver air conditioner demand response project

Ausgrid continued a trial to test the viability of air conditioning load control with the CoolSaver program in 2015-16. This trial tests whether more efficient management of air conditioning power consumption during peak demand events can offer a cost effective alternative to network investments.

Following a successful technology pilot of a new Demand Response Enabling Device (DRED) technology in 2012-13, Ausgrid invited customers in selected suburbs in the Central Coast and Lake Macquarie areas to participate in the CoolSaver trial from late 2013. The trial was extended in 2015-16 to the Maitland area in order to investigate the viability of an alternative lower cost approach to acquiring customers to the program by partnering with local air conditioner retailers and installers.

To date, the trial has verified the reliability and functionality of the technology, confirmed demand reductions and received consistently positive feedback from participating customers. During the summer period in 2015-16, there were 6 successful dispatch events across each of the 3 trial areas where electricity demand from customer air conditioners was moderated to reduce demand in peak periods. The trial will conclude at the end of the 2016-17 summer season.

In June 2016, the project was modified to explore the customer response to the use of the demand response technology in winter. Use of reverse cycle air conditioners for winter heating is increasingly common with 80% of survey respondents from our 2015/16 CoolSaver survey indicating that they used reverse cycle air conditioners as their primary heating source. As about half of Ausgrid’s zone substations are winter peaking or potentially winter peaking in the near future, this trial leverages previous DMIA project activities and load control equipment already in place to explore a potentially cost effective demand management solution. Ausgrid invited its Central Coast CoolSaver participants to participate in a new trial starting in June 2016.

Interim reports for the CoolSaver program have been published on the Ausgrid website at http://www.ausgrid.com.au/dm.

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Project Name

Project Description

2 Newington Grid Battery

This trial investigated the potential impacts, benefits and performance of battery storage. It specifically set out to test whether a grid-side battery can be operated reliably and effectively for summer peak reduction, improve power and supply quality parameters of the network and moderate the impacts of intermittent solar generation. This was projected was completed in 2015/16.

Trial results have shown that grid based energy storage can be a viable solution to managing network demand once the product matures and energy storage prices lower . In addition to a lower cost per Megawatt-hour of storage capacity, improvements to system reliability will be required to compete with existing alternative demand management solutions.

Following completion of the Newington grid battery trial, Ausgrid has now assessed the reliability, performance and implementation issues for both grid and customer based battery storage. While the outcomes from both trials highlighted a performance gap in reliability compared with more mature demand management solutions, we expect that these issues will be resolved in the near future. And with battery costs forecast to decline significantly in the near term, cost competitiveness may not be far off.

The trial has also highlighted potential areas of future research, notably into customer attitudes to battery investment. For further detail the full report on the trial has been published on Ausgrid’s website at www.ausgrid/dm.

3 Hot Water Trials

Between 2001 and 2015, Ausgrid conducted three hot water load control trials to explore ways to reduce the impact of peak demand from residential hot water systems. This included trials for:

1) Control of small hot water systems which aimed to explore the technical and practical considerations for controlling small hot water systems (less than 100L) directly at the appliance.

2) Subsidised controlled load connections which aimed to investigate new ways of getting more customers to connect their eligible hot water systems to Ausgrid’s existing load tariffs.

3) Controlled Load 2 Summer Scheduling which explored load schedule optimisation to reduce peak demand during the summer peak period.

Trial results have shown that while technically viable, the costs to acquire new customers for a new or existing controlled load tariff in comparison with the relatively modest peak demand reductions make this approach a high cost solution. High costs for some customers to install the required metering or other non-standard electrical work also impacted program results.

For the Controlled Load 2 Summer Scheduling project, modifying the summer schedule resulted in a summer peak reduction of between 150 and 200 Watts per customer with operational ripple load equipment. The project results demonstrated that changing the load control schedule for Controlled Load 2 customers can cost effectively reduce network summer peak demand and would be considered a cost-effective option for a network deferral project.

For further detail the full report on the trials have been published on Ausgrid’s website at www.ausgrid/dm.

4 Large customer power factor correction

Encouraging customers to install power factor correction (PFC) equipment is an established method for reducing peak demand and deferring network investment. However barriers such as a lack of customer awareness about the impact and costs of poor power factor and low understanding of how to implement a solution can challenge the effectiveness of uptake of this type of demand management solution. The objective of this trial is to identify and assess various techniques to improving customer adoption of power factor correction at least cost.

In 2015/16, about 1,000 non-residential customers using more than 160 MWh per year and on a low voltage kVA capacity tariff (E305 or E310) were sent a letter inviting them to request a PFC report for their premises. In some cases, customers were sent a PFC report for their premises directly. The letter encouraged them to seek a power factor solution by providing them information about the process for seeking quotations and installing equipment. Power factor service providers on Ausgrid’s PFC register were provided general information about the total kVA potential of the customers targeted in the mail-out.

The decision to invest in more efficient equipment for their premises can be a slow process as facility managers or owners often need to source or seek approval for sufficient budget. Consequently, final outcomes from the letter campaigns will take some time. Ausgrid continues to collect information on customer take-up and expects to finalise the project in 2016/17.

On completion of the trial, a final report will be published on Ausgrid’s website at www.ausgrid/dm.

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Project Name

Project Description

5 CBD embedded generator connection

Ausgrid has well-established processes for connecting embedded generators to the network but needs to overcome the technical limitations to connection imposed by the triplex network that supplies customers in the Sydney CBD. The unique triplex network was conceived with the aim of providing a high degree of reliability to customers in the Sydney CBD, such as the Australian Stock Exchange and Parliament House. However, a characteristic of this exceptionally reliable network is intrinsically high fault levels, making it difficult to safely connect embedded generators.

The CBD embedded generation project was initiated to address this shortfall by developing and trialling a new protection scheme at the site, and in doing so provide key lessons to assist the development of a standard specification for connecting embedded generators in the Sydney CBD.

The initial stage of the project involved considering, comparing and assessing various different approaches. The most viable approach was chosen and then developed into a concept brief to outline how the scheme would operate and the underlying conditions required. The concept brief was further developed into an engineering brief that described precisely how the system would function and included design drawings.

The project is now in the implementation phase with completion scheduled for 2016/17. Once equipping and commissioning of the new system has been completed there will be a trial operation period to ensure that the system works safely and as expected and to document any lessons and feedback that may contribute to future standard development

An interim report for the CBD Generator trial has been published on the Ausgrid website at http://www.ausgrid.com.au/dm.

6 Pool pump demand

Pool pumps are a large residential appliance with an estimated 180,000 pool owners in Ausgrid’s network area. The summer peak demand from residential pool pumps is estimated to be between 50 to 150 MW across the Ausgrid network area. The intention of the project was to assess the potential peak demand contribution and reduction potential from residential pool pumps in Ausgrid’s network area by analysing customer interval meter data. If found to be significant a customer trial would follow targeted at offering an energy efficient pool pump rebate offer to a sample of customers.

A pool pump identification technique and algorithm was developed internally which involved analysing 30-minute customer metering data. This technique was applied for samples of residential customers with a pool on a network time-of-use tariff as well as customers with a pool on a network block (or flat) tariff. Previous analysis of data from customers with pools indicates that 40% of residential pool owners in Ausgrid’s network are on time-of-use network tariffs with the remainder on a block (or flat) network tariff.

The data analysed was during the working week of 22 to 26 February 2016 when the 2015/16 system network peak occurred on the 25th February 2016. The results from the analysis of customer metering data has indicated that the diversified load contribution of pool pumps to Ausgrid’s summer peak demand is around 300 to 400 Watts per pool customer during the peak period. This equates to a total summer peak demand contribution of 54 MW to 72 MW.

For an Ausgrid zone substation with a high penetration of pool owners of about 2,000, the total contribution of pool pump load to summer peak demand for this zone substation would be around 600 to 800 kW. Assuming an optimistic program take-up of around 20% for an energy efficiency pool pump installation rebate offer and an optimistic reduction in peak load of 80%, the total demand reduction potential would be around 100kW to 130kW. Considering the small demand reduction potential and limited applicability of this demand management solution for a network deferral project it was decided not to proceed to Phase 2 and to close out the project.

A final report will be published on Ausgrid’s website at www.ausgrid/dm.

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Project Name

Project Description

7 Solar Power and Battery Systems

During 2015-16 development commenced on a project aimed at understanding and attaining detailed knowledge about customers’ awareness, attitudes, purchase intentions and usage behaviour of solar power systems and storage batteries. This would be the first comprehensive research in this area within the organisation, the results of which will help to inform the potential uptake of solar power and battery systems for the development of future demand management programs.

The project consists of two main phases of research; the first phase is designed to gain a high-level understanding based on quantitative research of customers’ perceptions about demand response programs for batteries, uptake of solar and battery storage packages and knowledge about these products. The method of gaining information is invitation to 15,000 customers to complete an online survey. The second phase of the project is designed to obtain a deeper level of understanding based on qualitative research around customer knowledge of battery systems and testing specific financial and non-financial attributes of a battery system product offer that might lead to higher take up of battery systems.

This project is scheduled for completion in early 2017. When complete, the project results will be published on the Ausgrid website at http://www.ausgrid.com.au/dm.

8 DMIA Stakeholder Engagement

Started in 2015/16, this project will engage with our stakeholders to help guide Ausgrid’s demand management innovation research program. To ensure that stakeholder views are effectively canvassed, a range of consultation techniques may be utilised, such as web-based and in-person seminars, the publication of a consultation paper, promotion via social and traditional media, and workshops or other techniques or tools.

To stimulate open conversation, an online discussion forum has been selected for the initial stage of the engagement process. Other engagement tools may be used considering the preferences of our stakeholders and the findings from the initial online forum.

This project is scheduled for completion in early 2017. When complete, the project results will be published on the Ausgrid website at http://www.ausgrid.com.au/dm.

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11.4 Forecast demand management projects For the forward planning period 2015-16 to 2020-21, a preliminary demand management assessment has determined that non-network alternatives is likely to offer a cost effective option for 3 projects. These assessments were based upon preliminary assumptions for project costs, unserved energy and other benefits. More detailed planning and assessment of all projects in the forward planning period is scheduled to occur later in the 2016-17 year to more accurately assess the viabiity of demand management to defer or avoid the network investment.

For one project, assessment for non-network solutions was completed as part of the joint planning process with Transgrid for the Inner Metro Transmission network. A consultation paper seeking expressions of interest from non-network providers to address the transmission needs in the Inner Sydney area as been published at www.transgrid.com.au/news-views/lets-connect/consultations/current-consultations/Pages/Powering-Sydney.aspx. Submissions to the expression of interest close 13 January 2017.

Note that these projects are all replacement projects which present a different type of network need for demand management than the traditional augmentation investment. Non-network solutions which allow the deferral of replacement expenditure will need to have quite different characteristics to those used to defer network augmentation.

A viable non-network solution for a replacement project must supply network support sufficient to maintain reliability of supply in the event of the failure of a network element. And on the failure of a network element, the lost capacity is typically far greater than a simple overload due to extreme weather conditions. As a result some common types of demand management may not offer a viable or cost effective alternative for replacement expenditure.

For example, a network support contract for the deferral of network augmentation may require the non-network solution to be available for a summer or winter season and a dispatch capability of 40 to 50 hours during peak demand periods in summer or winter. By contrast, if an existing piece of network needs to be replaced, the non-network alternative may need to offer an entire year of stand-by network support, as the failure of a network element can occur at any time of the year. And in the event of the failure of a network element, the non-network provider may be required to commit to 300 or more hours of dispatch each year to support the network while repairs are completed.

Where more detailed investigations closer to the need date confirms the potential for a non-network option, Ausgrid will consult with stakeholders and the community through a non-network options report or equivalent.

Note that the preliminary values in Section 4 are the demand reductions required to defer the investment only on a cost benefit basis and do not remove all load at risk. Where Ausgrid issues a non-network options report (or similar), we would also invite interest from non-network providers for proposals to remove all potential load at risk.

11.5 Demand side engagement During 2015-16 Ausgrid undertook a range of activities to encourage engagement with demand management proponents and other interested parties to improve demand management outcomes in meeting network needs.

Ausgrid invites interested parties and non-network solution providers to register their details on our Demand Side Engagement Register found on our website to receive information updates on our demand management activities.

To better inform those who have registered, the Ausgrid Demand Management e-newsletter is the main method by which registrees are kept informed about demand management activities by Ausgrid and other relevant industry and regulatory activities occurring in the industry.The e-newsletter will continue on a quarterly basis in 2016-17. Copies of past e-newsletters can be found at http://www.ausgrid.com.au/dm.

Ausgrid also continued its partnership with other electricity networks in Australia and the Institute of Sustainable Futures at University of Technology Sydney to provide planning information via an online mapping tool to better inform the community about proposed network investments and assist in identifying opportunities for demand management to defer investment. A link to the Network Opportunity Maps (NOM) is available on our website at http://www.ausgrid.com.au/dm.

These maps are a valuable tool in communicating network needs and complement other efforts to identify non-network solutions such as the Regulatory Investment Test for Distributors (RIT-D), our Demand Side Engagement Document and the Demand Side Engagement Register. The information for Ausgrid detailed in the maps is as per our 2015 Distribution & Transmission Annual Planning Review (DTAPR). The maps will be updated annually to reflect the latest information.

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

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investigates and implements non-network solutions, please refer to our Demand Side Engagement Strategy at http://www.ausgrid.com.au/dm.

11.6 Embedded generator enquiries and connection applications During the financial year 2015/16, Ausgrid has had no enquiries from embedded generator applicants electing to use 5.3A.

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12 Investments in metering and information technology

12.1 Metering Ausgrid is responsible for the Metering Provision for approximately 1.66 million Type 5 and Type 6 metering installations in the category of sub 160MWh per annum customer connection points across Ausgrid’s franchise area. [as at 30 June 2016 - MBS E2241]

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. (In accordance with the AER determination, an up-front fee is applied for the supply of new metering equipment as at 1 July 2015. This fee covers the financial cost of new and upgrade metering hardware)

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.

Type 5 Metering Installation – Time-of-Use capable

A metering installation registered in the National Electricity Market as MRIM (which stands for Manually Read Interval Meter) and has Interval Meter(s) installed and recording 30-minute kWh data. This data is regularly downloaded by meter readers into a handheld computer via the meter’s optical communications port, with the data forwarded to the National Electricity Market systems for market settlement. As at 30 June 2016, there we approximately 0.66 million interval meters (across 0.49 million premises) in the Ausgrid network. [MBS E2241]

Type 6 Metering Installation – Flat Rate

A metering installation registered in the National Electricity Market As BASIC and has meter(s) installed capable of recording the total accumulated kWh. This reading is regularly recorded manually by meter reader who types the reading into a handheld computer, with the data subsequently forwarded to the National Electricity Market Systems. As at 30 June 2016, there were approximately 1.72 million meters operating as Accumulation Meters (across 1.16 million premises) in the Ausgrid network. [MBS E2241]

Meter Replacement

Ausgrid has been monitoring the performance of in-service meters for a number of years, using the sample testing procedures defined in the MAMP. This process identified 255,486 meters that required proactive replacement within the regulatory period, in order to fulfil its compliance obligations. These meters are being like-for-like replaced with accumulation meters. At time of writing, the remaining number of these meters is 209,855. [MBS E51322 - Min, Max and Count of Meters (LNSP Meter) as at 28/09/2016]

Ausgrid’s approach for reactive replacement is like-for-like with interval meters replaced with interval meters and accumulation meters replaced with accumulation meters.

Metering Equipment Hardware Strategy for New and Upgrade

Ausgrid installs accumulation meters as default for all new and upgrade connections, with the exception of embedded generation, three phase commercial sites, CT connected sites and customer opt-in to ToU tariff. In these circumstances, an interval meter is installed.

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12.1.1 Metering investments actual 2015/16 and forecast Table 12.1: Metering investment actual 2015/16 and forecast

Metering Investment F’cast ($m)

Actual ($m)

Forecast ($m)

(FY14 $)

2015/ 16

2015/ 16

2016/ 17

2017/ 18

2018/ 19

2019/ 20

2020/ 21

NEW & UPGRADE - Supply of

LVCT and WC meters for New and Upgrade Type 5 & 6 customer

5.55 3.93 5.78 1.61 0 0 0

REACTIVE REPLACEMENT -

Replacing faulty interval and accumulation meters

4.50 5.73 5.44 2.40 0 0 0

PROACTIVE REPLACEMENT - Replacing

failed meter populations, specifically meter modesl Email AZ, BAZ & SD

4.07 3.78 18.34 8.10 0 0 0

Total metering investments 14.11 13.44 29.55 12.10 0 0 0

12.1.1.1 Metering investment 2014/15 to 2018/19

Following the submission of an initial and amended submission, in April 2015, the AER made its final determination for the period 2014/15 to 2018/19 period. The determination approved Ausgrid’s capital program for metering. Ausgrid’s operating program for metering is presently being reviewed.

The forecast for capital investment in FY17 is slightly increased to reflect a catch-up in capital program.

The AEMC’s November 2015, determination on the new National Electricity Rules, applicable from 1 December 2017, affected the transfer of metering responsibilities away from the Network business. In response to this, the forecast capital investment has been reduced for FY18 and dropped to zero in FY19 and subsequent years.

12.2 Information and communication technology

12.2.1 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 sub-transmission 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.

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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 “tier-three” 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) and distribution network monitoring and control.

12.2.2 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.

12.2.2.1 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

December 2016 144

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.

12.2.2.2 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.

12.2.2.3 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.

12.2.2.4 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 sub-transmission network.

12.2.2.5 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.

12.2.2.6 ICT investment actual 2015/16 and forecast

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.

In the development of the forward plan and stratgy the following principles were adopted:

Business Transformation Alignment: All technology investments must contribute to the business

outcomes as defined in the Business Transformation Plan or Ausgrid corporate strategy;

Cost Effective ICT: Transition the ICT services to market providers where there is mature, lower cost

option available in the market place whilst retaining critical business knowledge and expertise;

New technologies and delivery models (e.g. cloud computing, in-memory processing) should be

adopted only if the cost and risks are more favourable than alternative options. Every new business case must consider “cloud” solutions as one of the alternatives;

Business Continuity: Systems and applications are designed and configured to deliver to an agreed

level of continuity, recovery and data loss in case of disruptions.

The key objective of the ICT Capex program is to:

Meet new and existing compliance obligations – In order for Ausgrid to appropriately manage its business processes and fulfil its 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 prudent and efficient manner reducing the risk of potential failure and/or unplanned production outages.

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Failure to maintain these platforms would lead to increased business and technical operational cost and risk to deliver core business functions.

Table 12.2 below contains a summary of actual ICT investment in 2015/16 and forecast investment in 2016/17 to 2020/21.

Table 12.2: ICT Investment actual 2015/16 and forecast 2016/17 to 2020/21 (nominal $)

Actual ($m)

Forecast ($m)

2015/16 2016/17 2017/18 2018/19 2019/20 2020/21

Total ICT Capital Investment

15.0 36.9 42.9 41.8 31.2 32.9

December 2016

Annexure A – Glossary

AER Australian Energy Regulator

AEMC The Australian Energy Market Commission is the rule maker and developer for Australian energy markets

DTAPR Distribution and Transmission Annual Planning Report prepared by a Distribution Network Service Provider under the National Electricity Rules

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

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

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

GWh gigawatt hour One GWh = 1000 megawatt hours or one million kilowatt hours

HV high voltage Consists of 11kV and 22kV distribution assets

LV low voltage Consists of 400V and 230V distribution assets

kV kilovolt One kV = 1000 volts

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

MVA (unit of electrical power) Mega Volt Amp

MVAr MVA (reactive). Where quoted as part of a demand forecast, it is assumed that capacitors are in service.

MW megawatt One MW = 1000 kW or one million watts

MWh megawatt hour One MWh = 1000 kilowatt hours

N capacity The capacity of a network (or sub-section of network) with all elements in service.

N-1 capacity The capacity of a network (or sub-section of network) following a failure of a single critical element.

NER National Electricity Rules

POE 50 In this document, refers to a demand forecast with a 50% probability of being exceeded (i.e. 1 in 2 years)

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

pf Power Factor

RIT-D Regulatory Investment Test for Distribution

SAIDI System Average Interruption Duration Index

SAIFI System Average Interruption Frequency Index

December 2016

STPIS Service Target Performance Incentive Scheme

STS Sub-transmission Substation

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

Sub-transmission system Consists of 132kV, 66kV and 33kV assets, including dual function assets

TNSP Transmission Network Service Provider

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

ZS Zone substation

December 2016

Annexure B – Reliability and Performance Licence Conditions

The Reliability and Performance Licence Conditions for Electricity Distributors came into effect on 1 July, 2014 and repeal Schedule 1 of the former Design, Reliability and Performance Licence conditions.

RELIABILITY AND PERFORMANCE

LICENCE CONDITIONS

for

ELECTRICITY DISTRIBUTORS

THE HON ANTHONY ROBERTS MP MINISTER FOR RESOURCES & ENERGY

COMMENCEMENT DATE 1 JULY 2014

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Reliability and performance – distributor’s licence conditions- 1 July 2014

EXPLANATORY NOTE

Purpose of the reliability and performance conditions:

On 1 August 2005, the then Minister for Energy imposed additional conditions pursuant to item 6 (1) (b) of Schedule 2 of the Electricity Supply Act 1995 relating to reliability performance on licences held by electricity distributors under the Electricity Supply Act 1995.

On 1 December 2007 following a review by the Minister, the conditions were varied with effect on and from that date.

Following a further review by the Minister, the conditions were varied with effect on and from 1 July 2014.

The purpose of the revised conditions is to facilitate the delivery of a reliable and cost-effective supply of electricity. The conditions impose reliability and performance standards on electricity distributors.

Electricity distributors will be required to report to the Minister to ensure compliance with the conditions. The standards are as follows:

Network overall reliability standards:

The purposes of the network overall reliability standards are to:

define minimum average reliability performance, by feeder type, for a distributor across its distribution network; and

provide a basis against which a distributor’s reliability performance can be assessed.

Individual feeder standards:

The purposes of the individual feeder standards are to:

specify minimum standards of reliability performance for individual feeders;

require a distributor to focus continually on improving the reliability of its feeders where economically justifiable; and

enable the reliability performance of individual feeders to be monitored over time.

Customer service standards:

The purpose of the customer service standards is to provide financial recognition to eligible customers who have experienced poor supply reliability from a distributor.

Commencement:

This document sets out the revised licence conditions relating to reliability and performance that are to take effect from 1 July 2014.

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Reliability and performance – distributor’s licence conditions- 1 July 2014

Relationship with existing conditions and other obligations:

These conditions are additional to conditions that the Minister has previously imposed on licences held by electricity distributors and licence conditions imposed under the Electricity Supply Act 1995 and other regulatory instruments. These conditions replace the design, reliability and performance licence conditions imposed by the Minister on 1 August 2005 (as amended on 1 December 2007).

These conditions are also supplementary to obligations imposed on electricity distributors by the Electricity Supply Act 1995, the Electricity Supply (General) Regulation 2001, the Electricity Supply (Safety and Network Management) Regulation 2008, and other regulatory instruments.

Network management generally:

Network management requires long-term planning, investment decisions and prioritisation of work to ensure, as far as is reasonably practicable, an economic and reliable supply. The licence holder has discretion to plan its investment for compliance with these licence conditions to suit its individual circumstances.

These conditions do not reduce or alter the responsibility of licence holders under their Network Management Plans to assure delivery of a safe and reliable supply. Key operating and risk management requirements to meet reliability outcomes also need to be addressed when developing network management plans.

Enforcement:

These conditions are enforceable under the Electricity Supply Act 1995 by IPART and the Minister. These conditions are not intended to create standards which are enforceable against a licence holder by individual customers.

Consultation:

Before amending the existing conditions the Minister undertook consultation with key stakeholders including the licence holders and the Minister administering the Protection of the Environment Administration Act 1991. The Minister has given due consideration to submissions received during consultation.

Reporting:

Performance and audit reports will be required under these licence condition. Reliability performance reporting will continue to be implemented under the Electricity Supply (Safety and Network Management) Regulation 2008.

Review:

The Minister may, at his discretion, review the licence conditions at any time in accordance with the Electricity Supply Act 1995.

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Reliability and performance – distributor’s licence conditions- 1 July 2014

RELIABILITY AND PERFORMANCE CONDITIONS

14. .Repealed

15. Network overall reliability standards

15.1 A licence holder must not, when excluded interruptions are disregarded, exceed in a financial year the SAIDI average standards that apply to its feeder types.

15.2 A licence holder must not, when excluded interruptions are disregarded, exceed in a financial year the SAIFI average standards that apply to its feeder types.

16. Individual feeder performance

16.1 This condition applies where one or more of the feeders of a licence holder exceed the relevant individual feeder standards for any 12 month period ending at the end of March, June, September or December, when excluded interruptions are disregarded.

16.2 A licence holder must:

(a) investigate the causes for each feeder exceeding the individual feeder standards;

(b) by the end of the quarter following the quarter in which the feeder first exceeded the individual feeder standards, complete an investigation report identifying the causes and as appropriate, any action required to improve the performance of each feeder to the individual feeder standards;

(c) complete any operational actions identified in the investigation report to improve the performance of each feeder to the individual feeder standards by the end of the third quarter following the quarter in which each feeder first exceeded the individual feeder standards;

(d) except as permitted by condition 16.2(e), where the investigation report identifies actions, other than operational actions, required to improve the performance of each feeder to the individual feeder standards, develop a project plan, including implementation timetable, and commence its implementation by the end of the second quarter following the quarter in which the feeder first exceeded the individual feeder standards;

(e) consider non-network strategies which provide reliable outcomes for customers. Where found by the investigation report to be equal or more cost-effective than the lowest cost feasible network option such strategies shall be adopted rather than network augmentation options;

(f) ensure that the implementation timetable for the network project plan or alternative non-network solutions is as short as is reasonably practicable;

(g) where all reasonable steps to improve supply reliability have been taken, the costs of further actions to rectify the non-compliance must be subject to a cost benefit analysis. Where such analysis does not provide a positive benefit, no further action will be taken to improve the feeder’s performance and the ongoing non-conformance with the individual feeder standards will be reported to the Minister.

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16.3 The investigation report is to include a documented rectification plan where action is found to be justified in order to improve the performance of a feeder to the individual feeder standards. The action that is required may involve work to other network elements, or may involve only repair or maintenance work where capital works are not warranted and take into account any one-off events and previous performance trends.

17. Customer service standards

17.1 A licence holder must pay the sum of $80 to a customer where the licence holder exceeds the interruption duration standard at the customer’s premises and the customer has made a claim to the licence holder within three months of the interruption.

17.2 A licence holder must pay the sum of $80 to a customer where the licence holder exceeds the interruption frequency standard at the customer’s premises in a financial year and the customer has made a claim to the licence holder within three months of the end of the financial year to which the interruptions relate.

17.3 A licence holder must determine a claim for payment under condition 17, and notify the customer of the determination in writing, within one month of receipt of a claim. For customers eligible for payment, the notice of determination must include the amount to be paid, the manner of payment and the timing of payment. Where the claim is not paid (whether in part or in full), the notice of determination must include reasons for the decision.

17.4 A licence holder is required to take reasonable steps to make customers aware of the availability of payments on the terms set out in condition 17. Reasonable steps include, as a minimum, publication of information on the licence holder’s website and annual newspaper advertisements. On request from a customer, a licence holder must provide written information on the availability of payments on the terms set out in condition 17.

17.5 A licence holder is required to make only one payment of $80 to a customer per premises in a financial year for exceeding the interruption frequency standard.

17.6 A licence holder is required to pay no more than $320 under condition 17 to a customer per premises in any one financial year.

17.7 A payment under this condition does not:

(a) In any way alter or diminish any rights that a customer may have against any person under any trade practices or other applicable legislation, common law or contract;

(b) Represent any admission of legal liability by the licence holder; or

(c) Alter, vary or exclude the operation of section 119 of the National Electricity Law or any other statutory limitations on liability or immunities applicable to a licence holder.

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Reliability and performance – distributor’s licence conditions- 1 July 2014

17.8 Customers who are eligible for payments under this clause are limited to those customers who are supplied electricity through a metered connection point on an electricity distributor’s system.

18. Performance monitoring and reporting

18.1 Repealed

Network overall reliability standards report

18.2 A licence holder must submit a network overall reliability standards quarterly report to the Minister within one month of the end of each quarter.

18.3 Each network overall reliability standards report must include the following matters for the previous 12 month period to the end of that quarter:

(a) performance against the SAIDI average standards and SAIFI average standards by feeder type, disregarding excluded interruptions;

(b) reasons for any non-compliance by the licence holder with the network overall reliability standards and plans to improve performance; and

(c) any other matter formally notified by the Minister in writing.

Individual feeder standards report

18.4 A licence holder must submit, within one month of the end of each quarter, a quarterly individual feeder standards report to the Minister on feeders that exceeded the relevant individual feeder standards during the previous 12 month period to the end of that quarter, together with, for each feeder:

(a) the date at which the feeder first exceeded the relevant individual feeder standard, together with the actual SAIDI and SAIFI performance of the feeder for the 12 month period;

(b) details of the remedial action that the licence holder intends taking, or has taken, to improve the performance of those feeders; and

(c) the date of completion, or the date of planned completion, of the remedial action plan. or

(d) details of the investigation and action proposed or undertaken leading to the decision to advise the Minister that it is not economically justifiable to bring the feeder performance into compliance with the individual feeder standards.

Customer service standards report

18.5 A licence holder must submit a quarterly customer service standards report to the Minister on the following matters within one month of the end of each quarter, for the preceding quarter and for the previous 12 month period to the end of that quarter:

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Reliability and performance – distributor’s licence conditions- 1 July 2014

(a) the number of payments given under condition 17 to customers by each type of area listed in Column 1 of Table 1 and by the type of standard, as shown in Columns 2 and 3 of Table 1.

(b) the number of claims not paid (whether in part or full) under condition 17 by each type of area listed in Column 1 of Table 1 and by the type of standard, as shown in Columns 2 and 3 of Table 1.

Major network incident reporting

18.6 A licence holder must report to the Minister within 24 hours any major network incidents involving significant injury to persons, loss of property or widespread supply interruptions. High level severity network incidents are to be advised immediately.

Independent audit report

18.7 An independent audit must be conducted after the end of each financial year to audit the licence holder’s performance against the:

(a) Repealed

(b) network overall reliability standards;

(c) individual feeder standards; and

(d) customer service standards.

18.8 A licence holder is required to nominate a person to conduct the independent audit by notice in writing to IPART. The licence holder must give notice in accordance with any time specified by IPART in writing to the licence holder, or, if no time has been specified, no later than 1 July of the year in which the report is to be submitted to the Minister and IPART.

18.9 The person nominated is to be a person who is:

(a) independent of the licence holder; and

(b) competent to exercise the functions of an auditor in respect of the matters to be audited.

18.10 The nomination of an auditor by a licence holder ceases to have effect if IPART advises the licence holder, by notice in writing, that the nomination is not acceptable or has ceased to be acceptable.

18.11 IPART may nominate an auditor to carry out an audit, and the person so nominated is taken to have been nominated by the licence holder, if:

(a) the nomination of an auditor by the licence holder ceases to have effect; or

(b) the licence holder fails to nominate an auditor to carry out the audit in accordance with any requirements specified by IPART by notice in writing to the licence holder.

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18.12 A licence holder must provide a copy of the auditor’s report by 30 September each year to IPART and the Minister.

General matters concerning reports

18.13 Where the Minister determines the format of a report required by this condition, a licence holder must submit the report in that format.

18.14 The Minister may from time to time establish guidelines to be followed by the licence holder in complying with reports required by this condition and the licence holder must comply with any such guidelines.

18.15 The Minister may from time to time require, by notice in writing to the licence holder, further reports relating to these licence conditions including, without limitation, reports relating to capital expenditure works, network refurbishment and maintenance programs.

18.16 A licence holder must provide a report submitted to the Minister under this condition to IPART, if requested to do so by IPART by notice in writing.

19 Interpretation and definitions

19.1 These licence conditions are imposed by the Minister pursuant to item 6(1)(b) of Schedule 2 of the Act.

19.2 These licence conditions replace the design, reliability and performance licence conditions imposed by the Minister on electricity distributors on 1 August 2005 (as amended on 1 December 2007).

19.3 These licence conditions are in addition to other licence conditions imposed by the Minister, licence conditions under the Act or Regulations, and other obligations imposed on licence holders by the Act and Regulations.

19.4 These revised conditions take effect from 1 July 2014.

19.5 Expressions used in these licence conditions that are defined in the Act or the Regulations made under the Act have, unless otherwise stated, the meanings set out in the Act or the Regulations.

19.6 The Explanatory Note to these licence conditions does not form part of the licence conditions.

19.7 Repealed

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19.8 In these licence conditions:

Act means the Electricity Supply Act 1995.

CBD Sydney feeder means a feeder forming part of the triplex 11kV cable system supplying predominantly commercial high-rise buildings, within the City of Sydney.

customer means a wholesale or retail customer who is supplied electricity through a connection point on an electricity distributor’s system.

customer service means the customer service standards in Schedule 5 standards to these conditions.

Department means the Department of Trade and Investment, Regional Infrastructure and Services.

Emergency service has the same meaning as in section 3 of the State organisation Emergency and Rescue Management Act 1989.

excluded interruptions means excluded interruptions listed in Schedule 4 to these conditions.

feeder means a high-voltage line operating at over 1kV and generally at or below 22kV that connects between a zone substation and a distribution substation, excluding short radial sections off the trunk feeder used to supply a small number of distribution substations (eg a spur line into a peninsula or valley).

feeder type means a CBD Sydney feeder, long rural feeder, short rural feeder or urban feeder as the case may be.

financial year means the period commencing on 1 July and ending 30 June the following calendar year.

high level severity means as defined by the Department’s Significant Electrical Network Incident reporting scheme.

individual means the individual feeder standards in Schedule 3 feeder standards these conditions.

interruption means any temporary unavailability of electricity supply to a customer associated with an outage of the distribution system including outages affecting a single premises, but does not include disconnection.

interruption means the interruption duration standards set out duration standards in Schedule 5 to these conditions.

interruption means the interruption frequency standards set frequency standards out in Schedule 5 to these conditions.

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IPART means the Independent Pricing and Regulatory Tribunal established under the Independent Pricing and Regulatory Tribunal Act 1992.

licence holder means the holder of an electricity distributor’s licence.

local government area has the same meaning as in the Local Government Act 1993

long rural feeder means a feeder with a total feeder length greater than 200 km which is not a CBD Sydney feeder or an urban feeder.

major event day means a day determined under Schedule 6.

major network incident means as defined by the Department’s Significant Electrical Network Incident reporting scheme.

metropolitan means the areas comprising the local government areas and suburbs listed in Schedule 7.

Minister means the Minister administering the Act.

non-metropolitan means areas in NSW other than areas defined as metropolitan.

non-urban means areas which are not urban.

planned interruption means an interruption for which advance notice has been provided or which has been requested by a customer in accordance with the meaning contained in the National Energy Retail Law (Adoption) Regulation 2013.

quarter means a period of three months commencing 1 January, 1 April, 1 July and 1 October and concluding on the following 31 March, 30 June, 30 September and 31 December dates respectively, as the case may be.

Regulations means Regulations made under the Act.

regulatory period means the period for which the economic regulator provides for a price path for network income and for the purpose of this document will be taken to be a period of five years.

network overall means the requirements imposed under condition 15 of reliability standards these conditions.

SAIDI means the average derived from the sum of the durations of each sustained customer interruption (measured in minutes), divided by the total number of customers (averaged over the financial year) of the licence holder.

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SAIFI means the average derived from the total number of sustained customer interruptions divided by the total number of customers (averaged over the financial year) of the licence holder.

SAIDI average standards means the standards set out in item 1, Schedule 2.

SAIFI average standards means the standards set out in item 2, Schedule 2.

SAIDI individual means the standards set out in item 1, Schedule 3. feeder standards

SAIFI individual means the standards set out in item 2, Schedule 3. feeder standards

Severe thunderstorm or means weather given this classification by the severe weather Bureau of Meteorology.

short rural feeder means a feeder with a total feeder route length less than 200 km, and which is not a CBD Sydney feeder or an urban feeder.

suburb means an area defined by boundaries determined and gazetted by the Geographical Names Board of New South Wales.

table 1 means Table 1 in Schedule 5 to these conditions.

table 2 means Table 2 in Schedule 5 to these conditions.

third party does not include a person or body contracted or authorised by the licence holder to take action, or any animal or plant life.

transmission system means a network as defined in the National Electricity Rules.

urban feeder means a feeder with actual maximum demand over the reporting period per total feeder route length greater than 0.3 MVA/km and which is not a CBD Sydney Feeder.

SCHEDULE 1 – Repealed

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SCHEDULE 2 – NETWORK OVERALL RELIABILITY STANDARDS

1. SAIDI Average Reliability Duration Standards (Minutes per customer)

SAIDI (Minutes per customer) AUSGRID

Feeder Type CBD Sydney 45

Urban 80

Short-rural 300

Long-rural 700

ENDEAVOUR ENERGY Urban 80

Short-rural 300

Long-rural n/a

ESSENTIAL ENERGY Urban 125

Short-rural 300

Long-rural 700

2. SAIFI Average Reliability Interruption Standards (Number per customer)

SAIFI (Number per customer) AUSGRID

Feeder Type CBD Sydney 0.3

Urban 1.2

Short-rural 3.2

Long-rural 6

ENDEAVOUR ENERGY Urban 1.2

Short-rural 2.8

Long-rural n/a

ESSENTIAL ENERGY Urban 1.8

Short-rural 3.0

Long-rural 4.5

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SCHEDULE 3 – INDIVIDUAL FEEDER STANDARDS

1. SAIDI Individual Feeder Average Reliability Duration Standards (Minutes per customer)

SAIDI (Minutes per customer) AUSGRID

Feeder Type CBD Sydney 100

Urban 350

Short-rural 1000

Long-rural 1400

ENDEAVOUR ENERGY Urban 350

Short-rural 1000

Long-rural 1400

ESSENTIAL ENERGY Urban 400

Short-rural 1000

Long-rural 1400

2 SAIFI Individual Feeder Standards Average Reliability Interruption Standards (Number per customer)

SAIFI (Number per customer) AUSGRID

Feeder Type CBD Sydney 1.4

Urban 4

Short-rural 8

Long-rural 10

ENDEAVOUR ENERGY Urban 4

Short-rural 8

Long-rural 10

ESSENTIAL ENERGY Urban 6

Short-rural 8

Long-rural 10

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SCHEDULE 4 – EXCLUDED INTERRUPTIONS

The following types of interruptions (and no others) are excluded interruptions:

(a) an interruption of a duration of one minute or less;

(b) an interruption resulting from:

(i) load shedding due to a shortfall in generation;

(ii) a direction or other instrument issued under the National Electricity Law, Energy and Utilities Administration Act 1987, the Essential Services Act 1988 or the State Emergency and Rescue Management Act 1989 to interrupt the supply of electricity;

(iii) automatic shedding of load under the control of under-frequency relays following the occurrence of a power system under-frequency condition described in the Power System Security and Reliability Standards made under the National Electricity Rules;

(iv) a failure of the shared transmission system;

(c) a planned interruption;

(d) any interruption to the supply of electricity on a licence holder’s distribution system which commences on a major event day; and

(e) an interruption caused by a customer’s electrical installation or failure of that electrical installation.

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SCHEDULE 5 – CUSTOMER SERVICE STANDARDS

Interruption duration standard:

1. The interruption duration standard is the maximum duration, set out in column 2 of table 1, of an interruption to a customer’s premises located in the relevant area in column 1 of table 1.

Interruption frequency standard:

2. The interruption frequency standard is the maximum number of interruptions in a financial year set out in column 3 of table 1, to a customer’s premises located in the relevant area in column 1 of table 1:

Table 1

Column 1 Column 2 Column 3

Type of area in which customer’s

premises is located

Interruption duration standard (hours)

Interruption frequency standard (number of

interruptions and hours of duration)

metropolitan 12 4 interruptions of greater than or equal to 4 hours

non-metropolitan 18 4 interruptions of greater than or equal to 5 hours

Interruptions to be disregarded

3. In calculating the interruption duration standard or the interruption frequency standard the following types of interruptions (and no others) are excluded:

(a) an interruption resulting from the following external causes:

(i) a shortfall in generation;

(ii) a failure or instability of the shared transmission system;

(iii) a request or direction from an emergency service organisation;

(b) a planned interruption;

(c) an interruption within a region in which a natural disaster has occurred and:

(i) the responsible Minister has made a declaration of a Natural Disaster enabling the NSW Disaster Assistance Arrangements to apply in respect of that natural disaster for that region; and

Page 15 of 20

Reliability and performance – distributor’s licence conditions- 1 July 2014

(ii) the interruption occurred during the period for which a declaration of a Natural Disaster and NSW Disaster Assistance Arrangements were in effect;

(d) an interruption caused by the effects of a severe thunderstorm or severe weather as advised by the Bureau of Meteorology. These effects may include the necessary operation of a circuit protection device which interrupts supply to customers in areas not directly impacted by the severe thunderstorm or severe weather.

(e) an interruption caused by third party actions other than animal or vegetation interference (e.g. vehicle-hit-pole, vandalism) where the interruption is not also caused by any failure of the licence holder to comply with relevant plans, codes, guides or standards (e.g. low conductor clearance).

Page 16 of 20

Reliability and performance – distributor’s licence conditions- 1 July 2014

SCHEDULE 6 – MAJOR EVENT DAY

The following material is reprinted with permission from IEEE Std. 1366-2003, IEEE for Electric Power Distribution Reliability Indices, by IEEE. The IEEE disclaims any responsibility or liability resulting from the placement and use in the described manner. For the avoidance of doubt and the promotion of consistency, Items “a”, “b”, “c” and “e” listed in Schedule 4 should be removed from daily records before applying the following methodology to calculate a major event day.

Explanation and Purpose

The following process (“Beta Method”) is used to identify major event days which are to be excluded from the network overall reliability standards and individual feeder standards.

Its purpose is to allow major events to be studied separately from daily operation, and in the process, to better reveal trends in a daily operation that would be hidden by the large statistical effect of major events.

A major event day under the Beta Method is one in which the daily total system (i.e. not on a feeder type basis) SAIDI value (“daily SAIDI value”) exceeds a threshold value, TMED. The SAIDI is used as the basis of determining whether a day is a major event day since it leads to consistent results regardless of utility size and because SAIDI is a good indicator of operational and design stress.

In calculating the daily total system SAIDI, any interruption that spans multiple days is deemed to accrue on the day on which the interruption begins. That is, all minutes without supply resulting from an interruption beginning on a major event day are deemed to have occurred in the major event day, including those minutes without supply occurring on following days.

Determining a major event day

The major event day identification threshold value TMED is calculated at the end of each financial year for each electricity distributor for use during the next financial year as follows:

a) Collect daily SAIDI values for the last five financial years. If fewer than five years of historical data are available, use all available historical data for the lesser period.

b) Only those days that have a daily SAIDI value will be used to calculate the TMED

(i.e. days that did not have any interruptions are not included).

c) Take the natural logarithm (In) of each daily SAIDI value in the data set.

d) Find α (Alpha), the average of the logarithms (also known as the log-average) of the data set.

e) Find β (Beta), the standard deviation of the logarithms (also known as the log-standard deviation) of the data set.

f) Complete the major event day threshold TMED using the following equation: (α + 2.5β)TMED = e

g) Any day with daily SAIDI value greater than the threshold value TMED which occurs during the subsequent financial year is classified as a major event day.

Treatment of a major event day

To avoid doubt, a major event day, and all interruptions beginning on that day, are excluded from the calculation of an electricity distributor’s SAIDI and SAIFI in respect of all of its feeder types.

From IEEE Std. 1366-2003. Copyright 2003. All rights reserved.

Page 17 of 20

Reliability and performance – distributor’s licence conditions- 1 July 2014

SCHEDULE 7 – LIST OF METROPOLITAN AREAS

1. Local Government Areas

ASHFIELD HUNTERS HILL PITTWATER

AUBURN HURSTVILLE RANDWICK

BANKSTOWN KOGARAH ROCKDALE

BAULKHAM HILLS KU-RING-GAI RYDE

BLACKTOWN LAKE MACQUARIE SHELLHARBOUR

BOTANY BAY LANE COVE STRATHFIELD

BURWOOD LEICHHARDT SUTHERLAND

CAMDEN LIVERPOOL SYDNEY

CAMPBELLTOWN MANLY WARRINGAH

CANTERBURY MARRICKVILLE WAVERLEY

CANADA BAY MOSMAN WILLOUGHBY

FAIRFIELD NEWCASTLE WOLLONGONG

GOSFORD NORTH SYDNEY WOOLLAHRA

HOLROYD PARRAMATTA WYONG

HORNSBY PENRITH

2. Suburbs

A. Blue Mountains area

BLACKHEATH LINDEN

BLAXLAND MEDLOW BATH

BULLABURRA MOUNT RIVERVIEW

FAULCONBRIDGE MOUNT VICTORIA

GLENBROOK SPRINGWOOD

HAWKESBURY HEIGHTS VALLEY HEIGHTS

HAZELBROOK WARRIMOO

KATOOMBA WENTWORTH FALLS

LAPSTONE WINMALEE

LAWSON WOODFORD

LEURA YELLOW ROCK

Page 18 of 20

Reliability and performance – distributor’s licence conditions- 1 July 2014

B. Cessnock-Bellbird area

ABERDARE CESSNOCK

BELLBIRD KEARSLEY

BELLBIRD HEIGHTS NULKABA

C. Kiama area

BOMBO KIAMA HEIGHTS

KIAMA MINNAMURRA

KIAMA DOWNS

D. Kurri Kurri-Weston area

ABERMAIN PELAW MAIN

HEDDON GRETA STANFORD MERTHYR

KURRI KURRI WESTON

NEATH

E. Maitland area

ABERGLASSLYN MOUNT DEE

ASHTONFIELD OAKHAMPTON

BOLWARRA OAKHAMPTON HEIGHTS

BOLWARRA HEIGHTS PITNACREE

EAST MAITLAND RAWORTH

HORSESHOE BEND RUTHERFORD

LARGS SOUTH MAITLAND

LORN TELARAH

LOUTH PARK TENAMBIT

MAITLAND THORNTON

METFORD WOODBERRY

MORPETH

Page 19 of 20

Reliability and performance – distributor’s licence conditions- 1 July 2014

F. Newcastle Industrial area

FERN BAY WILLIAMTOWN

FULLERTON COVE

G. Port Stephens area

CORLETTE SALAMANDER BAY

FINGAL BAY SHOAL BAY

NELSON BAY SOLDIERS POINT

H. Raymond Terrace area

HEATHERBRAE TOMAGO

RAYMOND TERRACE

I. Richmond-Windsor area

BLIGH PARK NORTH RICHMOND

CLARENDON RICHMOND

HOBARTVILLE SOUTH WINDSOR

MCGRATHS HILL VINEYARD

MULGRAVE WINDSOR

Page 20 of 20

December 2016

Annexure C – STS and ZS Load Forecast

Section 3.4.1 specifies the generation systems included in the “Solar PV” and “Other” sections of the Embedded Generation column of each table.

Camperdown a

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

61.3 65.1 41.7 44.8 0.0 0.0 34.8 - 0.1 0.0

110.7 - 60.8 - 1.9 0.0 8.8 - 0.0

- 27.7 - 13.9 0.0 0.0 - 6.3 0.5 0.0

141.2 141.2 70.3 70.3 18.3 14.8 20.0 - 0.3 6.4

233.2 233.2 131.7 134.6 - - 8.8 - 0.1 0.0

SUMMER - Camperdown and Blackwattle Bay Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 20.2 19.8 19.7 19.1 18.4 18.2 18.3 18.8 Blackwattle Bay 33/5kV ZSPF 0.88 0.88 0.91 0.91 0.91 0.91 0.91 0.91 Blackwattle Bay 33/5kV ZSMVA - 5.3 13.1 19.7 21.8 21.9 22.2 22.6 Camperdown 33/11kV ZSPF - 0.90 0.90 0.91 0.91 0.91 0.91 0.9 Camperdown 33/11kV ZSMVA 18.9 18.4 - - - - - - Camperdown 33/5kV ZSPF 0.88 0.88 - - - - - - Camperdown 33/5kV ZSMVA 51.0 50.1 52.8 53.1 57.0 57.8 57.6 58.5 Darling Harbour 132/11kV ZSPF 0.95 0.95 0.96 0.96 0.96 0.96 0.96 0.96 Darling Harbour 132/11kV ZSMVA 69.7 73.7 88.9 116.8 120.0 121.9 125.1 125.9 Pyrmont 132/33kV STSPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Pyrmont 132/33kV STS

WINTER - Camperdown and Blackwattle Bay Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 18.8 17.7 18.0 16.8 16.7 16.8 17.1 17.6 Blackwattle Bay 33/5kV ZSPF 0.92 0.92 0.93 0.93 0.93 0.93 0.93 0.93 Blackwattle Bay 33/5kV ZSMVA - - - 13.5 21.2 21.5 21.8 22.3 Camperdown 33/11kV ZSPF - - - 0.94 0.94 0.9 0.9 0.9 Camperdown 33/11kV ZSMVA 19.3 16.0 14.7 - - - - - Camperdown 33/5kV ZSPF 0.93 0.93 0.95 - - - - - Camperdown 33/5kV ZSMVA 43.8 40.0 42.8 39.8 47.2 46.4 47.3 48.1 Darling Harbour 132/11kV ZSPF 0.96 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Darling Harbour 132/11kV ZSMVA 62.3 67.6 75.1 101.2 112.4 114.6 117.1 120.7 Pyrmont 132/33kV STSPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Pyrmont 132/33kV STS

Darling Harbour 132/11kV ZS

Pyrmont 132/33kV STS

Actual Load Forecast Load

Blackwattle Bay 33/5kV ZS

Camperdown 33/11kV ZS

Darling Harbour 132/11kV ZS

Pyrmont 132/33kV STS

Camperdown 33/5kV ZS

Substation

SubstationForecast Load

Blackwattle Bay 33/5kV ZS

Camperdown 33/11kV ZS

Camperdown 33/5kV ZS

Blackwattle Bay 33/5kV ZS

Camperdown 33/11kV ZS

Camperdown 33/5kV ZS

Darling Harbour 132/11kV ZS

Pyrmont 132/33kV STS

Camperdown and Blackwattle Bay Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C1 of C27

Canterbury Ban

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

127.7 128.2 63.5 65.0 21.4 18.1 4.5 - 3.2 0.0

206.1 223.4 137.4 155.8 - - 1.3 - 3.5 0.0

52.1 52.1 31.8 32.9 4.7 3.4 4.5 - 1.4 0.0

140.6 140.6 87.0 87.0 28.8 27.1 3.5 - 3.7 0.0

274.4 274.4 176.8 194.5 - - 3.3 10.5 6.6 0.0

87.6 87.6 61.9 61.9 19.6 22.9 - 16.5 2.2 0.0

70.5 70.5 44.8 44.8 14.0 13.2 4.3 - 1.1 0.0

152.4 152.5 86.2 92.0 16.1 10.5 4.5 - 1.8 6.0

35.8 35.8 19.6 19.6 9.0 8.0 8.8 - 1.2 0.1

123.2 123.2 61.2 64.6 18.2 16.2 8.3 - 2.9 0.0

- - - - 0.0 0.0 - - 0.0

107.0 107.0 54.9 54.9 27.8 22.4 8.8 - 2.4 0.1

109.5 110.1 75.8 78.6 7.3 7.6 4.3 3.5 2.2 0.0

76.2 76.2 44.9 47.8 10.3 8.8 2.8 - 2.9 2.4

152.4 152.5 94.6 99.7 33.3 26.4 4.0 - 3.5 0.1

SUMMER - Canterbury Bankstown Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 22.3 38.5 43.8 47.5 48.3 48.4 48.7 49.0 Bankstown 132/11kV ZSPF 0.77 0.80 0.80 0.81 0.81 0.81 0.81 0.81 Bankstown 132/11kV ZSMVA 77.2 69.4 74.9 63.0 63.8 64.4 65.3 66.5 Bankstown 132/33kV STSPF 1.00 0.90 1.00 1.00 1.00 1.00 1.00 1.0 Bankstown 132/33kV STSMVA 22.7 22.2 30.9 23.5 24.0 24.4 24.8 25.2 Bass Hill 33/11kV ZSPF 0.90 0.88 0.95 0.95 0.95 0.95 0.95 0.95 Bass Hill 33/11kV ZSMVA 52.6 50.2 64.4 61.1 69.5 71.0 72.2 73.3 Campsie 33/11kV ZSPF 0.92 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Campsie 33/11kV ZSMVA 120.5 119.8 132.9 128.1 135.4 138.7 141.4 143.7 Canterbury 132/33kV STSPF 1.00 0.99 1.00 1.00 1.00 0.99 0.99 0.99 Canterbury 132/33kV STSMVA 34.3 32.1 37.3 35.9 37.7 39.1 40.2 41.0 Dulwich Hill 33/11kV ZSPF 0.95 0.94 0.99 0.99 0.99 0.99 0.99 1.0 Dulwich Hill 33/11kV ZSMVA 19.1 17.7 20.7 19.3 19.9 20.3 20.8 21.2 Enfield 33/11kV ZSPF 0.92 0.89 0.93 0.93 0.93 0.93 0.93 0.93 Enfield 33/11kV ZSMVA 71.9 53.1 63.5 60.0 61.1 61.7 62.5 63.3 Greenacre Park 132/11kV ZSPF 0.97 0.96 0.97 1.00 1.00 1.00 1.00 1.00 Greenacre Park 132/11kV ZSMVA 20.8 22.4 23.2 23.4 23.3 23.3 23.4 23.6 Leightonfield 33/11kV ZSPF 0.94 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Leightonfield 33/11kV ZSMVA 44.1 46.3 47.2 45.8 44.3 43.3 43.0 43.3 Milperra 132/11kV ZSPF 0.9 0.9 0.9 0.9 0.9 0.9 0.92 0.92 Milperra 132/11kV ZSMVA - - - - - - - - Padstow 33/11kV ZSPF - - - - - - - - Padstow 33/11kV ZSMVA 11.3 37.0 41.3 41.2 41.9 42.9 43.7 44.2 Potts Hill 132/11kV ZSPF 0.90 0.83 0.84 0.84 0.84 0.84 0.84 0.8 Potts Hill 132/11kV ZSMVA 47.6 34.0 35.2 34.9 35.2 35.4 35.9 36.8 Punchbowl 33/11kV ZSPF 0.91 0.90 0.93 0.93 0.93 0.93 0.93 0.93 Punchbowl 33/11kV ZSMVA 36.6 38.2 46.2 41.2 41.3 41.5 42.0 42.8 Revesby 132/11kV ZSPF 0.95 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Revesby 132/11kV ZSMVA 49.1 39.2 44.0 46.7 46.6 46.7 47.1 47.9 Sefton 132/11kV ZSPF 0.91 0.90 0.91 0.91 0.91 0.91 0.91 0.91 Sefton 132/11kV ZS

WINTER - Canterbury Bankstown Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 21.8 30.8 37.1 38.3 39.6 40.0 40.4 41.2 Bankstown 132/11kV ZSPF 0.79 0.82 0.83 0.84 0.84 0.84 0.84 0.84 Bankstown 132/11kV ZSMVA 76.9 62.9 64.6 57.6 57.8 58.1 58.9 60.4 Bankstown 132/33kV STSPF 0.99 0.99 0.99 0.99 0.99 1.0 1.0 1.0 Bankstown 132/33kV STSMVA 20.7 21.3 22.1 18.2 18.3 18.5 18.8 19.3 Bass Hill 33/11kV ZSPF 0.94 0.94 0.96 0.96 0.96 0.96 0.96 0.96 Bass Hill 33/11kV ZSMVA 57.8 57.3 60.5 57.4 63.4 63.2 63.8 65.2 Campsie 33/11kV ZSPF 0.86 0.86 0.99 0.99 0.99 0.99 0.99 0.99 Campsie 33/11kV ZSMVA 131.5 128.3 133.8 129.7 133.8 135.2 137.2 140.0 Canterbury 132/33kV STSPF 0.98 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Canterbury 132/33kV STSMVA 41.8 40.8 43.6 43.3 45.0 46.3 47.4 48.4 Dulwich Hill 33/11kV ZSPF 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Dulwich Hill 33/11kV ZSMVA 19.7 19.7 19.6 18.9 18.9 19.1 19.4 19.9 Enfield 33/11kV ZSPF 0.9 0.9 1.0 1.0 0.96 0.96 0.96 0.96 Enfield 33/11kV ZSMVA 55.9 42.0 41.6 40.0 40.7 40.4 40.7 41.6 Greenacre Park 132/11kV ZSPF 0.98 0.98 0.99 1.00 1.00 1.0 1.0 1.0 Greenacre Park 132/11kV ZSMVA 18.9 18.6 20.8 20.9 20.9 20.9 21.1 21.4 Leightonfield 33/11kV ZSPF 0.96 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Leightonfield 33/11kV ZSMVA 41.8 38.9 42.0 40.8 39.5 38.8 38.7 39.3 Milperra 132/11kV ZSPF 0.90 0.95 0.94 0.94 0.94 0.94 0.94 0.94 Milperra 132/11kV ZSMVA - - - - - - - - Padstow 33/11kV ZSPF - - - - - - - - Padstow 33/11kV ZSMVA 0.9 30.8 33.2 31.9 32.1 32.9 33.6 34.4 Potts Hill 132/11kV ZSPF 0.90 0.84 0.85 0.85 0.85 0.85 0.85 0.85 Potts Hill 132/11kV ZSMVA 47.2 35.3 36.6 32.2 32.3 32.5 33.0 34.0 Punchbowl 33/11kV ZSPF 0.96 0.96 0.98 0.98 0.98 0.98 0.98 0.98 Punchbowl 33/11kV ZSMVA 35.8 35.9 39.5 38.0 37.4 37.3 37.7 38.6 Revesby 132/11kV ZSPF 0.97 0.98 0.97 0.97 0.97 1.0 1.0 1.0 Revesby 132/11kV ZSMVA 53.8 32.6 34.9 34.1 33.7 33.8 34.4 35.4 Sefton 132/11kV ZSPF 0.93 0.95 0.97 0.97 0.97 0.97 0.97 0.97 Sefton 132/11kV ZS

Punchbowl 33/11kV ZS

Revesby 132/11kV ZS

Sefton 132/11kV ZS

Greenacre Park 132/11kV ZS

Substation

Canterbury 132/33kV STS

Dulwich Hill 33/11kV ZS

Enfield 33/11kV ZS

Leightonfield 33/11kV ZS

Milperra 132/11kV ZS

Padstow 33/11kV ZS

Potts Hill 132/11kV ZS

Forecast Load

Bankstown 132/11kV ZS

Bankstown 132/33kV STS

Bass Hill 33/11kV ZS

Campsie 33/11kV ZS

Actual Load Forecast Load

Bankstown 132/11kV ZS

Bankstown 132/33kV STS

Sefton 132/11kV ZS

Campsie 33/11kV ZS

Canterbury 132/33kV STS

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

Bass Hill 33/11kV ZS

Substation

Punchbowl 33/11kV ZS

Revesby 132/11kV ZS

Sefton 132/11kV ZS

Potts Hill 132/11kV ZS

Bankstown 132/11kV ZS

Bankstown 132/33kV STS

Bass Hill 33/11kV ZS

Campsie 33/11kV ZS

Canterbury 132/33kV STS

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

Canterbury Bankstown Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C2 of C27

Carlingford

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

113.5 113.5 74.9 74.9 38.3 31.0 7.3 - 2.2 1.5

113.5 113.6 69.8 72.3 18.6 16.8 4.8 - 2.0 0.0

171.5 171.5 114.3 114.3 36.5 25.9 15.5 - 0.7 0.0

152.8 157.7 103.8 108.7 37.9 31.4 4.8 - 3.3 0.0

- - - - 0.0 0.0 - - 0.0

113.3 113.3 61.3 61.3 40.8 32.9 4.0 - 1.8 0.4

SUMMER - Carlingford Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 54.0 54.4 59.6 57.4 59.1 58.4 58.5 59.5 Epping 66/11kV ZSPF 0.98 0.94 0.94 0.98 0.98 0.98 0.98 0.98 Epping 66/11kV ZSMVA 42.7 41.9 50.8 49.5 51.9 52.6 53.3 54.2 Hunters Hill 66/11kV ZSPF 0.88 0.87 0.94 0.94 0.94 0.94 0.94 0.9 Hunters Hill 66/11kV ZSMVA 62.6 69.6 76.3 80.1 84.9 94.3 95.1 95.9 Macquarie Park 132/11kV ZSPF 0.96 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Macquarie Park 132/11kV ZSMVA 62.9 63.9 71.9 72.6 75.0 74.9 75.7 77.3 Meadowbank 132/11kV ZSPF 0.96 0.93 0.95 0.95 0.95 0.95 0.95 0.95 Meadowbank 132/11kV ZSMVA - - - - - - - - North Ryde 66/11kV ZSPF - - - - - - - - North Ryde 66/11kV ZSMVA 46.3 44.0 49.5 49.0 51.1 51.2 51.5 52.1 Top Ryde 132/11kV ZSPF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 1.0 Top Ryde 132/11kV ZS

WINTER - Carlingford Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 45.9 - 48.1 46.5 48.6 47.9 48.2 49.3 Epping 66/11kV ZSPF 0.99 - 0.98 1.00 1.00 1.00 1.00 1.00 Epping 66/11kV ZSMVA 42.2 42.7 45.8 44.3 44.3 44.9 45.3 46.4 Hunters Hill 66/11kV ZSPF 0.94 0.96 0.96 0.96 0.96 1.0 1.0 1.0 Hunters Hill 66/11kV ZSMVA 54.2 54.1 54.1 54.9 58.6 68.4 68.2 68.9 Macquarie Park 132/11kV ZSPF 0.97 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Macquarie Park 132/11kV ZSMVA 54.7 56.1 59.6 60.7 62.6 62.1 62.8 64.7 Meadowbank 132/11kV ZSPF 0.94 0.94 0.98 0.98 0.98 0.98 0.98 0.98 Meadowbank 132/11kV ZSMVA - - - - - - - - North Ryde 66/11kV ZSPF - - - - - - - - North Ryde 66/11kV ZSMVA 42.3 38.4 39.9 40.2 42.6 42.7 43.1 43.7 Top Ryde 132/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Top Ryde 132/11kV ZS

Macquarie Park 132/11kV ZS

Meadowbank 132/11kV ZS

North Ryde 66/11kV ZS

Top Ryde 132/11kV ZS

Actual Load

Top Ryde 132/11kV ZS

Substation

Forecast Load

Epping 66/11kV ZS

Hunters Hill 66/11kV ZS

Meadowbank 132/11kV ZS

North Ryde 66/11kV ZS

Macquarie Park 132/11kV ZS

Substation

Forecast Load

Epping 66/11kV ZS

Hunters Hill 66/11kV ZS

Top Ryde 132/11kV ZS

Carlingford Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Epping 66/11kV ZS

Hunters Hill 66/11kV ZS

Macquarie Park 132/11kV ZS

Meadowbank 132/11kV ZS

North Ryde 66/11kV ZS

Page C3 of C27

Eastern Suburb

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

- - - - - - - - 0.0 0.0

- - - - 0.0 0.0 - - 0.0

81.6 82.3 53.1 53.1 18.4 14.6 6.3 - 1.0 0.0

505.1 505.1 312.6 312.6 - - 4.3 - 3.8 0.0

127.0 127.0 62.8 65.0 27.3 23.7 19.3 - 0.1 0.0

128.0 128.0 87.6 93.0 27.3 36.1 - 18.3 1.9 0.1

121.9 121.9 85.2 90.1 18.1 16.2 24.0 - 0.3 0.0

157.2 157.2 81.3 87.8 26.7 28.3 - 9.3 0.6 0.0

22.2 22.2 - - 0.0 0.0 1.3 - 0.0

18.7 20.8 - - 0.0 0.0 0.5 - 0.0

171.5 171.5 114.3 114.3 26.6 21.0 20.3 - 0.4 0.2

124.6 124.6 62.2 65.0 21.9 27.2 - 24.3 1.5 1.7

148.3 148.3 102.8 102.8 15.1 16.3 - 20.0 1.4 0.0

76.2 76.4 71.9 72.7 24.7 24.6 4.5 20.8 4.7 0.3

103.5 105.0 76.5 78.8 29.3 24.6 15.8 - 0.9 4.6

101.3 105.7 68.1 72.7 19.9 22.0 - 3.5 1.7 4.4

114.3 114.3 66.5 69.8 22.7 23.9 0.5 2.5 0.2 0.0

112.3 112.3 59.2 59.2 5.0 4.6 18.8 - 0.1 0.0

- - - - 0.0 0.0 - - 0.0

111.3 111.3 59.3 59.3 11.8 14.9 - 7.3 1.2 1.5

- - - - 0.0 0.0 0.0 0.0 0.0

152.4 152.7 87.5 87.5 30.0 25.3 10.3 - 2.3 0.0

466.4 466.4 346.7 346.7 - - 19.5 - 0.7 0.0

126.4 127.0 77.8 77.8 19.6 16.5 9.3 - 0.5 0.0

96.0 108.8 71.0 58.6 20.9 27.7 - 5.3 0.5 0.0

- - - - 0.0 0.0 - - 0.0

152.4 152.5 83.6 90.3 38.4 33.5 11.0 - 0.7 0.0

SUMMER - Eastern Suburbs Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA - - - - - - - - Alexandria 132/33kV STSPF - - - - - - - - Alexandria 132/33kV STSMVA - - - - - - - - Alexandria 33/5kV ZSPF - - - - - - - - Alexandria 33/5kV ZSMVA 27.2 23.1 26.0 24.1 24.6 25.0 25.3 25.6 Botany 33/11kV ZSPF 0.91 0.93 0.87 0.87 0.87 0.87 0.87 0.87 Botany 33/11kV ZSMVA 205.6 199.6 212.9 196.9 199.5 202.6 204.6 206.1 Bunnerong North 132/33kV STPF 0.99 1.00 0.99 0.99 0.99 0.99 0.99 0.99 Bunnerong North 132/33kV STMVA 38.4 37.1 40.5 39.3 38.7 38.4 38.6 39.3 Campbell St 132/11kV ZSPF 0.95 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Campbell St 132/11kV ZSMVA 51.6 53.1 54.9 53.3 53.8 54.5 55.5 56.7 Clovelly 132/11kV ZSPF 0.99 0.99 0.98 0.98 0.98 0.98 0.98 1.0 Clovelly 132/11kV ZSMVA 46.2 43.2 45.0 44.1 43.2 42.8 42.9 43.6 Darlinghurst 33/11kV ZSPF 0.98 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Darlinghurst 33/11kV ZSMVA 52.7 54.5 60.2 59.3 60.2 60.5 61.2 62.2 Double Bay 132/11kV ZSPF 0.95 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Double Bay 132/11kV ZSMVA 6.5 9.7 9.0 9.0 9.0 9.0 9.0 9.0 Graving Dock No 1 33/11kV ZPF 0.79 0.79 0.90 0.90 0.90 0.90 0.90 0.90 Graving Dock No 1 33/11kV ZMVA 7.2 9.8 9.0 9.0 9.0 9.0 9.0 9.0 Graving Dock No 2 33/11kV ZPF 1.0 1.0 0.9 0.9 0.9 0.9 0.90 0.90 Graving Dock No 2 33/11kV ZMVA 37.9 41.2 48.8 50.1 47.2 47.1 47.4 48.0 Green Square 132/11kV ZSPF 0.82 0.81 0.87 0.87 0.87 0.87 0.87 0.87 Green Square 132/11kV ZSMVA 37.9 40.8 43.8 40.6 40.7 41.0 41.7 42.7 Kingsford 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.9 Kingsford 132/11kV ZSMVA 45.0 45.1 45.5 45.5 44.2 43.5 43.6 44.4 Maroubra 132/11kV ZSPF 0.95 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Maroubra 132/11kV ZSMVA 45.3 47.2 51.0 54.4 54.4 54.3 54.5 55.0 Marrickville 132/11kV ZSPF 0.92 0.93 0.94 0.94 0.94 0.94 0.94 0.94 Marrickville 132/11kV ZSMVA 45.1 43.6 47.2 50.8 55.1 56.9 57.8 58.4 Mascot 33/11kV ZSPF 0.90 0.91 0.93 0.93 0.93 0.93 0.93 0.93 Mascot 33/11kV ZSMVA 36.7 36.0 39.7 36.1 37.0 37.8 38.6 39.4 Matraville 33/11kV ZSPF 0.9 0.9 1.0 1.0 1.0 1.0 0.95 0.95 Matraville 33/11kV ZSMVA 25.6 26.8 30.0 29.8 30.1 30.6 31.1 31.9 Paddington 33/11kV ZSPF 0.94 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Paddington 33/11kV ZSMVA 3.0 6.9 6.7 6.7 7.6 8.2 8.5 8.6 Port Botany 33/11kV ZSPF 0.88 0.89 0.87 0.87 0.87 0.87 0.87 0.9 Port Botany 33/11kV ZSMVA - - - - - - - - Randwick 33/11kV ZSPF - - - - - - - - Randwick 33/11kV ZSMVA - 27.7 32.5 33.4 33.7 34.1 34.7 35.3 Rose Bay 132/11kV ZSPF - 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Rose Bay 132/11kV ZSMVA 26.9 - - - - - - - Rose Bay 33/11kV ZSPF 0.92 - - - - - - - Rose Bay 33/11kV ZSMVA 62.2 59.9 62.6 68.3 70.1 69.9 70.3 71.3 St Peters 132/11kV ZSPF 0.9 0.8 0.8 0.8 0.8 0.8 0.77 0.77 St Peters 132/11kV ZSMVA 182.1 168.1 157.5 152.2 151.4 150.2 150.8 153.3 Surry Hills 132/33kV STSPF 1.00 0.99 1.00 1.00 1.00 1.00 1.00 1.00 Surry Hills 132/33kV STSMVA 42.0 43.7 47.1 43.5 44.3 43.6 43.6 44.5 Surry Hills 33/11kV ZSPF 0.94 0.93 0.93 0.93 0.93 0.93 0.93 0.9 Surry Hills 33/11kV ZSMVA - 20.5 21.9 22.4 23.4 24.3 24.9 25.4 Waverley 132/11kV ZSPF - 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Waverley 132/11kV ZSMVA 19.3 - - - - - - - Waverley 33/11kV ZSPF 0.94 - - - - - - - Waverley 33/11kV ZSMVA 61.9 59.6 64.0 61.6 68.3 69.2 70.2 71.4 Zetland 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 0.99 0.99 Zetland 132/11kV ZS

Zetland 132/11kV 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 132/33kV STS

Surry Hills 33/11kV ZS

Waverley 132/11kV ZS

Waverley 33/11kV ZS

Actual Load Forecast Load

Alexandria 132/33kV STS

Alexandria 33/5kV ZS

Mascot 33/11kV ZS

Bunnerong North 132/33kV STS

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

Botany 33/11kV ZS

Waverley 132/11kV ZS

Waverley 33/11kV ZS

Zetland 132/11kV ZS

Substation

Surry Hills 33/11kV 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 132/33kV STS

Kingsford 132/11kV ZS

Alexandria 132/33kV STS

Alexandria 33/5kV ZS

Botany 33/11kV ZS

Bunnerong North 132/33kV STS

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

Eastern Suburbs Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C4 of C27

WINTER - Eastern Suburbs Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA - - - - - - - - Alexandria 132/33kV STSPF - - - - - - - - Alexandria 132/33kV STSMVA - - - - - - - - Alexandria 33/5kV ZSPF - - - - - - - - Alexandria 33/5kV ZSMVA 27.5 21.5 20.7 21.1 21.1 21.2 21.4 21.8 Botany 33/11kV ZSPF 0.92 0.96 0.90 0.90 0.90 0.90 0.90 0.90 Botany 33/11kV ZSMVA 191.4 182.7 186.2 174.4 179.4 183.2 185.2 186.8 Bunnerong North 132/33kV STPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Bunnerong North 132/33kV STMVA 33.5 31.5 35.2 32.3 32.1 32.1 32.5 33.1 Campbell St 132/11kV ZSPF 0.96 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Campbell St 132/11kV ZSMVA 73.1 71.1 72.8 72.5 72.1 72.3 73.0 74.4 Clovelly 132/11kV ZSPF 0.99 0.99 1.00 1.00 1.00 1.00 1.00 1.00 Clovelly 132/11kV ZSMVA 38.6 36.7 40.2 36.2 36.1 35.8 36.0 36.7 Darlinghurst 33/11kV ZSPF 1.0 1.0 0.9 0.9 0.90 0.90 0.90 0.90 Darlinghurst 33/11kV ZSMVA 60.6 60.4 64.0 61.9 62.5 62.8 63.4 64.5 Double Bay 132/11kV ZSPF 0.98 0.98 0.98 0.98 0.98 1.0 1.0 1.0 Double Bay 132/11kV ZSMVA 6.6 6.1 8.0 8.0 8.0 8.0 8.0 8.0 Graving Dock No 1 33/11kV ZPF 0.82 0.82 0.90 0.90 0.90 0.90 0.90 0.90 Graving Dock No 1 33/11kV ZMVA 6.2 5.9 5.4 5.4 5.4 5.4 5.4 5.4 Graving Dock No 2 33/11kV ZPF 0.94 0.94 0.90 0.90 0.90 0.90 0.90 0.90 Graving Dock No 2 33/11kV ZMVA 29.9 30.9 38.6 38.2 40.0 38.2 38.5 39.2 Green Square 132/11kV ZSPF 0.81 0.80 0.87 0.87 0.88 0.88 0.88 0.88 Green Square 132/11kV ZSMVA 51.0 52.2 54.3 53.8 53.6 53.9 54.5 55.6 Kingsford 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Kingsford 132/11kV ZSMVA 44.7 - 48.9 47.1 46.0 45.3 45.4 46.3 Maroubra 132/11kV ZSPF 0.97 - 0.90 0.90 0.90 0.90 0.90 0.90 Maroubra 132/11kV ZSMVA 49.2 48.1 50.8 51.2 56.3 56.8 57.6 58.8 Marrickville 132/11kV ZSPF 0.98 0.98 0.97 0.97 0.97 1.0 1.0 1.0 Marrickville 132/11kV ZSMVA 39.3 37.6 39.7 40.5 47.4 50.4 51.5 52.1 Mascot 33/11kV ZSPF 0.92 0.94 0.95 0.95 0.95 0.95 0.95 0.95 Mascot 33/11kV ZSMVA 44.2 41.9 44.0 42.0 43.2 44.3 45.2 46.1 Matraville 33/11kV ZSPF 0.96 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Matraville 33/11kV ZSMVA 29.5 28.8 31.6 29.6 29.7 29.9 30.4 31.3 Paddington 33/11kV ZSPF 1.0 1.0 1.0 1.0 0.97 0.97 0.97 0.97 Paddington 33/11kV ZSMVA 2.5 5.3 6.1 7.7 8.4 8.9 9.2 9.2 Port Botany 33/11kV ZSPF 0.88 0.89 0.88 0.88 0.88 0.9 0.9 0.9 Port Botany 33/11kV ZSMVA - - - - - - - - Randwick 33/11kV ZSPF - - - - - - - - Randwick 33/11kV ZSMVA - - 41.1 39.9 40.2 39.8 39.9 40.7 Rose Bay 132/11kV ZSPF - - 0.90 0.90 0.90 0.90 0.90 0.90 Rose Bay 132/11kV ZSMVA 40.0 40.0 - - - - - - Rose Bay 33/11kV ZSPF 0.97 0.90 - - - - - - Rose Bay 33/11kV ZSMVA 54.9 50.4 52.7 51.5 59.8 59.8 60.5 61.7 St Peters 132/11kV ZSPF 0.96 0.98 0.76 0.77 0.77 0.77 0.77 0.77 St Peters 132/11kV ZSMVA 182.2 186.3 136.7 131.7 131.7 131.0 131.8 132.6 Surry Hills 132/33kV STSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 1.00 Surry Hills 132/33kV STSMVA 35.7 36.4 39.6 39.0 39.4 39.2 39.5 40.4 Surry Hills 33/11kV ZSPF 0.95 0.93 0.95 0.95 0.95 0.95 0.95 0.95 Surry Hills 33/11kV ZSMVA - - 29.0 28.6 29.3 30.0 30.6 31.1 Waverley 132/11kV ZSPF - - 0.90 0.90 0.90 0.9 0.9 0.9 Waverley 132/11kV ZSMVA 28.0 26.6 - - - - - - Waverley 33/11kV ZSPF 0.97 0.98 - - - - - - Waverley 33/11kV ZSMVA 54.0 54.7 55.9 54.8 59.5 63.4 64.8 66.1 Zetland 132/11kV ZSPF 0.99 0.98 0.99 1.00 1.00 1.00 1.00 1.00 Zetland 132/11kV ZS

Waverley 33/11kV ZS

Zetland 132/11kV ZS

Paddington 33/11kV ZS

Port Botany 33/11kV ZS

Randwick 33/11kV ZS

Surry Hills 132/33kV STS

Surry Hills 33/11kV ZS

Rose Bay 33/11kV ZS

St Peters 132/11kV ZS

Rose Bay 132/11kV ZS

Maroubra 132/11kV ZS

Marrickville 132/11kV ZS

Mascot 33/11kV ZS

Matraville 33/11kV ZS

Waverley 132/11kV ZS

Bunnerong North 132/33kV STS

Campbell St 132/11kV ZS

Clovelly 132/11kV ZS

Darlinghurst 33/11kV ZS

Kingsford 132/11kV ZS

Graving Dock No 1 33/11kV ZS

Graving Dock No 2 33/11kV ZS

Green Square 132/11kV ZS

Double Bay 132/11kV ZS

SubstationForecast Load

Alexandria 132/33kV STS

Alexandria 33/5kV ZS

Botany 33/11kV ZS

Page C5 of C27

Greater Cessno

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

31.0 31.0 22.9 22.9 11.7 9.3 6.5 - 2.1 0.0

104.2 104.2 57.3 57.3 7.3 4.9 2.3 - 2.8 0.0

223.4 243.0 156.2 162.0 - - 4.5 - 9.3 0.0

- - - - 0.0 0.0 - - 0.0

76.2 76.2 38.1 38.1 10.6 7.8 6.5 - 2.0 0.0

25.5 12.5 0.0 0.0 1.1 0.9 3.3 - 0.8 0.0

76.2 76.2 38.1 38.1 5.1 3.3 4.5 - 1.3 0.3

20.8 22.2 0.0 0.0 0.4 0.4 0.8 1.5 29.0

SUMMER - Greater Cessnock Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 18.5 20.0 19.9 21.8 21.9 22.0 22.2 22.4 Cessnock 33/11kV ZSPF 0.99 0.99 0.99 1.00 1.00 1.00 1.00 1.00 Cessnock 33/11kV ZSMVA 22.6 26.3 28.9 28.9 28.8 28.9 29.1 29.4 Kurri 132/11kV ZSPF 0.96 0.98 0.98 1.00 1.00 1.00 1.00 1.0 Kurri 132/11kV ZSMVA 107.8 116.6 117.4 128.9 129.7 130.7 131.8 133.1 Kurri 132/33kV STSPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Kurri 132/33kV STSMVA - - - - - - - - Kurri 33/11kV ZSPF - - - - - - - - Kurri 33/11kV ZSMVA 18.1 19.6 19.3 21.2 21.4 21.6 21.7 21.9 Nulkaba 33/11kV ZSPF 1.00 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Nulkaba 33/11kV ZSMVA 4.8 5.2 5.1 5.7 5.8 6.0 6.1 6.1 Paxton 33/11kV ZSPF 0.95 0.96 0.90 0.90 0.90 0.90 0.90 0.9 Paxton 33/11kV ZSMVA 9.8 9.3 9.2 10.2 10.0 9.8 9.8 10.0 Rothbury 132/11kV ZSPF 0.97 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Rothbury 132/11kV ZSMVA 1.6 1.7 0.4 0.4 0.4 0.4 0.4 0.4 Tomalpin 33/11kV ZSPF 1.00 0.99 1.00 1.00 1.00 1.00 1.00 1.00 Tomalpin 33/11kV ZS

WINTER - Greater Cessnock Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 14.6 13.8 15.8 14.9 14.8 14.8 15.0 15.3 Cessnock 33/11kV ZSPF 0.97 0.98 0.99 1.00 1.00 1.00 1.00 1.00 Cessnock 33/11kV ZSMVA 18.3 18.5 19.4 21.3 21.5 21.7 22.1 22.5 Kurri 132/11kV ZSPF 0.96 0.97 0.98 0.98 0.98 1.0 1.0 1.0 Kurri 132/11kV ZSMVA 86.1 85.2 87.3 90.3 91.8 92.8 94.1 95.8 Kurri 132/33kV STSPF 0.96 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Kurri 132/33kV STSMVA - - - - - - - - Kurri 33/11kV ZSPF - - - - - - - - Kurri 33/11kV ZSMVA 13.0 12.7 14.2 13.6 13.6 13.6 13.8 14.0 Nulkaba 33/11kV ZSPF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Nulkaba 33/11kV ZSMVA 3.8 3.8 4.2 4.2 4.2 4.2 4.3 4.4 Paxton 33/11kV ZSPF 0.98 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Paxton 33/11kV ZSMVA 5.4 5.6 6.1 6.3 6.2 6.3 6.5 6.7 Rothbury 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.00 1.00 1.00 1.00 Rothbury 132/11kV ZSMVA 1.4 1.3 0.4 0.0 0.0 0.0 0.0 0.0 Tomalpin 33/11kV ZSPF 1.00 1.00 1.00 1.00 0.43 0.4 0.7 0.9 Tomalpin 33/11kV ZS

Tomalpin 33/11kV ZS

SubstationForecast Load

Cessnock 33/11kV ZS

Kurri 132/11kV ZS

Kurri 132/33kV STS

Kurri 33/11kV ZS

Nulkaba 33/11kV ZS

Paxton 33/11kV ZS

Rothbury 132/11kV ZS

Actual Load Forecast Load

Cessnock 33/11kV ZS

Kurri 132/11kV ZS

Kurri 33/11kV ZS

Substation

Nulkaba 33/11kV ZS

Paxton 33/11kV ZS

Rothbury 132/11kV ZS

Tomalpin 33/11kV ZS

Kurri 132/33kV STS

Paxton 33/11kV ZS

Rothbury 132/11kV ZS

Tomalpin 33/11kV ZS

Greater Cessnock Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Cessnock 33/11kV ZS

Kurri 132/11kV ZS

Kurri 132/33kV STS

Kurri 33/11kV ZS

Nulkaba 33/11kV ZS

Page C6 of C27

Inner West

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

75.9 75.9 41.0 41.0 14.7 11.2 10.0 - 0.9 0.1

152.4 152.4 83.6 90.3 35.2 29.6 8.8 - 2.5 0.0

82.3 82.3 54.4 54.4 12.4 8.8 2.5 - 1.0 0.0

- - - - 0.0 0.0 - - 0.0

102.1 112.3 56.2 61.8 20.4 22.9 - 16.0 1.7 0.0

64.6 65.6 41.3 44.2 15.6 16.2 2.5 19.0 1.4 0.0

152.4 152.4 98.7 106.6 51.2 38.8 24.0 - 2.2 2.2

266.2 266.2 140.3 142.9 - - 9.5 - 3.9 0.0

106.7 115.1 53.2 57.4 31.8 25.5 2.8 - 1.6 0.1

- - - - 0.0 0.0 - - 0.0

114.3 114.3 65.8 69.1 10.6 11.3 - 11.5 1.6 0.0

54.1 55.2 33.4 33.4 14.3 10.9 11.3 - 0.9 2.0

- - - - 0.0 0.0 - - 0.0

40.0 45.0 0.0 0.0 - - - 4.8 0.0 0.0

129.5 137.2 68.6 68.6 - - 1.0 - 1.6 0.0

SUMMER - Inner West Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 25.7 26.1 28.1 26.7 26.4 26.2 26.2 26.5 Auburn 33/11kV ZSPF 0.91 0.91 0.90 0.90 0.90 0.90 0.90 0.90 Auburn 33/11kV ZSMVA 63.7 63.7 71.9 67.5 72.6 72.5 64.5 65.9 Burwood 132/11kV ZSPF 0.93 0.91 0.90 0.92 0.91 0.91 0.92 0.9 Burwood 132/11kV ZSMVA 37.4 35.7 42.6 39.4 40.8 41.8 42.7 43.3 Concord 33/11kV ZSPF 0.94 0.94 0.98 0.98 0.98 0.98 0.98 0.98 Concord 33/11kV ZSMVA - - - - 35.1 35.3 35.0 35.8 Croydon 132/11kV ZSPF - - - - 0.90 0.90 0.90 0.90 Croydon 132/11kV ZSMVA 43.9 40.6 51.5 46.5 46.3 46.5 47.2 48.3 Drummoyne 132/11kV ZSPF 0.93 0.93 0.97 0.97 0.97 0.97 0.97 0.97 Drummoyne 132/11kV ZSMVA 33.2 32.0 35.5 41.5 - - - - Five Dock 33/11kV ZSPF 0.94 0.93 0.91 0.91 - - - - Five Dock 33/11kV ZSMVA 78.4 80.9 82.2 81.5 83.0 83.9 84.2 85.4 Flemington 132/11kV ZSPF 0.93 0.93 0.94 0.94 0.94 0.94 0.94 0.94 Flemington 132/11kV ZSMVA 115.6 112.8 118.5 120.4 82.0 83.5 84.8 86.0 Homebush 132/33kV STSPF 0.90 0.90 0.97 1.00 1.00 1.00 1.00 1.00 Homebush 132/33kV STSMVA 43.1 46.3 48.9 48.8 53.4 56.2 55.5 56.1 Homebush Bay 132/11kV ZSPF 0.97 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Homebush Bay 132/11kV ZSMVA - - - - - 33.4 33.7 34.3 Leichhardt 132/11kV ZSPF - - - - - 0.9 0.92 0.92 Leichhardt 132/11kV ZSMVA 29.2 30.9 31.4 33.5 33.4 - - - Leichhardt 33/11kV ZSPF 0.93 0.92 0.92 0.92 0.92 - - - Leichhardt 33/11kV ZSMVA 18.9 18.8 21.2 21.5 22.0 22.5 22.9 23.3 Lidcombe 33/11kV ZSPF 0.91 0.91 0.90 0.90 0.90 0.90 0.90 0.9 Lidcombe 33/11kV ZSMVA - - - - - - - - Olympic Park 132/11kV ZSPF - - - - - - - - Olympic Park 132/11kV ZSMVA 12.5 10.0 10.9 8.8 - - - - Rozelle 132/33kV STSPF 0.90 0.90 0.90 0.89 - - - - Rozelle 132/33kV STSMVA 51.9 51.8 61.2 63.2 63.1 39.1 39.1 39.1 Strathfield 132/33kV STSPF 0.99 0.98 0.96 0.96 0.96 0.95 0.95 0.95 Strathfield 132/33kV STS

WINTER - Inner West Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 21.9 23.3 21.5 21.7 22.0 22.3 22.6 23.0 Auburn 33/11kV ZSPF 0.92 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Auburn 33/11kV ZSMVA 58.0 57.1 60.6 59.3 64.7 65.0 65.9 60.5 Burwood 132/11kV ZSPF 0.93 0.93 0.97 1.00 1.00 1.0 1.0 1.0 Burwood 132/11kV ZSMVA 30.5 28.6 30.2 30.5 31.8 33.0 33.9 34.5 Concord 33/11kV ZSPF 0.93 0.93 0.97 0.97 0.97 0.97 0.97 0.97 Concord 33/11kV ZSMVA - - - - - 38.8 39.3 39.5 Croydon 132/11kV ZSPF - - - - - 0.96 0.96 0.96 Croydon 132/11kV ZSMVA 56.0 53.7 57.8 58.5 58.8 59.2 60.0 61.3 Drummoyne 132/11kV ZSPF 0.95 0.95 0.98 0.98 0.98 0.98 0.98 0.98 Drummoyne 132/11kV ZSMVA 34.7 35.6 36.9 45.5 46.6 - - - Five Dock 33/11kV ZSPF 0.96 0.96 0.97 0.97 0.97 - - - Five Dock 33/11kV ZSMVA 62.7 62.4 62.4 62.9 65.0 66.1 67.2 67.5 Flemington 132/11kV ZSPF 0.9 0.9 0.9 0.9 0.95 0.95 0.95 0.95 Flemington 132/11kV ZSMVA 98.6 86.5 91.3 96.9 100.0 58.5 60.1 61.5 Homebush 132/33kV STSPF 0.90 1.00 0.99 0.99 0.99 1.0 1.0 1.0 Homebush 132/33kV STSMVA 36.2 36.8 39.2 38.0 42.2 44.8 44.7 45.1 Homebush Bay 132/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Homebush Bay 132/11kV ZSMVA - - - - - 39.5 40.0 40.7 Leichhardt 132/11kV ZSPF - - - - - 0.95 0.95 0.95 Leichhardt 132/11kV ZSMVA 38.3 38.3 33.6 39.4 39.3 - - - Leichhardt 33/11kV ZSPF 0.93 0.93 0.96 0.95 0.95 - - - Leichhardt 33/11kV ZSMVA 15.2 14.3 16.1 15.4 16.1 16.7 17.2 17.7 Lidcombe 33/11kV ZSPF 0.94 0.94 0.92 0.92 0.92 0.92 0.92 0.92 Lidcombe 33/11kV ZSMVA - - - - - - - - Olympic Park 132/11kV ZSPF - - - - - - - - Olympic Park 132/11kV ZSMVA 13.5 13.5 15.5 13.9 13.9 - - - Rozelle 132/33kV STSPF 0.90 0.90 0.90 0.90 0.90 - - - Rozelle 132/33kV STSMVA 55.5 56.5 50.2 55.5 55.4 29.9 29.9 29.9 Strathfield 132/33kV STSPF 0.99 0.99 0.96 0.96 0.96 0.96 0.96 0.96 Strathfield 132/33kV STS

Olympic Park 132/11kV ZS

Rozelle 132/33kV STS

Strathfield 132/33kV STS

Homebush 132/33kV STS

Substation

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

Forecast Load

Auburn 33/11kV ZS

Burwood 132/11kV ZS

Concord 33/11kV ZS

Croydon 132/11kV ZS

Actual Load Forecast Load

Auburn 33/11kV ZS

Burwood 132/11kV ZS

Strathfield 132/33kV STS

Croydon 132/11kV ZS

Drummoyne 132/11kV ZS

Five Dock 33/11kV ZS

Flemington 132/11kV ZS

Homebush 132/33kV STS

Homebush Bay 132/11kV ZS

Leichhardt 132/11kV ZS

Leichhardt 33/11kV ZS

Lidcombe 33/11kV ZS

Olympic Park 132/11kV ZS

Rozelle 132/33kV STS

Concord 33/11kV ZS

Substation

Olympic Park 132/11kV ZS

Rozelle 132/33kV STS

Strathfield 132/33kV STS

Lidcombe 33/11kV ZS

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 132/33kV STS

Homebush Bay 132/11kV ZS

Leichhardt 132/11kV ZS

Leichhardt 33/11kV ZS

Inner West Area - STS and ZS details

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)Embedded Generation

(MW)95% Peak Load Exceeded

(hrs/yr)

Page C7 of C27

Lower Central

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

105.1 108.1 59.8 63.7 19.9 20.6 0.8 3.8 3.3 1.1

117.6 117.6 59.9 63.3 10.9 7.7 2.8 - 2.7 0.0

- - - - 0.0 0.0 - - 0.0

76.2 76.2 38.1 38.1 11.4 10.2 2.5 - 1.4 0.0

81.1 83.4 49.3 49.3 16.4 11.7 4.0 - 1.8 0.0

71.4 71.5 0.1 0.1 - - 7.3 - 1.9 0.0

349.8 349.8 225.4 233.2 - - 3.8 - 10.3 0.0

61.0 61.1 30.5 30.5 9.7 8.6 7.5 - 1.9 0.0

- - - - 0.0 0.0 - - 0.0

114.3 114.3 71.7 76.2 10.2 10.2 3.5 16.3 3.5 0.0

21.7 22.3 21.7 22.3 - - 7.3 - 0.9 0.0

57.2 57.2 0.0 0.0 - - - 6.0 3.5 0.0

29.2 29.2 15.2 16.5 2.6 2.2 2.0 - 0.9 0.0

104.5 112.3 51.9 56.1 0.6 0.6 7.0 - 1.6 0.1

96.7 98.9 58.8 61.0 12.7 12.1 3.0 - 2.6 1.1

29.9 32.1 34.4 36.9 13.3 14.4 - 3.0 1.6 0.0

72.5 75.0 34.4 36.3 0.0 0.0 - 1.3 0.0

130.0 130.0 65.0 65.0 23.0 19.1 7.0 - 3.7 0.1

62.0 68.0 30.8 32.7 10.4 10.8 1.8 2.0 1.5 0.0

SUMMER - Lower Central Coast Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 29.1 30.9 34.8 30.0 29.9 29.9 30.3 30.9 Avoca 66/11kV ZSPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Avoca 66/11kV ZSMVA 38.6 40.6 49.7 45.3 45.1 45.0 45.4 45.8 Berkeley Vale 132/11kV ZSPF 0.91 0.91 0.96 0.96 0.96 0.96 0.96 1.0 Berkeley Vale 132/11kV ZSMVA - - - - - - - - Berkeley Vale 33/11kV ZSPF - - - - - - - - Berkeley Vale 33/11kV ZSMVA 4.7 6.7 11.5 11.8 11.8 11.8 11.9 12.0 Empire Bay 66/11kV ZSPF 0.90 0.97 0.97 0.96 0.96 0.96 0.96 0.96 Empire Bay 66/11kV ZSMVA 30.8 29.7 34.4 32.1 32.0 32.0 32.2 32.5 Erina 66/11kV ZSPF 0.96 0.96 0.96 0.99 0.99 0.99 0.99 0.99 Erina 66/11kV ZSMVA 19.8 19.6 23.3 21.7 21.7 21.8 22.0 22.4 Gosford 132/33kV STSPF 0.97 0.96 0.96 0.95 0.95 0.95 0.95 0.9 Gosford 132/33kV STSMVA 107.6 105.0 128.8 111.8 111.5 111.8 112.8 114.4 Gosford 132/66kV STSPF 0.98 0.96 0.96 1.00 1.00 1.00 1.00 1.00 Gosford 132/66kV STSMVA 19.9 19.5 23.2 21.1 21.1 21.2 21.4 21.8 Lisarow 33/11kV ZSPF 0.98 0.96 0.97 1.00 1.00 1.00 1.00 1.00 Lisarow 33/11kV ZSMVA - - - - - - - - Long Jetty 33/11kV ZSPF - - - - - - - - Long Jetty 33/11kV ZSMVA 33.9 36.0 39.8 35.4 35.4 35.7 36.2 37.1 Long Jetty 66/11kV ZSPF 0.9 0.9 0.9 0.9 0.9 0.9 0.90 0.90 Long Jetty 66/11kV ZSMVA 13.4 13.1 16.4 17.5 17.1 16.8 16.7 16.8 Ourimbah 132/33kV STSPF 0.88 0.95 0.88 0.88 0.88 0.88 0.88 0.88 Ourimbah 132/33kV STSMVA 38.8 44.1 46.3 41.4 41.4 41.7 42.2 43.0 Ourimbah 132/66kV STSPF 0.97 0.96 0.96 0.94 0.94 0.94 0.95 0.9 Ourimbah 132/66kV STSMVA 9.8 11.2 12.2 11.4 11.0 10.8 10.7 10.7 Peats Ridge 33/11kV ZSPF 0.96 0.96 0.87 0.87 0.87 0.87 0.87 0.87 Peats Ridge 33/11kV ZSMVA 15.8 16.2 17.8 17.1 17.7 17.7 17.7 17.8 Somersby 132/11kV ZSPF 0.91 0.92 0.94 0.94 0.94 0.94 0.94 0.94 Somersby 132/11kV ZSMVA 26.4 26.6 30.6 27.5 27.6 27.7 28.0 28.4 Umina 66/11kV ZSPF 0.88 0.91 0.92 0.92 0.92 0.92 0.92 0.92 Umina 66/11kV ZSMVA 9.5 10.9 13.3 11.2 11.3 11.5 11.7 12.0 Wamberal 132/11kV ZSPF 0.9 0.9 0.9 0.9 0.9 0.9 0.90 0.90 Wamberal 132/11kV ZSMVA - - - - - - - - Wamberal 66/11kV ZSPF - - - - - - - - Wamberal 66/11kV ZSMVA 47.5 47.3 52.5 46.0 46.1 46.2 46.5 47.1 West Gosford 132/11kV ZSPF 0.90 0.90 0.90 0.97 0.97 0.97 0.97 1.0 West Gosford 132/11kV ZSMVA 18.8 16.6 18.2 16.5 16.5 16.5 16.7 16.9 Woy Woy 66/11kV ZSPF 0.92 0.91 0.95 0.95 0.95 0.95 0.95 0.95 Woy Woy 66/11kV ZS

Wamberal 132/11kV ZS

Wamberal 66/11kV ZS

West Gosford 132/11kV ZS

Woy Woy 66/11kV ZS

Actual LoadSubstation

Berkeley Vale 132/11kV ZS

Umina 66/11kV ZS

Empire Bay 66/11kV ZS

Erina 66/11kV ZS

Gosford 132/33kV STS

Gosford 132/66kV STS

Lisarow 33/11kV ZS

Long Jetty 33/11kV ZS

Long Jetty 66/11kV ZS

Ourimbah 132/33kV STS

Peats Ridge 33/11kV ZS

Somersby 132/11kV ZS

Berkeley Vale 33/11kV ZS

Umina 66/11kV ZS

Wamberal 132/11kV ZS

Wamberal 66/11kV ZS

Avoca 66/11kV ZS

West Gosford 132/11kV ZS

Woy Woy 66/11kV ZS

Ourimbah 132/66kV STS

Berkeley Vale 132/11kV ZS

Berkeley Vale 33/11kV ZS

Empire Bay 66/11kV ZS

Erina 66/11kV ZS

Lower Central Coast Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Avoca 66/11kV ZS

Forecast Load

Ourimbah 132/33kV STS

Peats Ridge 33/11kV ZS

Somersby 132/11kV ZS

Gosford 132/33kV STS

Gosford 132/66kV STS

Lisarow 33/11kV ZS

Long Jetty 33/11kV ZS

Long Jetty 66/11kV ZS

Ourimbah 132/66kV STS

Page C8 of C27

WINTER - Lower Central Coast Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 34.4 34.7 36.0 37.4 37.0 37.1 37.6 38.3 Avoca 66/11kV ZSPF 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Avoca 66/11kV ZSMVA 35.2 32.6 35.4 39.4 39.6 40.0 40.5 41.1 Berkeley Vale 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.9 0.9 0.9 Berkeley Vale 132/11kV ZSMVA - - - - - - - - Berkeley Vale 33/11kV ZSPF - - - - - - - - Berkeley Vale 33/11kV ZSMVA 5.8 5.3 10.3 10.5 12.3 12.3 12.4 12.6 Empire Bay 66/11kV ZSPF 0.90 0.99 0.98 0.98 0.98 0.98 0.98 0.98 Empire Bay 66/11kV ZSMVA 23.1 22.5 24.4 25.6 26.0 26.5 26.9 27.4 Erina 66/11kV ZSPF 0.98 0.99 0.99 1.00 1.00 1.00 1.00 1.00 Erina 66/11kV ZSMVA 19.6 19.1 20.3 20.8 20.9 21.2 21.4 21.8 Gosford 132/33kV STSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Gosford 132/33kV STSMVA 115.1 108.0 114.1 119.2 120.1 121.4 123.1 125.1 Gosford 132/66kV STSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 Gosford 132/66kV STSMVA 20.0 19.2 20.6 21.1 21.2 21.5 21.8 22.1 Lisarow 33/11kV ZSPF 0.98 0.98 0.98 1.00 1.00 1.0 1.0 1.0 Lisarow 33/11kV ZSMVA - - - - - - - - Long Jetty 33/11kV ZSPF - - - - - - - - Long Jetty 33/11kV ZSMVA 38.0 39.4 39.7 43.9 44.3 45.0 45.9 47.0 Long Jetty 66/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Long Jetty 66/11kV ZSMVA 11.4 11.9 12.0 11.5 11.3 11.2 11.3 11.4 Ourimbah 132/33kV STSPF 0.97 0.97 0.93 0.93 0.93 0.93 0.93 0.93 Ourimbah 132/33kV STSMVA 45.9 46.5 48.5 51.2 51.6 52.3 53.2 54.2 Ourimbah 132/66kV STSPF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Ourimbah 132/66kV STSMVA 9.3 9.2 10.4 9.7 9.5 9.4 9.4 9.6 Peats Ridge 33/11kV ZSPF 0.91 0.88 0.89 0.89 0.89 0.89 0.89 0.89 Peats Ridge 33/11kV ZSMVA 16.7 15.5 16.8 16.0 15.7 16.0 16.0 16.2 Somersby 132/11kV ZSPF 0.93 0.95 0.99 0.99 0.99 1.0 1.0 1.0 Somersby 132/11kV ZSMVA 25.2 25.5 28.9 29.5 28.7 29.3 29.8 30.3 Umina 66/11kV ZSPF 0.94 0.94 0.96 0.96 0.96 0.96 0.96 0.96 Umina 66/11kV ZSMVA 13.3 13.3 14.4 14.9 14.9 14.9 15.2 15.5 Wamberal 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Wamberal 132/11kV ZSMVA - - - 0.0 0.0 0.0 0.0 0.0 Wamberal 66/11kV ZSPF - - - 0.9 0.90 0.90 0.90 0.90 Wamberal 66/11kV ZSMVA 38.1 37.0 43.5 38.9 39.5 40.1 40.8 41.7 West Gosford 132/11kV ZSPF 0.95 0.90 0.95 1.00 1.00 1.0 1.0 1.0 West Gosford 132/11kV ZSMVA 21.0 18.7 18.8 16.2 16.1 16.2 16.4 16.8 Woy Woy 66/11kV ZSPF 0.97 0.97 0.96 0.96 0.96 0.96 0.96 0.96 Woy Woy 66/11kV ZS

Long Jetty 33/11kV ZS

Long Jetty 66/11kV ZS

Ourimbah 132/33kV STS

Ourimbah 132/66kV STS

Peats Ridge 33/11kV ZS

Woy Woy 66/11kV ZS

Lisarow 33/11kV ZS

SubstationForecast Load

Avoca 66/11kV ZS

Berkeley Vale 132/11kV ZS

Berkeley Vale 33/11kV ZS

Empire Bay 66/11kV ZS

Erina 66/11kV ZS

Gosford 132/33kV STS

Gosford 132/66kV STS

Somersby 132/11kV ZS

Umina 66/11kV ZS

Wamberal 132/11kV ZS

Wamberal 66/11kV ZS

West Gosford 132/11kV ZS

Page C9 of C27

Lower North Sh

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

152.4 152.4 90.7 96.3 32.4 27.1 12.3 - 2.0 0.0

121.9 122.1 67.1 70.5 29.2 29.7 6.0 8.3 2.0 3.7

- - - - 0.0 0.0 - - 0.7 0.0

93.2 94.6 60.0 60.0 23.8 23.3 16.0 4.8 0.0

151.3 151.3 96.9 96.9 19.7 16.9 4.8 - 0.7 0.0

152.4 152.6 82.5 89.1 20.7 24.9 - 28.8 2.1 0.2

171.5 - 114.3 - 15.8 0.0 16.8 - 0.2 0.0

- 152.7 - 119.7 0.0 41.0 - 8.8 0.1 3.4

97.3 97.3 53.5 53.5 6.7 5.3 5.8 - 0.0 4.0

453.2 453.2 313.6 313.6 - - - 8.0 2.5 0.0

SUMMER - Lower North Shore Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 60.8 60.0 66.5 61.9 59.6 58.3 58.2 59.0 Castle Cove 132/11kV ZSPF 0.98 0.89 0.87 0.91 0.92 0.92 0.92 0.92 Castle Cove 132/11kV ZSMVA 37.8 36.8 42.0 40.4 39.1 38.5 38.6 39.4 Chatswood 33/11kV ZSPF 0.92 0.92 0.92 0.92 0.92 0.92 0.92 0.9 Chatswood 33/11kV ZSMVA - - - 37.5 37.3 37.4 37.8 38.4 Crows Nest 132/11kV ZSPF - - - 0.83 0.83 0.83 0.83 0.83 Crows Nest 132/11kV ZSMVA 33.8 33.5 36.6 - - - - - Crows Nest 33/11kV ZSPF 0.82 0.82 0.83 - - - - - Crows Nest 33/11kV ZSMVA 58.4 58.0 61.1 59.0 58.7 58.6 59.0 59.8 Gore Hill 33/11kV ZSPF 0.93 0.92 0.95 0.95 0.95 0.95 0.95 0.95 Gore Hill 33/11kV ZSMVA 52.4 51.2 63.4 56.5 57.0 57.8 58.9 60.2 Mosman 132/11kV ZSPF 0.98 0.98 0.98 1.00 1.00 1.00 1.00 1.0 Mosman 132/11kV ZSMVA - - 50.3 68.2 66.0 64.8 64.7 65.7 North Sydney 132/11kV ZSPF - - 0.90 0.89 0.89 0.89 0.89 0.89 North Sydney 132/11kV ZSMVA 69.6 68.1 - - - - - - North Sydney 33/11kV ZSPF 0.93 0.93 - - - - - - North Sydney 33/11kV ZSMVA 11.3 11.3 12.1 12.0 12.0 12.0 12.0 12.1 RNS Hospital 132/11kV ZSPF 0.84 0.85 0.85 0.85 0.85 0.85 0.85 0.85 RNS Hospital 132/11kV ZSMVA 206.4 206.5 175.6 110.1 108.6 108.1 108.5 110.0 Willoughby 132/33kV STSPF 1.0 1.0 1.0 1.0 1.0 1.0 0.97 0.97 Willoughby 132/33kV STS

WINTER - Lower North Shore Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 54.5 53.4 55.7 52.6 52.3 52.5 53.1 54.0 Castle Cove 132/11kV ZSPF 0.83 0.79 0.79 0.87 0.87 0.87 0.87 0.87 Castle Cove 132/11kV ZSMVA 44.1 39.6 42.8 44.0 43.9 44.1 44.7 45.6 Chatswood 33/11kV ZSPF 0.90 0.90 0.95 0.95 0.95 0.9 0.9 0.9 Chatswood 33/11kV ZSMVA - - - - 39.0 39.2 39.7 40.4 Crows Nest 132/11kV ZSPF - - - - 0.83 0.83 0.83 0.83 Crows Nest 132/11kV ZSMVA 35.0 34.6 35.7 40.0 - - - - Crows Nest 33/11kV ZSPF 0.83 0.83 0.83 0.83 - - - - Crows Nest 33/11kV ZSMVA 55.5 51.4 52.4 49.8 48.0 47.0 46.9 47.6 Gore Hill 33/11kV ZSPF 0.89 0.89 0.93 0.93 0.93 0.93 0.93 0.93 Gore Hill 33/11kV ZSMVA 75.4 75.9 76.1 78.6 77.2 76.9 77.5 79.1 Mosman 132/11kV ZSPF 0.99 0.99 0.99 1.00 1.00 1.00 1.00 1.00 Mosman 132/11kV ZSMVA - - - 56.5 56.3 56.4 56.9 57.8 North Sydney 132/11kV ZSPF - - - 1.0 0.98 0.98 0.98 0.98 North Sydney 132/11kV ZSMVA 61.4 58.1 61.2 - - - - - North Sydney 33/11kV ZSPF 0.96 0.98 0.98 - - - - - North Sydney 33/11kV ZSMVA 9.4 9.5 9.5 9.5 9.5 9.5 9.5 9.6 RNS Hospital 132/11kV ZSPF 0.85 0.85 0.85 0.85 0.85 0.85 0.85 0.85 RNS Hospital 132/11kV ZSMVA 203.6 183.0 200.0 142.4 102.2 101.5 101.8 103.3 Willoughby 132/33kV STSPF 0.95 0.99 0.99 0.98 0.98 0.98 0.98 0.98 Willoughby 132/33kV STS

Lower North Shore Area - STS and ZS details

Embedded Generation (MW)

Castle Cove 132/11kV ZS

Chatswood 33/11kV ZS

Crows Nest 132/11kV ZS

95% Peak Load Exceeded (hrs/yr)

Crows Nest 33/11kV ZS

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)

RNS Hospital 132/11kV ZS

Willoughby 132/33kV STS

Gore Hill 33/11kV ZS

Mosman 132/11kV ZS

North Sydney 132/11kV ZS

North Sydney 33/11kV ZS

Forecast Load

Castle Cove 132/11kV ZS

Chatswood 33/11kV ZS

Crows Nest 132/11kV ZS

SubstationActual Load

North Sydney 33/11kV ZS

RNS Hospital 132/11kV ZS

Willoughby 132/33kV STS

Crows Nest 33/11kV ZS

Gore Hill 33/11kV ZS

Mosman 132/11kV ZS

North Sydney 132/11kV ZS

Forecast Load

Castle Cove 132/11kV ZS

Chatswood 33/11kV ZS

Crows Nest 132/11kV ZS

Crows Nest 33/11kV ZS

Substation

RNS Hospital 132/11kV ZS

Willoughby 132/33kV STS

Gore Hill 33/11kV ZS

Mosman 132/11kV ZS

North Sydney 132/11kV ZS

North Sydney 33/11kV ZS

Page C10 of C27

Maitland

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

228.6 228.6 114.3 114.3 - - 3.5 - 7.1 0.0

76.2 76.2 38.1 38.1 6.5 4.2 2.0 - 1.2 0.0

45.7 45.7 30.5 30.5 0.0 0.0 - 3.0 0.0

74.3 74.3 38.1 38.1 14.3 8.8 6.5 - 1.6 0.0

- - - - 0.0 0.0 - - 0.0

76.0 - 38.0 - 0.0 0.0 2.3 - 2.7 0.0

76.2 76.2 38.1 38.1 16.4 12.9 5.5 - 2.6 0.0

37.7 37.7 18.9 18.9 9.3 7.8 16.5 - 1.5 0.0

28.9 30.5 15.2 15.2 4.0 3.5 3.0 - 0.8 0.0

99.0 99.0 54.5 54.5 11.3 8.4 6.5 - 3.2 0.0

- 6.3 - 0.0 0.0 0.0 - 0.0 0.0

SUMMER - Maitland Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 87.3 86.5 88.3 84.1 83.5 83.3 83.7 84.7 Beresfield 132/33kV STSPF 0.94 1.00 0.95 1.00 1.00 1.00 1.00 1.00 Beresfield 132/33kV STSMVA 2.3 8.3 8.7 8.8 8.8 8.9 9.0 9.2 Brandy Hill 132/11kV ZSPF 0.98 0.90 0.90 0.90 0.90 0.90 0.90 0.9 Brandy Hill 132/11kV ZSMVA 26.0 27.6 - - - - - - East Maitland 33/11kV ZSPF 1.00 0.98 - - - - - - East Maitland 33/11kV ZSMVA 21.9 22.9 25.7 26.3 26.6 26.9 27.2 27.5 Maitland 33/11kV ZSPF 0.93 0.93 0.95 0.95 0.95 0.95 0.95 0.95 Maitland 33/11kV ZSMVA - - - - - - - - Maitland Central 33/11kV ZSPF - - - - - - - - Maitland Central 33/11kV ZSMVA - - 34.0 34.7 34.5 34.5 34.6 34.9 Metford 33/11kV ZSPF - - 0.90 0.90 0.90 0.90 0.90 0.9 Metford 33/11kV ZSMVA 24.1 25.5 28.1 28.9 28.9 29.0 29.1 29.4 Rutherford 33/11kV ZSPF 0.98 0.98 0.98 1.00 1.00 1.00 1.00 1.00 Rutherford 33/11kV ZSMVA 20.3 20.4 21.6 21.6 21.3 21.2 21.3 21.5 Tarro 33/11kV ZSPF 0.91 0.93 0.93 0.93 0.93 0.93 0.93 0.93 Tarro 33/11kV ZSMVA 12.1 13.7 12.6 13.2 13.3 13.5 13.7 14.0 Telarah 33/11kV ZSPF 0.95 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Telarah 33/11kV ZSMVA 29.2 30.7 30.5 31.5 31.3 31.3 31.5 32.0 Thornton 33/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 0.99 0.99 Thornton 33/11kV ZSMVA 4.0 - - - - - - - Wallalong 33/11kV ZSPF 0.90 - - - - - - - Wallalong 33/11kV ZS

WINTER - Maitland Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 73.2 64.9 81.0 66.3 65.8 65.6 66.1 67.4 Beresfield 132/33kV STSPF 0.96 0.97 0.94 0.94 0.94 0.94 0.94 0.94 Beresfield 132/33kV STSMVA 1.9 4.8 5.6 5.7 5.7 5.8 6.0 6.3 Brandy Hill 132/11kV ZSPF 0.96 0.90 0.90 0.90 0.90 0.9 0.9 0.9 Brandy Hill 132/11kV ZSMVA 18.5 18.5 20.5 - - - - - East Maitland 33/11kV ZSPF 0.99 1.00 1.00 - - - - - East Maitland 33/11kV ZSMVA - 14.4 15.8 15.9 16.2 16.6 16.9 17.3 Maitland 33/11kV ZSPF - 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Maitland 33/11kV ZSMVA 11.8 - - - - - - - Maitland Central 33/11kV ZSPF 0.96 - - - - - - - Maitland Central 33/11kV ZSMVA - - - 21.3 21.0 21.0 21.2 21.6 Metford 33/11kV ZSPF - - - 0.99 0.99 0.99 0.99 0.99 Metford 33/11kV ZSMVA 20.3 20.2 22.1 21.4 22.6 22.9 23.3 23.8 Rutherford 33/11kV ZSPF 0.9 1.0 1.0 1.0 1.00 1.00 1.00 1.00 Rutherford 33/11kV ZSMVA 18.3 16.0 18.2 17.2 17.4 17.4 17.5 17.9 Tarro 33/11kV ZSPF 0.93 0.94 0.94 0.94 0.94 0.9 0.9 0.9 Tarro 33/11kV ZSMVA 10.4 9.1 11.1 8.5 8.6 8.8 9.1 9.4 Telarah 33/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Telarah 33/11kV ZSMVA 19.4 20.6 22.7 19.9 19.4 19.2 19.5 20.2 Thornton 33/11kV ZSPF 0.96 0.98 0.94 0.99 0.99 0.99 0.99 0.99 Thornton 33/11kV ZSMVA 3.4 3.2 1.9 - - - - - Wallalong 33/11kV ZSPF 0.90 0.90 0.90 - - - - - Wallalong 33/11kV ZS

Thornton 33/11kV ZS

Wallalong 33/11kV ZS

Tarro 33/11kV ZS

Substation

Maitland Central 33/11kV ZS

Metford 33/11kV ZS

Rutherford 33/11kV ZS

Beresfield 132/33kV STS

Brandy Hill 132/11kV ZS

East Maitland 33/11kV ZS

Maitland 33/11kV ZS

Telarah 33/11kV ZS

Brandy Hill 132/11kV ZS

Maitland 33/11kV ZS

Forecast Load

Metford 33/11kV ZS

Rutherford 33/11kV ZS

Tarro 33/11kV ZS

Telarah 33/11kV ZS

Thornton 33/11kV ZS

Wallalong 33/11kV ZS

East Maitland 33/11kV ZS

Maitland Central 33/11kV ZS

East Maitland 33/11kV ZS

Maitland 33/11kV ZS

Maitland Central 33/11kV ZS

Forecast Load

Beresfield 132/33kV STS

Actual LoadSubstation

Wallalong 33/11kV ZS

Metford 33/11kV ZS

Rutherford 33/11kV ZS

Tarro 33/11kV ZS

Telarah 33/11kV ZS

Thornton 33/11kV ZS

Beresfield 132/33kV STS

Brandy Hill 132/11kV ZS

Maitland Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C11 of C27

Manly Warringa

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

- - - - 0.0 0.0 - - 0.0

76.5 76.5 43.9 43.9 6.8 8.6 - 7.8 2.0 0.1

54.1 54.1 26.7 26.7 17.7 17.8 5.3 6.0 1.1 0.0

70.5 70.5 40.3 44.3 12.9 13.3 0.8 6.0 2.6 0.0

87.6 87.6 54.3 54.3 18.6 17.7 17.3 0.5 0.9 0.0

90.2 90.4 53.5 58.8 17.2 21.4 - 7.5 2.4 0.0

73.7 75.1 37.3 37.5 15.8 23.0 - 13.3 1.6 0.0

21.1 21.1 21.1 21.1 9.0 9.2 1.8 5.5 1.2 0.0

45.7 45.7 22.9 22.9 16.0 20.7 - 5.0 0.4 0.0

43.0 43.0 23.6 23.6 3.8 3.1 2.8 - 0.1 4.8

273.7 301.1 217.4 229.8 - - 0.3 22.8 8.3 0.0

SUMMER - Manly Warringah Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA - - - - - - - - Balgowlah 33/11kV ZSPF - - - - - - - - Balgowlah 33/11kV ZSMVA 22.3 22.0 26.7 24.7 24.8 25.1 25.6 26.2 Balgowlah North 132/11kV ZSPF 0.98 0.90 0.99 0.99 0.99 0.99 0.99 1.0 Balgowlah North 132/11kV ZSMVA 18.8 19.5 21.4 18.8 18.7 18.7 18.8 19.0 Beacon Hill 33/11kV ZSPF 0.87 0.87 0.94 0.94 0.94 0.94 0.94 0.94 Beacon Hill 33/11kV ZSMVA 23.0 21.2 26.4 24.3 24.2 24.3 24.6 25.0 Belrose 33/11kV ZSPF 0.91 0.91 0.97 0.97 0.97 0.97 0.97 0.97 Belrose 33/11kV ZSMVA 39.8 38.8 41.1 37.3 36.9 36.7 36.9 37.3 Brookvale 33/11kV ZSPF 0.87 0.86 0.97 0.99 0.99 0.99 0.99 0.99 Brookvale 33/11kV ZSMVA 27.2 29.6 33.6 33.5 34.5 35.4 36.2 37.0 Dee Why West 33/11kV ZSPF 0.93 0.93 0.93 0.93 0.93 0.93 0.93 0.9 Dee Why West 33/11kV ZSMVA 13.9 14.5 15.8 14.7 14.7 14.8 15.1 15.6 Harbord 33/11kV ZSPF 0.92 0.92 0.92 0.92 0.92 0.92 0.92 0.92 Harbord 33/11kV ZSMVA 11.8 10.6 14.1 12.5 12.3 12.2 12.3 12.6 Killarney 33/11kV ZSPF 0.90 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Killarney 33/11kV ZSMVA 16.0 15.1 16.0 15.5 15.2 15.1 15.2 15.5 Manly 33/11kV ZSPF 0.91 0.91 0.91 0.91 0.91 0.91 0.91 0.91 Manly 33/11kV ZSMVA 21.2 19.5 20.3 20.3 20.2 20.2 20.3 20.5 North Head 33/11kV ZSPF 0.9 0.9 0.9 0.9 0.9 0.9 0.92 0.92 North Head 33/11kV ZSMVA 142.8 132.6 164.5 140.5 140.7 141.6 143.4 145.8 Warringah 132/33kV STSPF 0.98 0.98 0.98 1.00 1.00 1.00 1.00 1.00 Warringah 132/33kV STS

WINTER - Manly Warringah Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA - - - - - - - - Balgowlah 33/11kV ZSPF - - - - - - - - Balgowlah 33/11kV ZSMVA 31.5 31.3 33.8 34.0 33.9 34.1 34.6 35.3 Balgowlah North 132/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 1.0 1.0 1.0 Balgowlah North 132/11kV ZSMVA 19.8 19.5 21.5 19.1 18.7 18.5 18.6 18.9 Beacon Hill 33/11kV ZSPF 0.93 0.90 0.96 1.00 1.00 1.00 1.00 1.00 Beacon Hill 33/11kV ZSMVA 26.9 25.4 27.1 27.5 26.4 26.4 26.7 27.2 Belrose 33/11kV ZSPF 0.94 0.94 0.96 0.96 0.96 0.96 0.96 0.96 Belrose 33/11kV ZSMVA 35.7 34.8 39.1 32.8 35.7 36.3 36.8 37.4 Brookvale 33/11kV ZSPF 0.89 0.86 0.98 1.00 1.00 1.00 0.99 0.99 Brookvale 33/11kV ZSMVA 39.9 39.8 41.9 41.6 41.2 41.1 41.5 42.3 Dee Why West 33/11kV ZSPF 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Dee Why West 33/11kV ZSMVA 24.1 21.7 23.0 24.0 24.1 24.3 24.7 25.2 Harbord 33/11kV ZSPF 1.0 1.0 1.0 1.0 0.96 0.96 0.96 0.96 Harbord 33/11kV ZSMVA 13.0 13.2 14.4 13.9 13.9 14.0 14.2 14.5 Killarney 33/11kV ZSPF 0.96 0.96 0.98 0.98 0.98 1.0 1.0 1.0 Killarney 33/11kV ZSMVA 20.6 19.6 20.7 19.6 19.2 19.1 19.2 19.5 Manly 33/11kV ZSPF 0.95 0.96 0.95 0.95 0.95 0.95 0.95 0.95 Manly 33/11kV ZSMVA 21.5 20.9 16.4 16.4 16.3 16.4 16.4 16.6 North Head 33/11kV ZSPF 0.87 0.87 0.93 0.93 0.93 0.93 0.93 0.93 North Head 33/11kV ZSMVA 170.2 170.8 187.2 173.5 173.8 174.3 175.9 178.8 Warringah 132/33kV STSPF 0.99 0.99 0.90 0.99 0.99 0.99 0.99 0.99 Warringah 132/33kV STS

North Head 33/11kV ZS

Warringah 132/33kV STS

Killarney 33/11kV ZS

Substation

Brookvale 33/11kV ZS

Dee Why West 33/11kV ZS

Harbord 33/11kV ZS

Balgowlah 33/11kV ZS

Balgowlah North 132/11kV ZS

Beacon Hill 33/11kV ZS

Belrose 33/11kV ZS

Manly 33/11kV ZS

Balgowlah North 132/11kV ZS

Belrose 33/11kV ZS

Forecast Load

Dee Why West 33/11kV ZS

Harbord 33/11kV ZS

Killarney 33/11kV ZS

Manly 33/11kV ZS

North Head 33/11kV ZS

Warringah 132/33kV STS

Beacon Hill 33/11kV ZS

Brookvale 33/11kV ZS

Beacon Hill 33/11kV ZS

Belrose 33/11kV ZS

Brookvale 33/11kV ZS

Forecast Load

Balgowlah 33/11kV ZS

Actual LoadSubstation

Warringah 132/33kV STS

Dee Why West 33/11kV ZS

Harbord 33/11kV ZS

Killarney 33/11kV ZS

Manly 33/11kV ZS

North Head 33/11kV ZS

Balgowlah 33/11kV ZS

Balgowlah North 132/11kV ZS

Manly Warringah Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C12 of C27

Newcastle Inne

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

125.2 130.0 63.0 65.0 14.6 13.8 7.5 - 2.3 0.0

- - - - 0.0 0.0 - - 0.0

109.4 109.4 59.5 59.5 19.1 6.6 3.8 - 2.0 0.0

- 45.7 - 22.9 0.0 0.0 - 5.5 0.0

61.0 61.0 30.5 30.5 15.1 13.8 5.0 - 1.4 0.0

30.5 30.5 30.5 30.5 16.9 11.7 6.3 - 1.4 0.0

44.4 45.7 22.9 22.9 15.1 11.7 6.5 - 0.9 0.0

112.8 113.7 76.2 76.2 23.1 17.3 4.3 - 1.8 0.5

- - 35.5 - 0.0 0.0 - - 0.0

- - - - 0.0 0.0 - - 0.0

SUMMER - Newcastle Inner City Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 25.6 22.8 25.6 21.3 21.3 21.4 21.6 22.0 Adamstown 132/11kV ZSPF 0.93 0.90 0.90 1.00 1.00 1.00 1.00 1.00 Adamstown 132/11kV ZSMVA 0.2 - - - - - - - Adamstown 33/11kV ZSPF 0.90 - - - - - - - Adamstown 33/11kV ZSMVA - 11.4 29.9 26.5 26.2 26.1 26.0 26.1 Broadmeadow 132/11kV ZSPF - 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Broadmeadow 132/11kV ZSMVA 18.5 10.5 - - - - - - Broadmeadow 33/11kV ZSPF 0.92 0.96 - - - - - - Broadmeadow 33/11kV ZSMVA 22.5 21.1 22.6 22.6 - - - - Carrington 33/11kV ZSPF 0.92 0.93 0.94 0.94 - - - - Carrington 33/11kV ZSMVA 22.0 22.3 25.3 21.9 21.4 21.2 21.2 21.4 Kotara 33/11kV ZSPF 0.95 0.95 0.96 0.96 0.96 0.96 0.96 1.0 Kotara 33/11kV ZSMVA 19.1 18.2 18.5 15.4 16.5 16.4 16.5 16.7 New Lambton 33/11kV ZSPF 0.96 0.97 0.97 0.97 0.97 0.97 0.97 0.97 New Lambton 33/11kV ZSMVA 39.4 41.7 46.9 41.8 41.6 41.6 41.8 42.3 Newcastle CBD 33/11kV ZSPF 0.99 0.99 0.98 1.00 1.00 1.00 1.00 1.00 Newcastle CBD 33/11kV ZSMVA - - - - - - - - Newcastle City Main 33/11kV PF - - - - - - - - Newcastle City Main 33/11kV MVA - - - - 22.4 22.4 22.4 22.6 Tighes Hill 33/11kV ZSPF - - - - 0.9 0.9 0.94 0.94 Tighes Hill 33/11kV ZS

WINTER - Newcastle Inner City Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 23.5 22.5 24.2 19.1 18.8 18.7 18.9 19.4 Adamstown 132/11kV ZSPF 0.97 0.90 0.90 1.00 1.00 1.00 1.00 1.00 Adamstown 132/11kV ZSMVA - - - - - - - - Adamstown 33/11kV ZSPF - - - - - - - - Adamstown 33/11kV ZSMVA - 8.9 10.4 26.5 26.5 26.6 26.8 27.2 Broadmeadow 132/11kV ZSPF - 0.90 0.90 0.95 0.95 0.95 0.95 0.95 Broadmeadow 132/11kV ZSMVA 17.0 8.9 10.7 - - - - - Broadmeadow 33/11kV ZSPF 0.96 0.98 0.98 - - - - - Broadmeadow 33/11kV ZSMVA 22.1 23.3 20.6 22.0 22.0 - - - Carrington 33/11kV ZSPF 0.96 0.96 0.96 0.96 0.96 - - - Carrington 33/11kV ZSMVA 17.0 15.9 17.6 15.9 15.6 15.6 15.7 16.0 Kotara 33/11kV ZSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Kotara 33/11kV ZSMVA 13.3 13.1 14.3 9.2 8.9 9.5 9.5 9.8 New Lambton 33/11kV ZSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 New Lambton 33/11kV ZSMVA 32.5 31.2 35.2 32.8 32.6 32.8 33.1 33.8 Newcastle CBD 33/11kV ZSPF 0.99 0.99 0.99 1.00 1.00 1.0 1.0 1.0 Newcastle CBD 33/11kV ZSMVA - - - - - - - - Newcastle City Main 33/11kV PF - - - - - - - - Newcastle City Main 33/11kV MVA - - - - - 22.0 22.2 22.5 Tighes Hill 33/11kV ZSPF - - - - - 0.96 0.96 0.96 Tighes Hill 33/11kV ZS

Newcastle City Main 33/11kV ZS

Tighes Hill 33/11kV ZS

Newcastle CBD 33/11kV ZS

SubstationForecast Load

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

Actual Load Forecast Load

Adamstown 132/11kV ZS

Adamstown 33/11kV ZS

Broadmeadow 33/11kV ZS

Tighes Hill 33/11kV ZS

Broadmeadow 132/11kV ZS

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

Carrington 33/11kV ZS

Kotara 33/11kV ZS

New Lambton 33/11kV ZS

Newcastle Inner City Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C13 of C27

Newcastle Port

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

107.5 107.5 57.5 57.5 17.8 14.3 9.0 - 3.4 0.6

285.8 285.8 142.9 142.9 - - 1.0 2.3 0.0 0.0

- - - - 0.0 0.0 - - 0.0

126.4 126.4 62.6 65.0 13.4 12.2 1.3 - 2.2 0.1

- - - - 0.0 0.0 - - 0.0

- - 60.0 60.0 - - 4.0 1.3 0.0 0.0

68.6 68.6 45.7 45.7 - - - 1.0 0.0 0.0

SUMMER - Newcastle Port Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 39.5 40.2 43.6 43.4 42.5 43.0 43.5 44.0 Jesmond 132/11kV ZSPF 0.95 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Jesmond 132/11kV ZSMVA 63.4 69.4 65.1 65.1 65.1 65.1 65.1 65.1 Kooragang 132/33kV STSPF 0.95 0.94 0.96 0.96 0.96 0.96 0.96 1.0 Kooragang 132/33kV STSMVA - - - - - - - - Mayfield 33/11kV ZSPF - - - - - - - - Mayfield 33/11kV ZSMVA 20.7 23.4 26.3 23.3 22.5 22.0 21.7 21.8 Mayfield West 132/11kV ZSPF 0.90 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Mayfield West 132/11kV ZSMVA - - - - - - - - Shortland 33/11kV ZSPF - - - - - - - - Shortland 33/11kV ZSMVA 56.3 54.8 56.9 56.9 56.9 56.9 56.9 56.9 Waratah (Comsteel) 132/33kVPF 0.96 0.99 0.98 0.98 0.98 0.98 0.98 1.0 Waratah (Comsteel) 132/33kVMVA 6.2 5.0 3.8 3.8 3.8 3.8 3.8 3.8 Waratah (Domestic) 132/33kVPF 0.90 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Waratah (Domestic) 132/33kV

WINTER - Newcastle Port Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 31.4 32.0 34.9 32.6 32.5 31.9 32.3 32.9 Jesmond 132/11kV ZSPF 0.98 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Jesmond 132/11kV ZSMVA 65.6 65.5 65.2 65.2 65.2 65.2 65.2 65.2 Kooragang 132/33kV STSPF 0.94 0.94 0.94 0.94 0.94 0.9 0.9 0.9 Kooragang 132/33kV STSMVA 0.4 0.3 - - - - - - Mayfield 33/11kV ZSPF 0.90 0.90 - - - - - - Mayfield 33/11kV ZSMVA 20.1 15.5 23.8 21.3 20.6 20.2 20.2 20.5 Mayfield West 132/11kV ZSPF 0.92 0.93 0.94 0.94 0.94 0.94 0.94 0.94 Mayfield West 132/11kV ZSMVA - - - - - - - - Shortland 33/11kV ZSPF - - - - - - - - Shortland 33/11kV ZSMVA 57.3 55.7 55.7 55.7 55.7 55.7 55.7 55.7 Waratah (Comsteel) 132/33kVPF 0.94 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Waratah (Comsteel) 132/33kVMVA 22.8 4.6 5.3 5.3 5.3 5.3 5.3 5.3 Waratah (Domestic) 132/33kVPF 0.9 0.7 0.9 0.9 0.90 0.90 0.90 0.90 Waratah (Domestic) 132/33kV

Forecast Load

Jesmond 132/11kV ZS

Kooragang 132/33kV STS

Mayfield 33/11kV ZS

Mayfield West 132/11kV ZS

Shortland 33/11kV ZS

Waratah (Comsteel) 132/33kV STS

Waratah (Domestic) 132/33kV STS

Actual Load

Waratah (Comsteel) 132/33kV STS

Waratah (Domestic) 132/33kV STS

Substation

Forecast Load

Jesmond 132/11kV ZS

Kooragang 132/33kV STS

Mayfield West 132/11kV ZS

Shortland 33/11kV ZS

Mayfield 33/11kV ZS

Substation

Waratah (Comsteel) 132/33kV STS

Waratah (Domestic) 132/33kV STS

Newcastle Port Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Jesmond 132/11kV ZS

Kooragang 132/33kV STS

Mayfield 33/11kV ZS

Mayfield West 132/11kV ZS

Shortland 33/11kV ZS

Page C14 of C27

Newcastle Wes

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

121.4 121.4 60.8 64.2 14.0 10.6 2.5 - 3.3 0.0

285.8 285.8 142.9 142.9 - - 10.8 - 8.2 0.0

135.2 137.2 68.6 68.6 - - 0.8 - 1.2 8.3

- - - - 0.0 0.0 - - 0.0

45.7 45.7 22.9 22.9 7.8 5.8 2.8 - 2.0 0.0

37.5 37.5 22.9 22.9 14.6 10.4 3.3 - 2.4 0.0

76.2 76.2 38.1 38.1 13.1 8.4 3.5 - 2.5 2.3

- - - - 0.0 0.0 - - 0.0

SUMMER - Newcastle Western Corridor Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 31.2 30.7 33.6 29.1 29.0 29.0 29.1 29.4 Argenton 132/11kV ZSPF 0.94 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Argenton 132/11kV ZSMVA 83.2 81.3 89.8 91.7 92.9 94.0 95.1 96.0 Argenton 132/33kV STSPF 0.93 0.94 0.94 0.94 0.94 0.94 0.94 0.9 Argenton 132/33kV STSMVA 21.7 19.1 25.2 7.5 7.5 7.5 7.5 7.5 Awaba 132/33kV STSPF 0.95 0.96 0.90 0.90 0.90 0.90 0.90 0.90 Awaba 132/33kV STSMVA - - - - - - - - Boolaroo 33/11kV ZSPF - - - - - - - - Boolaroo 33/11kV ZSMVA 18.6 19.4 23.3 23.7 24.3 24.7 25.1 25.3 Cardiff 33/11kV ZSPF 0.95 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Cardiff 33/11kV ZSMVA 18.7 20.5 22.7 24.7 25.4 26.0 26.4 26.7 Edgeworth 33/11kV ZSPF 0.95 0.97 0.97 0.97 0.97 0.97 0.97 1.0 Edgeworth 33/11kV ZSMVA 20.8 18.9 22.0 23.2 23.5 23.9 24.3 24.8 Maryland 132/11kV ZSPF 0.94 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Maryland 132/11kV ZSMVA - - - - - - - - Wallsend 33/11kV ZSPF - - - - - - - - Wallsend 33/11kV ZS

WINTER - Newcastle Western Corridor Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 27.0 25.2 25.3 25.5 19.9 19.6 19.6 20.0 Argenton 132/11kV ZSPF 0.96 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Argenton 132/11kV ZSMVA 64.4 60.1 69.5 67.0 68.2 68.7 69.5 70.6 Argenton 132/33kV STSPF 0.97 0.98 0.98 0.98 0.98 1.0 1.0 1.0 Argenton 132/33kV STSMVA 19.0 20.0 17.5 17.3 7.0 7.0 7.0 7.0 Awaba 132/33kV STSPF 0.94 0.93 0.97 0.97 0.97 0.97 0.97 0.97 Awaba 132/33kV STSMVA - - - - - - - - Boolaroo 33/11kV ZSPF - - - - - - - - Boolaroo 33/11kV ZSMVA 14.8 13.9 17.4 16.0 17.6 17.6 17.8 18.1 Cardiff 33/11kV ZSPF 0.98 0.98 0.97 0.97 0.97 0.97 0.97 0.97 Cardiff 33/11kV ZSMVA 12.7 13.4 16.2 15.3 15.7 16.1 16.5 16.8 Edgeworth 33/11kV ZSPF 0.98 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Edgeworth 33/11kV ZSMVA 12.9 11.4 14.2 12.6 12.5 12.7 13.1 13.7 Maryland 132/11kV ZSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 Maryland 132/11kV ZSMVA - - - - - - - - Wallsend 33/11kV ZSPF - - - - - - - - Wallsend 33/11kV ZS

Wallsend 33/11kV ZS

SubstationForecast Load

Argenton 132/11kV ZS

Argenton 132/33kV STS

Awaba 132/33kV STS

Boolaroo 33/11kV ZS

Cardiff 33/11kV ZS

Edgeworth 33/11kV ZS

Maryland 132/11kV ZS

Actual Load Forecast Load

Argenton 132/11kV ZS

Argenton 132/33kV STS

Boolaroo 33/11kV ZS

Substation

Cardiff 33/11kV ZS

Edgeworth 33/11kV ZS

Maryland 132/11kV ZS

Wallsend 33/11kV ZS

Awaba 132/33kV STS

Edgeworth 33/11kV ZS

Maryland 132/11kV ZS

Wallsend 33/11kV ZS

Newcastle Western Corridor Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Argenton 132/11kV ZS

Argenton 132/33kV STS

Awaba 132/33kV STS

Boolaroo 33/11kV ZS

Cardiff 33/11kV ZS

Page C15 of C27

North East Lak

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

113.0 113.0 60.2 60.2 23.8 19.8 6.3 - 2.7 3.8

- - - - 0.0 0.0 - - 0.0

74.9 76.2 38.1 38.1 12.4 9.1 7.0 - 2.1 0.0

- - - - 0.0 0.0 - - 0.0

44.4 44.4 24.1 24.4 13.6 11.9 5.5 - 1.6 0.0

30.8 32.5 16.9 18.1 12.4 10.6 5.3 - 1.7 0.0

411.5 411.5 274.4 274.4 - - 4.0 - 10.3 0.0

59.8 65.8 32.7 34.3 14.2 11.6 5.8 - 1.9 0.0

49.6 51.3 25.6 25.6 5.3 4.8 4.3 - 0.9 0.0

29.9 29.9 16.4 16.4 2.8 2.7 4.3 0.5 1.3 0.0

SUMMER - North East Lake Macquarie Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 31.5 28.4 32.5 28.6 28.5 28.5 28.7 29.0 Charlestown 132/11kV ZSPF 0.90 0.90 0.90 0.97 0.97 0.97 0.97 0.97 Charlestown 132/11kV ZSMVA - - - - - - - - Charlestown 33/11kV ZSPF - - - - - - - - Charlestown 33/11kV ZSMVA 22.2 19.9 23.4 20.9 21.0 21.1 21.3 21.5 Croudace Bay 33/11kV ZSPF 0.90 0.95 0.96 1.00 1.00 1.00 1.00 1.00 Croudace Bay 33/11kV ZSMVA 0.1 - - - - - - - Dudley 33/11kV ZSPF 0.80 - - - - - - - Dudley 33/11kV ZSMVA 13.0 14.7 16.1 14.2 13.7 13.4 13.3 13.4 Gateshead 33/11kV ZSPF 0.92 0.95 0.96 0.96 0.96 0.96 0.96 0.96 Gateshead 33/11kV ZSMVA 13.1 13.1 15.3 13.5 13.3 13.2 13.3 13.5 Jewells 33/11kV ZSPF 0.95 0.97 0.97 0.97 0.97 0.97 0.97 1.0 Jewells 33/11kV ZSMVA 149.1 154.3 163.0 132.3 131.8 131.2 131.7 133.4 Merewether 132/33kV STSPF 0.90 0.98 0.99 0.98 0.99 0.99 0.99 0.98 Merewether 132/33kV STSMVA 17.2 16.4 17.9 17.3 17.1 17.1 17.2 17.4 Mt Hutton 33/11kV ZSPF 0.90 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Mt Hutton 33/11kV ZSMVA 10.2 10.2 12.2 11.4 11.3 11.2 11.3 11.5 Pelican 33/11kV ZSPF 0.94 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Pelican 33/11kV ZSMVA 9.8 9.9 12.5 11.5 11.7 11.9 12.1 12.3 Swansea 33/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 0.98 0.98 Swansea 33/11kV ZS

WINTER - North East Lake Macquarie Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 24.8 25.2 27.1 24.4 24.0 24.1 24.4 24.8 Charlestown 132/11kV ZSPF 0.98 0.90 0.90 0.98 0.98 0.98 0.98 0.98 Charlestown 132/11kV ZSMVA - - - - - - - - Charlestown 33/11kV ZSPF - - - - - - - - Charlestown 33/11kV ZSMVA 16.3 14.9 17.2 15.8 15.2 15.2 15.3 15.6 Croudace Bay 33/11kV ZSPF 0.90 0.98 0.98 1.00 0.99 0.99 0.99 0.99 Croudace Bay 33/11kV ZSMVA 0.0 - - - - - - - Dudley 33/11kV ZSPF 0.99 - - - - - - - Dudley 33/11kV ZSMVA 12.9 13.0 14.1 13.2 13.1 13.0 13.1 13.4 Gateshead 33/11kV ZSPF 0.98 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Gateshead 33/11kV ZSMVA 12.5 11.9 13.1 12.6 12.4 12.3 12.3 12.6 Jewells 33/11kV ZSPF 0.98 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Jewells 33/11kV ZSMVA 141.5 130.6 140.0 120.6 119.2 119.8 120.8 123.1 Merewether 132/33kV STSPF 1.0 1.0 1.0 1.0 0.98 0.98 0.98 0.98 Merewether 132/33kV STSMVA 13.0 12.6 14.6 14.0 14.0 14.1 14.3 14.5 Mt Hutton 33/11kV ZSPF 0.95 0.99 0.99 0.99 0.99 1.0 1.0 1.0 Mt Hutton 33/11kV ZSMVA 9.8 9.8 11.0 10.2 10.1 10.1 10.2 10.4 Pelican 33/11kV ZSPF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Pelican 33/11kV ZSMVA 10.8 10.7 12.0 11.3 11.2 11.2 11.4 11.7 Swansea 33/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Swansea 33/11kV ZS

Pelican 33/11kV ZS

Swansea 33/11kV ZS

Mt Hutton 33/11kV ZS

SubstationForecast Load

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

Merewether 132/33kV STS

Mt Hutton 33/11kV ZS

Pelican 33/11kV ZS

Actual Load Forecast Load

Charlestown 132/11kV ZS

Charlestown 33/11kV ZS

Dudley 33/11kV ZS

Swansea 33/11kV ZS

Croudace Bay 33/11kV ZS

Substation

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

Merewether 132/33kV STS

Mt Hutton 33/11kV ZS

Pelican 33/11kV ZS

Swansea 33/11kV ZS

Gateshead 33/11kV ZS

Jewells 33/11kV ZS

Merewether 132/33kV STS

North East Lake Macquarie Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C16 of C27

North West

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

82.9 85.5 42.3 44.6 12.8 13.0 3.0 3.0 2.3 0.0

76.2 76.2 38.1 38.1 10.7 9.6 4.3 - 1.1 0.0

171.5 171.5 114.3 114.3 30.7 30.3 7.0 3.5 3.6 0.1

164.1 171.5 106.9 114.3 23.9 20.3 3.0 - 5.6 0.0

SUMMER - North West Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 19.1 18.3 21.6 22.3 21.5 21.2 21.2 21.6 Berowra 132/11kV ZSPF 0.94 0.93 0.93 0.93 0.93 0.93 0.93 0.93 Berowra 132/11kV ZSMVA 9.4 9.3 10.8 11.1 11.5 11.7 11.9 12.0 Galston 132/11kV ZSPF 0.93 0.93 0.93 0.93 0.93 0.93 0.93 0.9 Galston 132/11kV ZSMVA 60.6 60.7 68.1 73.0 80.5 81.3 76.5 77.9 Hornsby 132/11kV ZSPF 0.97 0.97 0.98 0.99 0.99 0.99 0.99 0.99 Hornsby 132/11kV ZSMVA 68.2 65.3 77.4 82.0 101.9 103.3 86.0 86.9 Pennant Hills 132/11kV ZSPF 0.96 0.96 0.97 0.97 0.97 0.97 0.97 0.97 Pennant Hills 132/11kV ZS

WINTER - North West Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 20.6 20.6 22.0 22.6 22.0 21.6 21.6 22.0 Berowra 132/11kV ZSPF 0.90 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Berowra 132/11kV ZSMVA 8.6 8.1 9.8 9.6 9.6 9.6 9.7 9.9 Galston 132/11kV ZSPF 0.97 0.97 0.98 0.98 0.98 1.0 1.0 1.0 Galston 132/11kV ZSMVA 59.1 59.6 67.3 69.6 76.1 76.0 70.8 72.5 Hornsby 132/11kV ZSPF 0.99 0.99 0.99 1.00 1.00 1.00 1.00 1.00 Hornsby 132/11kV ZSMVA 59.0 59.7 65.9 61.4 79.8 78.5 59.8 60.9 Pennant Hills 132/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Pennant Hills 132/11kV ZS

Pennant Hills 132/11kV ZS

Actual Load Forecast Load

Berowra 132/11kV ZS

Galston 132/11kV ZS

Pennant Hills 132/11kV ZS

Hornsby 132/11kV ZS

Substation

SubstationForecast Load

Berowra 132/11kV ZS

Galston 132/11kV ZS

Hornsby 132/11kV ZS

Berowra 132/11kV ZS

Galston 132/11kV ZS

Hornsby 132/11kV ZS

Pennant Hills 132/11kV ZS

North West Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C17 of C27

Pittwater and T

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

15.2 15.3 15.2 15.3 5.4 7.5 - 4.0 0.8 0.0

97.8 97.8 57.4 59.6 12.7 12.2 6.5 2.5 1.9 0.3

20.3 20.3 19.6 20.3 11.7 13.4 - 3.5 1.1 1.0

22.6 22.6 20.8 22.4 10.6 13.0 - 7.3 0.9 0.0

233.2 233.2 141.0 149.0 - - 2.8 1.3 5.3 5.0

60.7 60.7 30.5 30.5 3.8 3.2 12.0 - 0.9 0.0

SUMMER - Pittwater and Terrey Hills Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 9.2 9.5 10.3 9.3 9.1 9.1 9.1 9.3 Careel Bay 33/11kV ZSPF 0.97 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Careel Bay 33/11kV ZSMVA 27.0 26.7 34.4 32.8 33.2 33.6 34.1 34.6 Mona Vale 33/11kV ZSPF 0.92 0.90 0.93 0.93 0.93 0.93 0.93 0.9 Mona Vale 33/11kV ZSMVA 8.9 11.0 11.7 12.3 12.5 12.7 12.9 13.3 Narrabeen 33/11kV ZSPF 0.90 0.89 0.90 0.90 0.90 0.90 0.90 0.90 Narrabeen 33/11kV ZSMVA 10.9 10.5 12.0 10.5 10.3 10.3 10.4 10.6 Newport 33/11kV ZSPF 0.90 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Newport 33/11kV ZSMVA 59.5 58.9 79.8 69.6 69.9 70.4 71.4 72.7 Sydney East 132/33kV STSPF 1.00 0.99 0.97 0.97 0.97 0.97 0.97 0.97 Sydney East 132/33kV STSMVA 14.4 15.9 17.0 17.3 17.4 17.5 17.7 17.8 Terrey Hills 33/11kV ZSPF 0.94 0.94 0.94 0.94 0.94 0.94 0.94 0.9 Terrey Hills 33/11kV ZS

WINTER - Pittwater and Terrey Hills Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 12.3 12.2 14.3 13.3 13.5 13.6 13.8 14.0 Careel Bay 33/11kV ZSPF 0.90 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Careel Bay 33/11kV ZSMVA 31.1 30.1 33.1 33.0 33.2 33.2 33.5 34.2 Mona Vale 33/11kV ZSPF 0.92 0.90 0.96 0.96 0.96 1.0 1.0 1.0 Mona Vale 33/11kV ZSMVA 11.6 10.5 13.4 14.0 14.1 14.3 14.6 15.0 Narrabeen 33/11kV ZSPF 0.90 0.93 0.96 0.96 0.96 0.96 0.96 0.96 Narrabeen 33/11kV ZSMVA 14.6 13.7 14.7 14.6 14.5 14.5 14.6 14.9 Newport 33/11kV ZSPF 0.95 0.95 0.98 0.98 0.98 0.98 0.98 0.98 Newport 33/11kV ZSMVA 70.8 70.0 75.7 74.6 74.8 75.2 76.2 77.9 Sydney East 132/33kV STSPF 1.00 0.99 0.98 0.99 0.99 0.99 0.99 0.98 Sydney East 132/33kV STSMVA 12.5 12.7 14.4 13.7 13.6 13.6 13.8 14.0 Terrey Hills 33/11kV ZSPF 0.95 0.95 0.97 0.97 0.97 0.97 0.97 0.97 Terrey Hills 33/11kV ZS

Narrabeen 33/11kV ZS

Newport 33/11kV ZS

Sydney East 132/33kV STS

Terrey Hills 33/11kV ZS

Actual Load

Terrey Hills 33/11kV ZS

Substation

Forecast Load

Careel Bay 33/11kV ZS

Mona Vale 33/11kV ZS

Newport 33/11kV ZS

Sydney East 132/33kV STS

Narrabeen 33/11kV ZS

Substation

Forecast Load

Careel Bay 33/11kV ZS

Mona Vale 33/11kV ZS

Terrey Hills 33/11kV ZS

Pittwater and Terrey Hills Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Careel Bay 33/11kV ZS

Mona Vale 33/11kV ZS

Narrabeen 33/11kV ZS

Newport 33/11kV ZS

Sydney East 132/33kV STS

Page C18 of C27

Port Stephens

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

73.0 66.0 38.1 38.0 1.5 1.2 3.0 - 1.6 0.0

65.6 67.9 44.3 45.0 14.1 12.1 3.5 - 3.2 0.0

73.6 73.6 38.1 38.1 7.2 5.5 3.5 - 1.9 0.1

- - - - 0.0 0.0 - - 0.0

- - - - 0.0 0.0 - - 0.0

40.0 40.0 20.0 20.0 4.0 3.1 1.3 - 0.6 0.0

38.8 40.5 18.7 18.8 1.6 1.4 2.5 - 1.4 0.0

219.3 242.4 153.1 161.9 - - 2.8 - 10.7 0.0

74.3 74.3 38.1 38.1 12.2 11.5 3.3 - 0.9 0.0

73.3 73.3 38.1 38.1 9.0 7.8 1.8 - 1.4 0.0

45.3 49.8 24.8 25.6 4.8 3.1 4.5 - 0.3 6.5

SUMMER - Port Stephens Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA - 10.9 11.6 11.9 11.9 11.9 12.1 12.4 Medowie 33/11kV ZSPF - 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Medowie 33/11kV ZSMVA 24.0 21.9 26.0 22.8 22.9 23.0 23.3 23.6 Nelson Bay 33/11kV ZSPF 0.99 0.98 0.97 0.97 0.97 0.97 0.97 1.0 Nelson Bay 33/11kV ZSMVA 23.3 20.2 23.6 22.8 23.0 23.2 23.5 23.9 Raymond Terr NEW 33/11kV PF 0.93 0.96 0.98 0.98 0.98 0.98 0.98 0.98 Raymond Terr NEW 33/11kV MVA - - - - - - - - Raymond Terrace 33/11kV ZSPF - - - - - - - - Raymond Terrace 33/11kV ZSMVA 0.2 - - - - - - - Salt Ash 33/11kV ZSPF 0.90 - - - - - - - Salt Ash 33/11kV ZSMVA 6.0 6.9 8.6 8.1 8.4 8.5 8.7 8.9 Stockton 33/11kV ZSPF 0.96 0.97 0.97 0.97 0.97 0.97 0.97 1.0 Stockton 33/11kV ZSMVA 8.4 9.2 10.8 9.7 10.0 10.3 10.5 10.6 Tanilba Bay 33/11kV ZSPF 0.90 0.90 0.90 0.99 0.99 0.99 0.99 0.99 Tanilba Bay 33/11kV ZSMVA 99.7 102.8 122.5 109.1 109.8 110.8 112.0 113.4 Tomago 132/33kV STSPF 0.95 0.96 0.96 0.99 0.99 0.99 0.99 0.99 Tomago 132/33kV STSMVA 12.6 12.6 12.2 11.7 11.6 11.4 11.4 11.4 Tomago 33/11kV ZSPF 0.90 0.92 0.92 0.92 0.92 0.92 0.92 0.92 Tomago 33/11kV ZSMVA 15.9 12.7 17.3 15.5 15.6 15.7 15.9 16.2 Tomaree 33/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 0.97 0.97 Tomaree 33/11kV ZSMVA 13.6 3.6 4.8 3.9 3.9 3.9 3.9 3.9 Williamtown 33/11kV ZSPF 0.94 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Williamtown 33/11kV ZS

WINTER - Port Stephens Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA - - 9.1 8.8 8.8 8.9 9.1 9.4 Medowie 33/11kV ZSPF - - 0.99 0.99 0.99 0.99 0.99 0.99 Medowie 33/11kV ZSMVA 20.1 20.7 22.2 21.2 20.6 20.4 20.5 20.9 Nelson Bay 33/11kV ZSPF 0.99 0.99 1.00 1.00 1.00 1.0 1.0 1.0 Nelson Bay 33/11kV ZSMVA 18.1 19.3 18.1 18.0 17.9 18.0 18.3 18.7 Raymond Terr NEW 33/11kV PF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Raymond Terr NEW 33/11kV MVA - - - - - - - - Raymond Terrace 33/11kV ZSPF - - - - - - - - Raymond Terrace 33/11kV ZSMVA 1.8 - - - - - - - Salt Ash 33/11kV ZSPF 0.96 - - - - - - - Salt Ash 33/11kV ZSMVA 5.2 5.9 6.6 6.6 6.7 6.9 7.1 7.3 Stockton 33/11kV ZSPF 0.98 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Stockton 33/11kV ZSMVA 7.1 8.8 9.5 8.7 8.8 8.9 9.1 9.3 Tanilba Bay 33/11kV ZSPF 0.9 0.9 0.9 1.0 1.00 0.99 0.99 0.99 Tanilba Bay 33/11kV ZSMVA 89.9 92.3 95.6 92.4 91.6 91.8 92.8 94.6 Tomago 132/33kV STSPF 0.98 0.96 0.96 0.99 0.99 1.0 1.0 1.0 Tomago 132/33kV STSMVA 13.4 12.8 11.5 12.0 11.9 11.9 12.0 12.1 Tomago 33/11kV ZSPF 0.91 0.92 0.94 0.94 0.94 0.94 0.94 0.94 Tomago 33/11kV ZSMVA 13.2 14.4 15.0 14.5 14.1 14.0 14.1 14.4 Tomaree 33/11kV ZSPF 0.98 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Tomaree 33/11kV ZSMVA 11.0 10.8 3.1 3.2 3.2 3.2 3.3 3.3 Williamtown 33/11kV ZSPF 0.97 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Williamtown 33/11kV ZS

Tomaree 33/11kV ZS

Williamtown 33/11kV ZS

Tomago 132/33kV STS

Substation

Salt Ash 33/11kV ZS

Stockton 33/11kV ZS

Tanilba Bay 33/11kV ZS

Medowie 33/11kV ZS

Nelson Bay 33/11kV ZS

Raymond Terr NEW 33/11kV ZS

Raymond Terrace 33/11kV ZS

Tomago 33/11kV ZS

Nelson Bay 33/11kV ZS

Raymond Terrace 33/11kV ZS

Forecast Load

Stockton 33/11kV ZS

Tanilba Bay 33/11kV ZS

Tomago 132/33kV STS

Tomago 33/11kV ZS

Tomaree 33/11kV ZS

Williamtown 33/11kV ZS

Raymond Terr NEW 33/11kV ZS

Salt Ash 33/11kV ZS

Raymond Terr NEW 33/11kV ZS

Raymond Terrace 33/11kV ZS

Salt Ash 33/11kV ZS

Forecast Load

Medowie 33/11kV ZS

Actual LoadSubstation

Williamtown 33/11kV ZS

Stockton 33/11kV ZS

Tanilba Bay 33/11kV ZS

Tomago 132/33kV STS

Tomago 33/11kV ZS

Tomaree 33/11kV ZS

Medowie 33/11kV ZS

Nelson Bay 33/11kV ZS

Port Stephens Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C19 of C27

Singleton

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

28.9 30.5 15.1 15.2 8.1 6.9 4.8 - 1.5 0.0

32.4 35.6 13.4 14.7 2.4 2.2 1.5 - 0.1 0.0

6.0 6.7 0.0 0.0 1.2 0.9 1.8 - 0.2 0.0

35.2 35.2 20.3 20.3 1.6 1.3 1.0 - 0.9 0.0

53.7 58.0 26.8 29.0 0.9 0.7 0.8 - 0.1 0.0

405.7 459.4 284.4 300.7 - - 8.0 - 5.2 160.0

45.7 45.7 22.9 22.9 12.1 9.0 6.3 - 1.0 0.4

76.2 76.2 38.1 38.1 8.2 6.8 1.8 - 1.8 12.8

SUMMER - Singleton Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 11.5 13.5 11.9 12.6 12.6 12.6 12.8 13.0 Branxton 66/11kV ZSPF 0.97 0.99 0.98 0.98 0.98 0.98 0.98 0.98 Branxton 66/11kV ZSMVA 3.0 2.9 2.4 2.4 2.4 2.4 2.4 2.5 Lemington 66/11kV ZSPF 0.91 0.92 0.92 0.92 0.92 0.92 0.92 0.9 Lemington 66/11kV ZSMVA 1.1 1.2 1.2 1.3 1.3 1.3 1.3 1.3 Mitchells Flat 66/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Mitchells Flat 66/11kV ZSMVA 7.5 7.2 6.7 6.8 6.7 6.7 6.6 6.6 Mt Thorley 66/11kV ZSPF 0.94 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Mt Thorley 66/11kV ZSMVA 6.7 3.4 3.9 3.8 3.8 3.8 3.8 3.9 Newdell 66/11kV ZSPF 0.93 0.92 0.96 0.96 0.96 0.96 0.96 0.96 Newdell 66/11kV ZSMVA 170.3 149.8 153.2 149.6 149.6 149.8 150.1 150.7 Singleton 132/66kV STSPF 0.90 0.90 0.90 0.96 0.96 0.96 0.96 1.0 Singleton 132/66kV STSMVA 19.9 20.1 19.4 21.1 21.2 21.4 21.5 21.7 Singleton 66/11kV ZSPF 0.92 0.93 0.95 0.95 0.95 0.95 0.95 0.95 Singleton 66/11kV ZSMVA 15.4 17.6 16.8 17.2 17.1 17.1 17.3 17.5 Singleton North 66/11kV ZSPF 0.95 0.94 0.94 0.94 0.94 0.94 0.94 0.94 Singleton North 66/11kV ZS

WINTER - Singleton Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 8.5 9.0 10.0 8.8 8.9 9.0 9.2 9.5 Branxton 66/11kV ZSPF 0.99 0.99 1.00 1.00 1.00 1.00 1.00 1.00 Branxton 66/11kV ZSMVA 2.0 2.7 2.2 2.2 2.2 2.2 2.2 2.2 Lemington 66/11kV ZSPF 0.93 0.93 0.95 0.95 0.95 1.0 1.0 1.0 Lemington 66/11kV ZSMVA 0.8 0.8 0.9 0.8 0.8 0.8 0.8 0.8 Mitchells Flat 66/11kV ZSPF 1.00 0.97 1.00 1.00 1.00 1.00 1.00 1.00 Mitchells Flat 66/11kV ZSMVA 6.7 6.0 5.8 5.6 5.5 5.5 5.6 5.7 Mt Thorley 66/11kV ZSPF 0.94 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Mt Thorley 66/11kV ZSMVA 10.3 3.5 3.1 3.3 3.3 3.3 3.3 3.3 Newdell 66/11kV ZSPF 0.93 0.94 0.96 0.96 0.96 0.96 0.96 0.96 Newdell 66/11kV ZSMVA 155.5 156.0 144.6 141.8 141.9 142.2 142.6 143.3 Singleton 132/66kV STSPF 0.90 0.90 0.90 0.97 0.97 0.97 0.97 0.97 Singleton 132/66kV STSMVA 12.0 13.9 14.4 14.8 15.2 15.5 15.7 16.0 Singleton 66/11kV ZSPF 1.0 0.9 1.0 1.0 0.97 0.97 0.97 0.97 Singleton 66/11kV ZSMVA 11.6 12.1 13.8 12.1 11.8 11.7 11.7 12.0 Singleton North 66/11kV ZSPF 0.99 0.94 0.97 0.97 0.97 1.0 1.0 1.0 Singleton North 66/11kV ZS

Singleton North 66/11kV ZS

SubstationForecast Load

Branxton 66/11kV ZS

Lemington 66/11kV ZS

Mitchells Flat 66/11kV ZS

Mt Thorley 66/11kV ZS

Newdell 66/11kV ZS

Singleton 132/66kV STS

Singleton 66/11kV ZS

Actual Load Forecast Load

Branxton 66/11kV ZS

Lemington 66/11kV ZS

Mt Thorley 66/11kV ZS

Substation

Newdell 66/11kV ZS

Singleton 132/66kV STS

Singleton 66/11kV ZS

Singleton North 66/11kV ZS

Mitchells Flat 66/11kV ZS

Singleton 132/66kV STS

Singleton 66/11kV ZS

Singleton North 66/11kV ZS

Singleton Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Branxton 66/11kV ZS

Lemington 66/11kV ZS

Mitchells Flat 66/11kV ZS

Mt Thorley 66/11kV ZS

Newdell 66/11kV ZS

Page C20 of C27

St George

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

60.6 62.4 39.1 42.9 13.9 14.1 7.5 31.0 0.9 0.0

47.4 47.4 31.6 31.6 10.3 10.5 3.0 7.0 1.4 0.0

- - - - 0.0 0.0 - - 0.0

108.2 108.2 60.0 60.0 9.6 5.6 4.8 - 0.9 0.0

- - - - 0.0 0.0 0.0 0.0 0.0

170.8 170.8 114.3 114.3 53.9 49.3 6.5 - 3.7 1.8

114.3 114.3 64.3 70.7 19.7 17.9 5.3 - 2.9 0.2

349.8 349.8 233.2 233.2 - - 6.0 - 8.3 0.0

65.7 65.7 42.8 42.8 19.6 18.4 3.0 - 2.2 0.0

- - - - 0.0 0.0 - - 0.0 0.0

58.0 60.3 27.1 27.1 14.9 13.3 8.0 - 0.7 0.0

49.9 52.5 26.9 26.9 5.6 5.4 3.5 0.5 0.7 0.0

SUMMER - St George Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 14.3 14.4 18.3 22.9 24.1 24.3 24.6 25.0 Arncliffe 33/11kV ZSPF 0.90 0.88 0.98 0.98 0.98 0.98 0.98 0.98 Arncliffe 33/11kV ZSMVA 17.1 15.3 19.7 18.8 19.0 19.3 19.6 20.1 Blakehurst 33/11kV ZSPF 0.93 0.93 0.98 0.98 0.98 0.98 0.98 1.0 Blakehurst 33/11kV ZSMVA - - - - - - - - Carlton 33/11kV ZSPF - - - - - - - - Carlton 33/11kV ZSMVA - 23.7 29.8 25.0 25.7 26.3 26.8 27.1 Hurstville North 132/11kV ZSPF - 0.90 0.90 1.00 1.00 1.00 0.99 0.99 Hurstville North 132/11kV ZSMVA 18.7 - - - - - - - Hurstville North 33/11kV ZSPF 0.92 - - - - - - - Hurstville North 33/11kV ZSMVA 65.2 61.9 72.6 70.2 69.4 69.3 69.8 71.2 Kogarah 132/11kV ZSPF 0.92 0.91 0.93 0.93 0.93 0.93 0.93 0.9 Kogarah 132/11kV ZSMVA 39.9 36.9 45.7 42.8 42.7 43.0 43.6 44.5 Mortdale 33/11kV ZSPF 0.96 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Mortdale 33/11kV ZSMVA 134.9 106.3 135.8 129.8 132.6 115.9 117.7 120.3 Peakhurst 132/33kV STSPF 0.97 0.99 0.99 0.98 0.98 0.99 0.99 0.99 Peakhurst 132/33kV STSMVA 22.7 21.5 25.7 23.2 23.2 23.4 23.7 24.3 Riverwood 33/11kV ZSPF 0.87 0.87 0.95 0.95 0.95 0.95 0.95 0.95 Riverwood 33/11kV ZSMVA - - - - - 19.0 19.2 19.5 Rockdale 132/11kV ZSPF - - - - - 0.9 0.87 0.87 Rockdale 132/11kV ZSMVA 17.4 16.2 17.8 18.0 18.7 - - - Rockdale 33/11kV ZSPF 0.89 0.88 0.87 0.87 0.87 - - - Rockdale 33/11kV ZSMVA 11.9 12.5 16.2 14.6 15.6 15.8 16.1 16.4 Sans Souci 33/11kV ZSPF 0.97 0.98 0.97 0.97 0.97 0.97 0.97 1.0 Sans Souci 33/11kV ZS

WINTER - St George Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 16.8 15.9 18.6 21.4 26.8 27.2 27.6 28.2 Arncliffe 33/11kV ZSPF 0.92 0.93 0.96 0.96 0.96 0.96 0.96 0.96 Arncliffe 33/11kV ZSMVA 18.4 18.2 20.1 19.9 21.3 21.6 22.0 22.6 Blakehurst 33/11kV ZSPF 0.93 0.95 0.95 0.95 0.95 1.0 1.0 1.0 Blakehurst 33/11kV ZSMVA - - - - - - - - Carlton 33/11kV ZSPF - - - - - - - - Carlton 33/11kV ZSMVA - - 17.5 15.6 16.5 16.6 16.8 17.2 Hurstville North 132/11kV ZSPF - - 0.90 0.99 1.00 1.00 1.00 1.00 Hurstville North 132/11kV ZSMVA 15.4 16.1 - - - - - - Hurstville North 33/11kV ZSPF 0.90 0.95 - - - - - - Hurstville North 33/11kV ZSMVA 66.7 67.8 66.4 68.9 69.3 69.9 71.0 72.6 Kogarah 132/11kV ZSPF 0.88 0.81 0.79 0.79 0.79 0.79 0.79 0.79 Kogarah 132/11kV ZSMVA 40.6 40.6 41.5 41.6 42.6 42.4 42.9 44.0 Mortdale 33/11kV ZSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 Mortdale 33/11kV ZSMVA 145.3 137.9 128.8 129.6 137.8 138.8 123.7 126.8 Peakhurst 132/33kV STSPF 0.97 0.96 0.98 0.98 0.97 1.0 1.0 1.0 Peakhurst 132/33kV STSMVA 24.1 23.3 24.1 23.9 23.7 23.8 24.2 24.9 Riverwood 33/11kV ZSPF 0.96 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Riverwood 33/11kV ZSMVA - - - - - - 17.7 18.1 Rockdale 132/11kV ZSPF - - - - - - 0.96 0.96 Rockdale 132/11kV ZSMVA 15.3 14.8 15.8 16.2 17.1 17.4 - - Rockdale 33/11kV ZSPF 0.92 0.92 0.97 0.97 0.97 0.97 - - Rockdale 33/11kV ZSMVA 14.2 14.4 15.5 15.1 15.0 15.0 15.2 15.6 Sans Souci 33/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Sans Souci 33/11kV ZS

Rockdale 132/11kV ZS

Rockdale 33/11kV ZS

Sans Souci 33/11kV ZS

Peakhurst 132/33kV STS

Forecast Load

Arncliffe 33/11kV ZS

Blakehurst 33/11kV ZS

Carlton 33/11kV ZS

Riverwood 33/11kV ZS

Hurstville North 132/11kV ZS

Hurstville North 33/11kV ZS

Kogarah 132/11kV ZS

Mortdale 33/11kV ZS

Rockdale 132/11kV ZS

Rockdale 33/11kV ZS

Sans Souci 33/11kV ZS

Substation

Forecast Load

Arncliffe 33/11kV ZS

Blakehurst 33/11kV ZS

Hurstville North 132/11kV ZS

Hurstville North 33/11kV ZS

Carlton 33/11kV ZS

SubstationActual Load

Kogarah 132/11kV ZS

Mortdale 33/11kV ZS

Peakhurst 132/33kV STS

Riverwood 33/11kV ZS

Sans Souci 33/11kV ZS

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

Peakhurst 132/33kV STS

Riverwood 33/11kV ZS

Rockdale 132/11kV ZS

Rockdale 33/11kV ZS

St George Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C21 of C27

Sutherland

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

76.2 76.2 38.1 38.1 19.5 18.2 5.3 - 0.7 0.0

106.9 118.2 53.5 64.2 24.7 28.5 - 6.8 2.7 0.5

- - - - 0.0 0.0 - - 2.8 0.0

56.2 56.2 29.0 30.9 7.4 7.8 - 3.0 0.0

85.9 85.9 40.2 40.2 13.7 10.6 3.3 - 1.2 0.0

- - - - 0.0 0.0 3.3 - 0.0

61.3 62.7 36.1 37.8 14.8 14.7 2.5 3.0 2.3 0.2

76.2 76.3 44.6 44.6 23.8 26.0 - 6.0 2.0 0.0

- 174.9 - 116.6 - - 10.5 3.0 0.0 0.0

64.9 66.3 35.6 35.7 0.0 0.0 - 15.0 0.0

14.6 14.6 8.9 8.9 0.0 0.0 - - 0.0

76.2 76.2 38.1 38.1 2.8 3.1 - 2.0 0.3 0.0

76.2 76.2 38.1 38.1 2.8 3.1 - 2.0 0.3 0.0

38.5 44.1 19.2 22.0 0.0 0.0 3.8 - 22.5

121.4 130.0 60.7 65.0 10.7 9.7 3.8 - 3.4 0.2

71.9 71.9 42.0 42.0 19.7 17.6 3.8 - 1.1 0.0

205.8 206.1 137.2 137.4 - - 2.3 2.0 4.0 0.0

SUMMER - Sutherland Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 19.7 20.1 22.0 21.7 23.0 23.1 23.3 23.6 Caringbah 33/11kV ZSPF 0.89 0.89 0.93 0.93 0.93 0.93 0.93 0.93 Caringbah 33/11kV ZSMVA 40.5 39.8 49.3 43.9 45.4 45.7 46.4 47.4 Cronulla 132/11kV ZSPF 0.97 0.96 0.98 0.98 0.98 0.98 0.98 1.0 Cronulla 132/11kV ZSMVA - - - 23.9 23.9 24.0 24.3 24.8 Engadine 132/11kV ZSPF - - - 0.90 0.90 0.90 0.90 0.90 Engadine 132/11kV ZSMVA 23.9 23.2 28.3 - - - - - Engadine 33/11kV ZSPF 0.96 0.97 0.90 - - - - - Engadine 33/11kV ZSMVA 26.9 26.8 35.8 32.4 33.3 34.0 34.5 34.9 Gwawley Bay 132/11kV ZSPF 0.90 0.95 0.96 0.96 0.96 0.96 0.96 0.96 Gwawley Bay 132/11kV ZSMVA - - - - - - - - Gwawley Bay 33/11kV ZSPF - - - - - - - - Gwawley Bay 33/11kV ZSMVA 23.7 21.8 32.7 26.3 26.6 27.0 27.5 28.0 Jannali 33/11kV ZSPF 0.94 0.94 1.00 1.00 1.00 1.00 1.00 1.00 Jannali 33/11kV ZSMVA 29.6 29.1 36.1 33.3 34.1 34.8 35.5 36.2 Kirrawee 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Kirrawee 132/11kV ZSMVA 42.6 29.2 - - - - - - Kurnell 132/33kV STSPF 0.88 0.98 - - - - - - Kurnell 132/33kV STSMVA 16.2 4.9 - - - - - - Kurnell 33/11kV ZSPF 1.0 1.0 - - - - - - Kurnell 33/11kV ZSMVA 7.2 2.6 - - - - - - Kurnell 33/6.3kV ZSPF 0.86 0.86 - - - - - - Kurnell 33/6.3kV ZSMVA - - 6.6 6.4 6.4 6.4 6.5 6.6 Kurnell South 132/11kV ZSPF - - 0.90 0.90 0.90 0.90 0.90 0.9 Kurnell South 132/11kV ZSMVA 7.4 7.9 8.5 8.4 8.4 8.4 8.4 8.5 Lucas Heights 33/11kV ZSPF 0.91 0.91 0.91 0.91 0.91 0.91 0.91 0.91 Lucas Heights 33/11kV ZSMVA 38.6 35.8 44.7 40.2 40.4 40.7 41.2 41.8 Menai 132/11kV ZSPF 0.96 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Menai 132/11kV ZSMVA 26.5 26.1 33.0 30.5 30.0 29.8 30.0 30.4 Miranda 33/11kV ZSPF 0.94 0.93 0.95 0.95 0.95 0.95 0.95 0.95 Miranda 33/11kV ZSMVA 78.0 74.3 122.2 88.6 88.4 88.6 89.3 90.3 Port Hacking 132/33kV STSPF 0.94 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Port Hacking 132/33kV STS

WINTER - Sutherland Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 18.4 18.3 20.6 18.7 19.9 20.1 20.3 20.7 Caringbah 33/11kV ZSPF 0.93 0.91 0.91 0.91 0.91 0.91 0.91 0.91 Caringbah 33/11kV ZSMVA 56.3 55.2 57.0 57.0 58.6 58.9 59.4 60.6 Cronulla 132/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 1.0 1.0 1.0 Cronulla 132/11kV ZSMVA - - - - 29.1 29.3 29.7 30.3 Engadine 132/11kV ZSPF - - - - 0.90 0.90 0.90 0.90 Engadine 132/11kV ZSMVA 27.5 28.2 29.9 28.9 - - - - Engadine 33/11kV ZSPF 0.98 0.98 0.90 0.90 - - - - Engadine 33/11kV ZSMVA 25.2 25.1 27.6 26.7 26.6 26.8 27.1 27.6 Gwawley Bay 132/11kV ZSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Gwawley Bay 132/11kV ZSMVA - - - - - - - - Gwawley Bay 33/11kV ZSPF - - - - - - - - Gwawley Bay 33/11kV ZSMVA 28.2 29.3 32.5 31.4 31.6 31.9 32.4 33.1 Jannali 33/11kV ZSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 Jannali 33/11kV ZSMVA 36.3 37.1 39.3 38.4 38.1 38.2 38.7 39.5 Kirrawee 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.9 0.9 0.9 Kirrawee 132/11kV ZSMVA 40.8 47.2 26.8 - - - - - Kurnell 132/33kV STSPF 0.93 0.90 0.91 - - - - - Kurnell 132/33kV STSMVA 14.8 16.5 - - - - - - Kurnell 33/11kV ZSPF 0.92 0.92 - - - - - - Kurnell 33/11kV ZSMVA 8.2 9.1 - - - - - - Kurnell 33/6.3kV ZSPF 0.86 0.85 - - - - - - Kurnell 33/6.3kV ZSMVA - - 7.2 7.1 7.1 7.1 7.1 7.2 Kurnell South 132/11kV ZSPF - - 0.90 0.90 0.90 0.90 0.90 0.90 Kurnell South 132/11kV ZSMVA 6.2 6.5 7.3 7.2 7.2 7.2 7.2 7.2 Lucas Heights 33/11kV ZSPF 0.92 0.92 0.97 0.97 0.97 0.97 0.97 0.97 Lucas Heights 33/11kV ZSMVA 41.1 - 40.8 39.8 39.2 39.0 39.3 40.0 Menai 132/11kV ZSPF 0.97 - 0.99 0.99 0.99 1.0 1.0 1.0 Menai 132/11kV ZSMVA 25.8 25.2 29.4 29.5 29.4 29.6 29.9 30.4 Miranda 33/11kV ZSPF 0.97 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Miranda 33/11kV ZSMVA 79.7 81.9 102.1 111.5 84.3 84.7 85.6 86.8 Port Hacking 132/33kV STSPF 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Port Hacking 132/33kV STS

Miranda 33/11kV ZS

Port Hacking 132/33kV STS

Kirrawee 132/11kV ZS

Kurnell 132/33kV STS

Kurnell 33/11kV ZS

Kurnell 33/6.3kV ZS

Kurnell South 132/11kV ZS

Lucas Heights 33/11kV ZS

Caringbah 33/11kV ZS

Cronulla 132/11kV ZS

Engadine 132/11kV ZS

Menai 132/11kV ZS

Engadine 33/11kV ZS

Gwawley Bay 132/11kV ZS

Gwawley Bay 33/11kV ZS

Jannali 33/11kV ZS

Port Hacking 132/33kV STS

Substation

Actual Load Forecast Load

Caringbah 33/11kV ZS

Cronulla 132/11kV ZS

Miranda 33/11kV ZS

Engadine 33/11kV ZS

Gwawley Bay 132/11kV ZS

Gwawley Bay 33/11kV ZS

Jannali 33/11kV ZS

Kirrawee 132/11kV ZS

Kurnell 132/33kV STS

Kurnell 33/11kV ZS

Kurnell 33/6.3kV ZS

Forecast Load

Kurnell South 132/11kV ZS

Lucas Heights 33/11kV ZS

Menai 132/11kV ZS

Engadine 132/11kV ZS

Substation

Kurnell South 132/11kV ZS

Lucas Heights 33/11kV ZS

Menai 132/11kV ZS

Miranda 33/11kV ZS

Port Hacking 132/33kV STS

Kurnell South 132/11kV ZS

Caringbah 33/11kV ZS

Cronulla 132/11kV ZS

Engadine 132/11kV ZS

Engadine 33/11kV ZS

Gwawley Bay 132/11kV ZS

Gwawley Bay 33/11kV ZS

Jannali 33/11kV ZS

Kirrawee 132/11kV ZS

Kurnell 132/33kV STS

Kurnell 33/11kV ZS

Kurnell 33/6.3kV ZS

Sutherland Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C22 of C27

Sydney CBD

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

188.5 - 125.6 - 0.0 0.0 - - 0.0

254.4 254.4 128.0 130.0 44.4 53.3 - - 0.2 1.5

- - - - 0.0 0.0 - - 0.0

103.7 107.4 70.7 74.5 6.6 8.0 - - 0.0 0.4

213.7 213.7 112.0 112.0 21.8 26.1 - - 0.0 1.2

- - - - 0.0 0.0 - - 0.0

200.0 200.0 130.3 130.3 49.8 59.7 - - 4.4

243.2 258.0 123.6 130.0 24.6 29.6 - - 0.1 1.6

SUMMER - Sydney CBD Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA - - - - - - - - Belmore Park 132/11kV ZSPF - - - - - - - - Belmore Park 132/11kV ZSMVA 120.6 115.8 117.3 118.5 117.0 114.6 115.4 115.4 City Central 132/11kV ZSPF 0.93 0.95 0.92 0.93 0.94 0.94 0.93 0.9 City Central 132/11kV ZSMVA - - - - - - - - City East 132/11kV ZSPF - - - - - - - - City East 132/11kV ZSMVA 39.29 40.72 39.25 35.27 34.13 33.46 33.31 33.66 City East 33/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 City East 33/11kV ZSMVA 55.00 65.39 70.17 78.76 79.29 78.69 78.34 79.17 City North 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 City North 132/11kV ZSMVA - - - - - - - - City North 33/11kV ZSPF - - - - - - - - City North 33/11kV ZSMVA 127.39 126.05 133.56 126.20 124.59 122.46 122.01 123.5 City South 132/11kV ZSPF 1.0 1.0 1.0 1.0 0.9 0.9 0.9 0.9 City South 132/11kV ZSMVA 107.78 107.53 107.53 82.48 80.09 78.47 78.27 79.22 Dalley St 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 Dalley St 132/11kV ZS

WINTER - Sydney CBD Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA - - - - - - - - Belmore Park 132/11kV ZSPF - - - - - - - - Belmore Park 132/11kV ZSMVA 109.5 101.7 90.7 95.9 94.2 92.3 91.8 92.8 City Central 132/11kV ZSPF 0.94 0.95 0.95 0.95 0.95 1.0 1.0 1.0 City Central 132/11kV ZSMVA - - - - - - - - City East 132/11kV ZSPF - - - - - - - - City East 132/11kV ZSMVA 35.82 33.08 30.98 28.22 27.24 26.67 26.47 26.73 City East 33/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 City East 33/11kV ZSMVA 49.10 48.22 53.50 59.96 64.15 63.62 63.27 63.95 City North 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 City North 132/11kV ZSMVA - - - - - - - - City North 33/11kV ZSPF - - - - - - - - City North 33/11kV ZSMVA 112.87 106.94 104.48 100.99 98.69 97.90 97.39 97.59 City South 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 0.9 0.9 1.0 City South 132/11kV ZSMVA 102.2 88.8 90.2 64.8 62.71 61.34 60.92 61.65 Dalley St 132/11kV ZSPF 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 Dalley St 132/11kV ZS

Dalley St 132/11kV ZS

SubstationForecast Load

Belmore Park 132/11kV ZS

City Central 132/11kV ZS

City East 132/11kV ZS

City East 33/11kV ZS

City North 132/11kV ZS

City North 33/11kV ZS

City South 132/11kV ZS

Actual Load Forecast Load

Belmore Park 132/11kV ZS

City Central 132/11kV ZS

City East 33/11kV ZS

Substation

City North 132/11kV ZS

City North 33/11kV ZS

City South 132/11kV ZS

Dalley St 132/11kV ZS

City East 132/11kV ZS

City North 33/11kV ZS

City South 132/11kV ZS

Dalley St 132/11kV ZS

Sydney CBD Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Belmore Park 132/11kV ZS

City Central 132/11kV ZS

City East 132/11kV ZS

City East 33/11kV ZS

City North 132/11kV ZS

Page C23 of C27

Upper Central

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

125.9 130.0 63.3 65.0 11.1 8.3 3.3 - 4.6 0.0

76.2 76.2 38.1 38.1 5.6 5.2 5.8 - 2.9 0.1

- - - - 0.0 0.0 - - 0.0

- - - - - - - - 0.0 0.0

- - 64.0 69.0 - - - 7.3 2.6 0.0

47.4 52.6 34.4 37.5 13.1 13.3 4.5 7.0 2.7 0.0

30.5 30.5 15.2 15.2 0.0 0.0 - 2.8 0.0

110.3 115.2 54.0 58.8 10.6 8.0 2.5 - 3.9 2.2

SUMMER - Upper Central Coast Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 38.8 39.0 46.8 40.8 40.9 41.1 41.6 42.2 Charmhaven 132/11kV ZSPF 0.94 0.96 0.96 0.96 0.96 0.96 0.96 0.96 Charmhaven 132/11kV ZSMVA 14.9 15.9 19.3 23.8 23.9 24.1 24.4 24.8 Lake Munmorah 132/11kV ZSPF 0.98 0.90 0.90 0.91 0.91 0.91 0.91 0.9 Lake Munmorah 132/11kV ZSMVA - - - - - - - - Lake Munmorah 33/11kV ZSPF - - - - - - - - Lake Munmorah 33/11kV ZSMVA - - - - 22.4 22.4 22.4 22.4 Munmorah 132/33kV STSPF - - - - 0.90 0.90 0.90 0.90 Munmorah 132/33kV STSMVA 22.9 24.0 26.5 23.7 - - - - Munmorah 330/33kV STSPF 0.90 0.90 0.90 0.88 - - - - Munmorah 330/33kV STSMVA 18.0 17.0 22.0 19.4 19.2 19.2 19.3 19.5 Noraville 33/11kV ZSPF 0.93 0.94 0.94 0.94 0.94 0.94 0.94 0.9 Noraville 33/11kV ZSMVA 7.1 7.1 6.4 6.4 6.4 6.4 6.4 6.4 Vales Point 33/11kV ZSPF 0.83 0.85 0.85 0.85 0.85 0.85 0.85 0.85 Vales Point 33/11kV ZSMVA 31.1 31.7 37.4 36.9 37.6 38.3 39.0 39.7 Wyong 132/11kV ZSPF 0.94 0.94 0.95 0.95 0.95 0.95 0.95 0.95 Wyong 132/11kV ZS

WINTER - Upper Central Coast Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 32.6 32.9 34.9 37.1 34.6 35.3 36.1 36.9 Charmhaven 132/11kV ZSPF 0.90 0.90 0.99 0.99 0.99 0.99 0.99 0.99 Charmhaven 132/11kV ZSMVA 16.2 16.3 17.9 18.1 21.2 21.4 21.7 22.2 Lake Munmorah 132/11kV ZSPF 0.99 0.90 0.90 0.90 0.92 0.9 0.9 0.9 Lake Munmorah 132/11kV ZSMVA - - - - - - - - Lake Munmorah 33/11kV ZSPF - - - - - - - - Lake Munmorah 33/11kV ZSMVA - - - - 29.6 29.6 29.6 29.6 Munmorah 132/33kV STSPF - - - - 0.90 0.90 0.90 0.90 Munmorah 132/33kV STSMVA 25.1 27.5 28.9 30.8 - - - - Munmorah 330/33kV STSPF 0.90 0.90 0.90 0.91 - - - - Munmorah 330/33kV STSMVA 20.8 20.8 22.2 23.4 23.3 23.5 23.7 24.1 Noraville 33/11kV ZSPF 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Noraville 33/11kV ZSMVA 6.8 7.9 7.4 7.4 7.4 7.4 7.4 7.4 Vales Point 33/11kV ZSPF 0.6 0.8 0.8 0.8 0.83 0.83 0.83 0.83 Vales Point 33/11kV ZSMVA 26.3 26.7 28.0 28.5 28.6 29.0 29.7 30.7 Wyong 132/11kV ZSPF 0.97 0.90 0.97 0.97 0.97 1.0 1.0 1.0 Wyong 132/11kV ZS

Wyong 132/11kV ZS

SubstationForecast Load

Charmhaven 132/11kV ZS

Lake Munmorah 132/11kV ZS

Lake Munmorah 33/11kV ZS

Munmorah 132/33kV STS

Munmorah 330/33kV STS

Noraville 33/11kV ZS

Vales Point 33/11kV ZS

Actual Load Forecast Load

Charmhaven 132/11kV ZS

Lake Munmorah 132/11kV ZS

Munmorah 132/33kV STS

Substation

Munmorah 330/33kV STS

Noraville 33/11kV ZS

Vales Point 33/11kV ZS

Wyong 132/11kV ZS

Lake Munmorah 33/11kV ZS

Noraville 33/11kV ZS

Vales Point 33/11kV ZS

Wyong 132/11kV ZS

Upper Central Coast Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Charmhaven 132/11kV ZS

Lake Munmorah 132/11kV ZS

Lake Munmorah 33/11kV ZS

Munmorah 132/33kV STS

Munmorah 330/33kV STS

Page C24 of C27

Upper Hunter

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

- - - - 0.0 0.0 - - 0.0

46.4 46.4 25.5 25.5 5.2 3.8 6.0 - 0.5 0.0

2.4 2.7 0.0 0.0 0.3 0.2 3.3 - 0.1 0.0

32.4 35.6 13.4 14.7 4.9 3.7 4.3 - 0.8 0.0

6.9 7.6 0.0 0.0 0.4 0.3 3.0 - 0.4 0.0

277.3 299.3 141.3 149.6 - - 5.0 0.5 3.6 0.0

29.0 30.5 24.0 26.4 8.9 7.5 6.0 - 0.6 0.0

6.9 7.6 2.9 3.1 1.1 1.1 0.8 1.8 0.1 0.0

69.3 79.5 47.1 50.9 - - 3.3 - 1.1 0.0

47.6 47.6 23.8 23.8 10.9 9.3 4.0 - 1.1 0.0

- - - - 0.0 0.0 - - 0.0

- - - - - - - - 0.0 0.0

5.8 6.3 0.0 0.0 0.0 0.0 5.8 - 0.1 5.8

- - - - 0.0 0.0 - - 0.0

66.0 66.0 38.0 38.0 9.2 8.1 7.0 - 1.4 0.0

SUMMER - Upper Hunter Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 2.5 - - - - - - - Aberdeen 33/11kV ZSPF 0.92 - - - - - - - Aberdeen 33/11kV ZSMVA 0.9 5.2 5.2 5.9 5.9 5.9 6.0 6.1 Aberdeen 66/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.9 Aberdeen 66/11kV ZSMVA 1.0 0.9 0.8 0.8 0.8 0.8 0.8 0.8 Baerami 33/11kV ZSPF 0.94 0.95 0.97 0.97 0.97 0.97 0.97 0.97 Baerami 33/11kV ZSMVA 6.5 6.0 5.3 5.4 5.4 5.4 5.5 5.5 Denman 66/11kV ZSPF 0.93 0.94 0.95 1.00 1.00 1.00 1.00 1.00 Denman 66/11kV ZSMVA 3.5 3.4 3.2 3.3 3.3 3.2 3.3 3.3 Merriwa 33/11kV ZSPF 0.96 0.97 0.97 0.97 0.97 0.97 0.97 0.97 Merriwa 33/11kV ZSMVA 72.5 78.3 73.6 80.9 81.2 81.6 82.0 82.5 Mitchell Line 132/66kV STSPF 0.92 0.94 0.95 0.95 0.95 0.95 0.95 1.0 Mitchell Line 132/66kV STSMVA 11.7 11.3 10.3 12.1 12.0 12.0 12.1 12.2 Mitchell Line 66/11kV ZSPF 0.93 0.94 0.97 0.97 0.97 0.97 0.97 0.97 Mitchell Line 66/11kV ZSMVA 0.9 0.9 1.1 0.9 0.9 0.9 0.9 0.9 Moonan 33/11kV ZSPF 0.94 0.95 0.95 0.95 0.95 0.95 0.95 0.95 Moonan 33/11kV ZSMVA 20.7 16.1 17.0 15.9 16.2 16.5 16.7 16.9 Muswellbrook 132/33kV STSPF 0.74 1.00 0.83 0.84 0.84 0.84 0.84 0.84 Muswellbrook 132/33kV STSMVA 13.5 12.9 14.2 14.1 14.4 14.7 14.9 15.1 Muswellbrook 33/11kV ZSPF 0.9 0.9 0.9 1.0 0.9 0.9 0.95 0.94 Muswellbrook 33/11kV ZSMVA - - - - - - - - Muswellbrook North 132/11kVPF - - - - - - - - Muswellbrook North 132/11kVMVA - - - - - - - - Muswellbrook North 132/33kVPF - - - - - - - - Muswellbrook North 132/33kVMVA 1.2 1.2 1.3 1.3 1.3 1.3 1.3 1.3 Rouchel 33/11kV ZSPF 0.92 0.92 0.92 0.92 0.92 0.92 0.92 0.92 Rouchel 33/11kV ZSMVA - - - - - - - - Scone 33/11kV ZSPF - - - - - - - - Scone 33/11kV ZSMVA 15.6 15.2 14.8 17.2 17.7 18.1 18.3 18.5 Scone 66/11kV ZSPF 0.99 0.99 0.99 1.00 1.00 1.00 1.00 1.00 Scone 66/11kV ZS

WINTER - Upper Hunter Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 1.9 2.0 - - - - - - Aberdeen 33/11kV ZSPF 0.95 0.95 - - - - - - Aberdeen 33/11kV ZSMVA - 4.1 3.8 3.9 3.9 3.9 3.9 4.0 Aberdeen 66/11kV ZSPF - 0.90 0.90 0.90 0.90 0.9 0.9 0.9 Aberdeen 66/11kV ZSMVA 0.7 0.6 0.6 0.5 0.5 0.5 0.5 0.5 Baerami 33/11kV ZSPF 0.92 0.96 0.95 0.95 0.95 0.95 0.95 0.95 Baerami 33/11kV ZSMVA 4.5 4.4 4.0 3.8 3.8 3.8 3.9 3.9 Denman 66/11kV ZSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Denman 66/11kV ZSMVA 2.9 3.0 2.9 2.7 2.6 2.6 2.6 2.6 Merriwa 33/11kV ZSPF 0.98 0.98 1.00 1.00 1.00 1.00 1.00 1.00 Merriwa 33/11kV ZSMVA 64.7 69.5 72.2 70.7 71.7 71.7 72.0 72.5 Mitchell Line 132/66kV STSPF 0.95 0.94 0.95 0.95 0.95 0.95 0.95 0.95 Mitchell Line 132/66kV STSMVA 8.7 9.1 8.7 8.2 7.9 7.8 7.9 8.0 Mitchell Line 66/11kV ZSPF 1.0 1.0 1.0 1.0 0.99 0.99 0.99 0.99 Mitchell Line 66/11kV ZSMVA 1.0 1.0 1.1 1.1 1.1 1.1 1.1 1.1 Moonan 33/11kV ZSPF 0.99 0.99 0.99 0.99 0.99 1.0 1.0 1.0 Moonan 33/11kV ZSMVA 16.6 16.9 14.4 14.4 13.1 13.0 13.1 13.4 Muswellbrook 132/33kV STSPF 0.97 0.77 0.99 0.99 0.99 0.99 0.99 0.99 Muswellbrook 132/33kV STSMVA 10.8 11.0 12.0 10.5 11.6 11.5 10.5 10.7 Muswellbrook 33/11kV ZSPF 0.90 0.90 0.90 1.00 0.90 0.90 1.00 1.00 Muswellbrook 33/11kV ZSMVA - - - - - - - - Muswellbrook North 132/11kVPF - - - - - - - - Muswellbrook North 132/11kVMVA - - - - - - - - Muswellbrook North 132/33kVPF - - - - - - - - Muswellbrook North 132/33kVMVA 1.0 0.9 0.8 0.8 0.8 0.8 0.9 0.9 Rouchel 33/11kV ZSPF 0.91 0.94 0.96 0.96 0.96 0.96 0.96 0.96 Rouchel 33/11kV ZSMVA - - - - - - - - Scone 33/11kV ZSPF - - - - - - - - Scone 33/11kV ZSMVA 12.4 12.6 12.9 12.7 12.7 12.8 13.0 13.2 Scone 66/11kV ZSPF 0.98 0.97 0.98 1.00 1.00 1.00 1.00 1.00 Scone 66/11kV ZS

Rouchel 33/11kV ZS

Scone 33/11kV ZS

Scone 66/11kV ZS

Moonan 33/11kV ZS

Substation

Merriwa 33/11kV ZS

Mitchell Line 132/66kV STS

Mitchell Line 66/11kV ZS

Muswellbrook 132/33kV STS

Muswellbrook 33/11kV ZS

Muswellbrook North 132/11kV ZS

Muswellbrook North 132/33kV STS

Forecast Load

Aberdeen 33/11kV ZS

Aberdeen 66/11kV ZS

Baerami 33/11kV ZS

Denman 66/11kV ZS

Actual Load Forecast Load

Aberdeen 33/11kV ZS

Aberdeen 66/11kV ZS

Scone 66/11kV ZS

Denman 66/11kV ZS

Merriwa 33/11kV ZS

Mitchell Line 132/66kV STS

Mitchell Line 66/11kV ZS

Moonan 33/11kV ZS

Muswellbrook 132/33kV STS

Muswellbrook 33/11kV ZS

Muswellbrook North 132/11kV ZS

Muswellbrook North 132/33kV STS

Rouchel 33/11kV ZS

Scone 33/11kV ZS

Baerami 33/11kV ZS

Substation

Rouchel 33/11kV ZS

Scone 33/11kV ZS

Scone 66/11kV ZS

Muswellbrook North 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 132/66kV STS

Mitchell Line 66/11kV ZS

Moonan 33/11kV ZS

Muswellbrook 132/33kV STS

Muswellbrook 33/11kV ZS

Muswellbrook North 132/11kV ZS

Upper Hunter Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C25 of C27

Upper North Sh

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

349.8 349.8 261.0 272.1 - - 0.3 6.8 6.8 0.0

65.1 70.8 36.8 40.5 16.6 18.6 - 5.3 1.5 0.0

67.7 67.7 38.9 40.9 20.1 19.4 2.3 1.3 1.4 0.1

101.4 108.0 58.5 63.7 17.8 17.0 2.8 0.8 2.4 0.0

66.1 72.3 43.3 44.8 27.7 29.4 - 5.8 1.7 0.0

SUMMER - Upper North Shore Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 118.0 117.7 140.9 135.1 134.8 135.4 137.0 139.4 Kuring-gai 132/33kV STSPF 0.95 0.96 0.93 0.93 0.93 0.93 0.93 0.93 Kuring-gai 132/33kV STSMVA 25.4 25.2 29.1 28.8 28.6 28.7 29.0 29.6 Lindfield 33/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.9 Lindfield 33/11kV ZSMVA 29.7 28.9 35.4 33.0 33.5 34.1 34.6 35.1 Pymble 33/11kV ZSPF 0.92 0.91 0.91 0.91 0.91 0.91 0.91 0.91 Pymble 33/11kV ZSMVA 38.5 38.1 46.3 41.5 41.0 40.9 41.2 42.0 St Ives 33/11kV ZSPF 0.89 0.89 0.97 0.97 0.97 0.97 0.97 0.97 St Ives 33/11kV ZSMVA 28.8 27.9 32.3 31.7 31.6 31.7 32.0 32.7 Turramurra 33/11kV ZSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Turramurra 33/11kV ZS

WINTER - Upper North Shore Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 130.4 142.2 144.3 144.7 144.0 144.8 146.7 149.6 Kuring-gai 132/33kV STSPF 0.96 0.96 0.95 0.95 0.96 0.96 0.96 0.96 Kuring-gai 132/33kV STSMVA 30.2 30.2 32.6 32.6 32.2 32.3 32.6 33.4 Lindfield 33/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.9 0.9 0.9 Lindfield 33/11kV ZSMVA 28.4 29.9 34.3 31.9 32.0 32.2 32.7 33.3 Pymble 33/11kV ZSPF 0.93 0.92 0.97 0.97 0.97 0.97 0.97 0.97 Pymble 33/11kV ZSMVA 41.7 42.2 44.1 43.9 43.9 44.2 44.8 45.7 St Ives 33/11kV ZSPF 0.94 0.94 0.96 0.96 0.96 0.96 0.96 0.96 St Ives 33/11kV ZSMVA 31.4 34.6 34.3 33.6 33.7 34.0 34.4 35.1 Turramurra 33/11kV ZSPF 0.98 0.99 0.99 0.99 0.99 0.99 0.99 0.99 Turramurra 33/11kV ZS

St Ives 33/11kV ZS

Turramurra 33/11kV ZS

Actual Load Forecast Load

Kuring-gai 132/33kV STS

Lindfield 33/11kV ZS

St Ives 33/11kV ZS

Turramurra 33/11kV ZS

Pymble 33/11kV ZS

Substation

SubstationForecast Load

Kuring-gai 132/33kV STS

Lindfield 33/11kV ZS

Pymble 33/11kV ZS

Kuring-gai 132/33kV STS

Lindfield 33/11kV ZS

Pymble 33/11kV ZS

St Ives 33/11kV ZS

Turramurra 33/11kV ZS

Upper North Shore Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Page C26 of C27

West Lake Mac

Summer Winter Summer Winter Summer Winter Summer Winter Solar PV Other

45.7 45.7 22.9 22.9 10.8 9.2 5.0 - 1.6 0.0

134.3 134.3 69.5 73.5 - - 1.0 20.3 1.5 0.0

76.2 76.2 38.1 38.1 6.6 5.1 2.0 - 2.5 0.0

- - - - - - - - 0.0 0.0

- - - - 0.0 0.0 - - 0.0

- - - - 0.0 0.0 - - 0.0

76.2 76.2 38.1 38.1 8.0 6.5 2.3 - 2.4 1.1

37.7 37.7 18.9 18.9 3.3 2.6 5.8 - 1.2 0.0

- - - - 0.0 0.0 - - 0.0

SUMMER - West Lake Macquarie Area STS and ZS Load Forecast

2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21MVA 9.5 8.4 10.8 11.2 11.5 11.7 12.0 12.1 Avondale 33/11kV ZSPF 0.95 0.97 0.98 0.98 0.98 0.98 0.98 0.98 Avondale 33/11kV ZSMVA 28.3 30.5 30.0 30.3 30.5 30.8 31.0 31.1 Eraring 132/33kV STSPF 0.94 0.91 0.93 0.93 0.93 0.93 0.93 0.9 Eraring 132/33kV STSMVA 18.0 19.3 23.5 22.8 23.4 23.9 24.3 24.5 Morisset 132/11kV ZSPF 0.94 0.95 0.96 0.96 0.96 0.96 0.96 0.96 Morisset 132/11kV ZSMVA - - - - 10.2 10.2 10.2 10.2 Morisset 132/33kV STSPF - - - - 0.90 0.90 0.90 0.90 Morisset 132/33kV STSMVA - - - - - - - - Morisset 33/11kV Temp ZSPF - - - - - - - - Morisset 33/11kV Temp ZSMVA - - - - - - - - Rathmines 132/11kV Temp ZSPF - - - - - - - - Rathmines 132/11kV Temp ZSMVA 14.5 12.9 16.7 14.2 14.1 14.1 14.2 14.4 Rathmines 132/11kV ZSPF 0.90 0.90 0.90 0.90 0.90 0.90 0.90 0.90 Rathmines 132/11kV ZSMVA 12.1 12.7 14.3 - - - - - Toronto 33/11kV ZSPF 0.95 0.96 0.96 - - - - - Toronto 33/11kV ZSMVA - - - 21.6 21.6 21.6 21.7 21.8 Toronto West 132/11kV ZSPF - - - 0.95 0.95 0.95 0.95 0.95 Toronto West 132/11kV ZS

WINTER - West Lake Macquarie Area STS and ZS Load ForecastActual Load

2012 2013 2014 2015 2016 2017 2018 2019MVA 8.9 9.3 9.2 9.5 9.5 9.5 9.7 9.9 Avondale 33/11kV ZSPF 0.98 0.98 0.99 0.99 0.99 0.99 0.99 0.99 Avondale 33/11kV ZSMVA 28.9 30.7 30.7 30.7 30.7 30.7 30.8 31.1 Eraring 132/33kV STSPF 0.93 0.89 0.92 0.92 0.92 0.9 0.9 0.9 Eraring 132/33kV STSMVA 17.4 17.9 18.4 17.8 17.4 17.2 17.4 17.7 Morisset 132/11kV ZSPF 0.97 0.98 0.98 0.98 0.98 0.98 0.98 0.98 Morisset 132/11kV ZSMVA - - - - - 10.5 10.5 10.5 Morisset 132/33kV STSPF - - - - - 0.90 0.90 0.90 Morisset 132/33kV STSMVA - - - - - - - - Morisset 33/11kV Temp ZSPF - - - - - - - - Morisset 33/11kV Temp ZSMVA - - - - - - - - Rathmines 132/11kV Temp ZSPF - - - - - - - - Rathmines 132/11kV Temp ZSMVA 13.6 12.9 13.5 12.7 10.7 10.6 10.6 10.9 Rathmines 132/11kV ZSPF 0.9 0.9 0.9 0.9 0.90 0.90 0.90 0.90 Rathmines 132/11kV ZSMVA 11.0 10.6 11.5 11.1 - - - - Toronto 33/11kV ZSPF 0.97 0.98 0.98 0.98 - - - - Toronto 33/11kV ZSMVA - - - - 16.7 16.8 16.9 17.1 Toronto West 132/11kV ZSPF - - - - 0.97 0.97 0.97 0.97 Toronto West 132/11kV ZS

Toronto West 132/11kV ZS

Toronto 33/11kV ZS

SubstationForecast Load

Avondale 33/11kV ZS

Eraring 132/33kV STS

Morisset 132/11kV ZS

Morisset 132/33kV STS

Morisset 33/11kV Temp ZS

Rathmines 132/11kV Temp ZS

Rathmines 132/11kV ZS

Actual Load Forecast Load

Avondale 33/11kV ZS

Eraring 132/33kV STS

Morisset 132/33kV STS

Morisset 132/11kV ZS

Substation

Morisset 33/11kV Temp ZS

Rathmines 132/11kV Temp ZS

Rathmines 132/11kV ZS

Toronto 33/11kV ZS

Toronto West 132/11kV ZS

Rathmines 132/11kV Temp ZS

Rathmines 132/11kV ZS

Toronto 33/11kV ZS

Toronto West 132/11kV ZS

West Lake Macquarie Area - STS and ZS details

Embedded Generation (MW)

Substation

Total Capacity (MVA) Firm Capacity (MVA)Load Transfer Capacity

(MVA)95% Peak Load Exceeded

(hrs/yr)

Avondale 33/11kV ZS

Eraring 132/33kV STS

Morisset 132/11kV ZS

Morisset 132/33kV STS

Morisset 33/11kV Temp ZS

Page C27 of C27

December 2016

Annexure D – Feeder Load Forecast

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 13.3 14.3 15.3 16.8 16.8 13.0 14.0 15.0 16.0 17.4

Rating 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5

Load 13.3 14.3 15.3 16.8 16.8 13.0 14.0 15.0 16.0 17.4

Rating 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5

Load 13.3 14.3 15.3 16.8 16.8 13.0 14.0 15.0 16.0 17.4

Rating 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5

Load 6.3 6.3 6.0 6.0 6.4 5.5 5.5 5.7 5.8 6.0

Rating 17.0 17.0 17.0 17.0 17.0 18.4 18.4 18.4 18.4 18.4

Load 6.5 6.3 6.2 6.2 6.4 5.7 5.6 5.7 5.8 6.0

Rating 18.6 18.6 18.6 18.6 18.6 20.2 20.2 20.2 20.2 20.2

Load 6.5 6.3 6.2 6.2 6.4 5.7 5.6 5.7 5.8 6.0

Rating 18.8 18.8 18.8 18.8 18.8 20.5 20.5 20.5 20.5 20.5

Load 6.5 6.3 6.2 6.2 6.4 5.7 5.6 5.7 5.8 6.0

Rating 15.3 15.3 15.3 15.3 15.3 17.0 17.0 17.0 17.0 17.0

Load 10.1 11.3 11.3 11.5 11.7 6.8 10.9 11.1 11.2 11.5

Rating 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0

Load 10.1 11.3 11.3 11.5 11.7 6.7 10.9 11.0 11.2 11.5

Rating 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0

Load 10.2 11.3 11.4 11.5 11.7 6.8 10.9 11.1 11.3 11.5

Rating 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Feeder 583 (Pyrmont STS to Camperdown ZS T5) 33

Feeder 561 (Pyrmont STS to Blackwattle Bay ZS T4) 33

Feeder 581 (Pyrmont STS to Camperdown ZS T3) 33

Feeder 582 (Pyrmont STS to Camperdown ZS T4) 33

Feeder 527 (Pyrmont STS to Blackwattle Bay ZS T1) 33

Feeder 559 (Pyrmont STS to Blackwattle Bay ZS T2) 33

Feeder 560 (Pyrmont STS to Blackwattle Bay ZS T3) 33

Feeder 490 (Pyrmont STS to Global Switch) 33

Feeder 491 (Pyrmont STS to Global Switch) 33

Feeder 592 (Pyrmont STS to Global Switch) 33

Camperdown-Blackwattle Bay Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D1 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 6.5 6.7 6.9 7.0 7.2 6.0 6.0 6.1 6.2 6.3

Rating 16.4 16.4 16.4 16.4 16.4 17.3 17.3 17.3 17.3 17.3

Load 12.8 13.3 13.7 14.2 14.5 12.5 12.5 12.7 12.9 13.2

Rating 16.4 16.4 16.4 16.4 16.4 17.3 17.3 17.3 17.3 17.3

Load 9.0 9.3 9.5 9.7 9.9 9.8 9.8 9.9 10.1 10.3

Rating 16.4 16.4 16.4 16.4 16.4 17.3 17.3 17.3 17.3 17.3

Load 23.6 30.5 31.2 32.0 32.3 21.8 27.3 27.2 27.5 28.1

Rating 32.1 32.1 32.1 32.1 32.1 33.8 33.8 33.8 33.8 33.8

Load 22.8 23.9 24.4 24.8 25.2 21.1 21.4 21.3 21.6 22.0

Rating 32.1 32.1 32.1 32.1 32.1 33.8 33.8 33.8 33.8 33.8

Load 16.9 17.9 18.3 18.6 18.9 15.7 16.1 16.0 16.2 16.5

Rating 32.1 32.1 32.1 32.1 32.1 33.8 33.8 33.8 33.8 33.8

Load 11.8 15.4 15.8 16.1 16.3 10.9 13.8 13.8 13.9 14.2

Rating 16.5 16.5 16.5 16.5 16.5 18.5 18.5 18.5 18.5 18.5

Load 11.8 15.4 15.8 16.1 16.3 10.9 13.8 13.8 13.9 14.2

Rating 16.5 16.5 16.5 16.5 16.5 18.5 18.5 18.5 18.5 18.5

Load 12.3 13.0 13.5 13.9 14.2 14.8 15.5 15.9 16.3 16.7

Rating 18.5 18.5 18.5 18.5 18.5 20.0 20.0 20.0 20.0 20.0

Load 12.1 12.8 13.3 13.7 14.1 14.8 15.6 16.0 16.4 16.8

Rating 18.9 18.9 18.9 18.9 18.9 20.4 20.4 20.4 20.4 20.4

Load 12.3 13.0 13.5 13.8 14.1 14.8 15.4 15.9 16.3 16.6

Rating 18.9 18.9 18.9 18.9 18.9 20.4 20.4 20.4 20.4 20.4

Load 11.6 12.2 12.6 13.0 13.3 13.9 14.5 14.9 15.3 15.6

Rating 18.9 18.9 18.9 18.9 18.9 20.4 20.4 20.4 20.4 20.4

Load 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7

Rating 31.1 31.1 31.1 31.1 31.1 33.4 33.4 33.4 33.4 33.4

Load 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7

Rating 31.1 31.1 31.1 31.1 31.1 33.4 33.4 33.4 33.4 33.4

Load 24.5 25.3 25.8 26.1 26.8 18.4 18.5 18.7 19.0 19.5

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 24.5 25.5 26.1 26.1 26.9 18.5 18.6 18.8 19.1 19.6

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 9.1 9.2 - - - 8.2 8.2 8.2 - -

Rating 21.3 21.3 - - - 22.5 22.5 22.5 - -

Load 8.8 8.9 12.1 12.3 12.6 8.0 8.0 8.1 11.1 11.4

Rating 21.3 21.3 32.0 32.0 32.0 22.5 22.5 22.5 32.0 32.0

Load 8.8 8.9 12.2 12.4 12.7 8.0 8.0 8.1 11.1 11.5

Rating 21.3 21.3 32.0 32.0 32.0 22.5 22.5 22.5 32.0 32.0

Load 8.8 8.9 12.1 12.3 12.6 8.0 8.0 8.1 11.0 11.4

Rating 21.3 21.3 32.0 32.0 32.0 22.5 22.5 22.5 32.0 32.0

Load 8.8 8.9 12.3 12.5 12.8 8.0 8.0 8.1 11.2 11.5

Rating 21.3 21.3 32.0 32.0 32.0 22.5 22.5 22.5 32.0 32.0

Load 89.9 88.1 87.3 87.6 88.8 72.8 71.4 70.5 71.2 72.4

Rating 184.7 184.7 184.7 184.7 184.7 196.4 196.4 196.4 196.4 196.4

Load 47.4 45.5 44.4 44.1 44.4 34.6 33.4 32.8 32.8 33.3

Rating 143.1 143.1 143.1 143.1 143.1 152.0 152.0 152.0 152.0 152.0

Load 89.7 88.0 87.0 87.3 88.5 73.0 71.2 70.4 71.1 72.4

Rating 193.0 193.0 193.0 193.0 193.0 202.1 202.1 202.1 202.1 202.1

Load 47.4 45.5 44.3 43.9 44.3 34.6 33.4 32.8 33.0 33.3

Rating 155.5 155.5 155.5 155.5 155.5 164.6 164.6 164.6 164.6 164.6

Load 22.7 22.6 22.6 22.7 22.9 19.0 19.0 19.1 19.3 19.6

Rating 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9

Load 22.7 22.6 22.5 22.6 22.9 19.0 19.0 19.1 19.3 19.6

Rating 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9Feeder 736 (Guildford to Leightonfield ZS) 33

Feeder 283/1 (Sydney South BSP to Reversby ZS) 132

Feeder 283/2 (Revesby ZS to Milperra ZS) 132

Feeder 735 (Guildford to Leightonfield ZS) 33

Feeder 669 (Bankstown STS to Punchbowl ZS T5) 33

Feeder 282/1 (Sydney South BSP to Revesby ZS) 132

Feeder 282/2 (Revesby ZS to Milperra ZS) 132

Feeder 666 (Bankstown STS to Punchbowl ZS T2) 33

Feeder 667 (Bankstown STS to Punchbowl ZS T3) 33

Feeder 668 (Bankstown STS to Punchbowl ZS T4) 33

Feeder 661 (Bankstown STS to Bass Hill ZS) 33

Feeder 655 (Bankstown STS to Bass Hill ZS) 33

Feeder 665 (Bankstown STS to Punchbowl ZS T1) 33

Feeder 643 (Canterbury STS to Dulwich Hill ZS T4) 33

Feeder 632 (Canterbury STS to M5 Tunnel) 33

Feeder 633 (Canterbury STS to M5 Tunnel) 33

Feeder 636 (Canterbury STS to Dulwich Hill ZS T1) 33

Feeder 644 (Canterbury STS to Dulwich Hill ZS T2) 33

Feeder 645 (Canterbury STS to Dulwich Hill ZS T3) 33

Feeder 631 (Canterbury STS to Campsie ZS T4) 33

Feeder 634 (Canterbury STS to Campsie ZS T4) 33

Feeder 648 (Canterbury STS to Campsie ZS T1) 33

Feeder 649 (Canterbury STS to Campsie ZS T2) 33

Feeder 650 (Canterbury STS to Campsie ZS T3) 33

Feeder 639 (Canterbury STS to Enfield ZS T1) 33

Feeder 640 (Canterbury STS to Enfield ZS T2) 33

Feeder 641 (Canterbury STS to Enfield ZS T3) 33

Canterbury-Bankstown Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D2 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 60.6 60.7 61.8 63.1 64.4 48.6 48.8 50.0 51.1 52.4

Rating 79.0 79.0 79.0 79.0 79.0 83.4 83.4 83.4 83.4 83.4

Load 56.7 57.6 58.6 59.6 60.7 47.3 47.8 49.0 50.2 51.4

Rating 93.6 93.6 93.6 93.6 93.6 114.5 114.5 114.5 114.5 114.5

Load 60.5 60.7 61.8 63.0 64.4 48.6 48.8 50.0 51.2 52.3

Rating 90.2 90.2 90.2 90.2 90.2 91.4 91.4 91.4 91.4 91.4

Load 56.7 57.6 58.5 59.5 60.7 47.3 47.8 49.0 50.1 51.4

Rating 93.6 93.6 93.6 93.6 93.6 114.5 114.5 114.5 114.5 114.5Feeder 82C (Carlingford BSP to Hunters Hill ZS) 66

Feeder 813 (Carlingford BSP to Epping ZS) 66

Feeder 819 (Carlingford BSP to Hunters Hill ZS) 66

Feeder 820 (Carlingford BSP to Epping ZS) 66

Carlingford Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D3 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 57.0 63.8 64.8 65.9 67.2 51.4 55.5 59.3 60.6 61.9

Rating 111.0 111.0 111.0 111.0 111.0 118.0 118.0 118.0 118.0 118.0

Load 23.7 23.9 24.3 24.7 25.3 32.2 32.0 32.1 32.4 33.1

Rating 135.0 135.0 135.0 135.0 135.0 130.0 130.0 130.0 130.0 130.0

Load 88.8 96.2 97.6 99.4 101.3 93.6 98.1 102.1 104.0 106.2

Rating 111.0 111.0 111.0 111.0 111.0 118.0 118.0 118.0 118.0 118.0

Load 32.2 32.5 33.0 33.6 34.4 43.4 43.1 43.2 43.7 44.6

Rating 75.0 75.0 75.0 75.0 75.0 55.0 55.0 55.0 55.0 55.0

Load 58.3 58.9 59.7 60.9 62.4 79.4 78.9 79.1 80.1 81.7

Rating 179.5 179.5 179.5 179.5 179.5 182.9 182.9 182.9 182.9 182.9

Load 86.0 84.8 84.5 85.4 87.5 103.7 102.2 102.0 102.7 105.1

Rating 251.0 251.0 251.0 251.0 251.0 265.7 265.7 265.7 265.7 265.7

Load 85.9 84.6 84.3 85.2 87.3 103.6 102.1 101.8 102.5 105.0

Rating 140.6 140.6 140.6 140.6 140.6 149.8 149.8 149.8 149.8 149.8

Load 47.4 46.0 45.3 45.4 46.5 60.0 59.7 60.0 60.9 62.2

Rating 250.4 250.4 250.4 250.4 250.4 265.2 265.2 265.2 265.2 265.2

Load 5.9 6.0 6.1 6.3 6.4 6.8 7.0 7.2 7.3 7.5

Rating 17.4 17.4 17.4 17.4 17.4 18.0 18.0 18.0 18.0 18.0

Load 13.0 13.4 13.7 14.0 14.3 15.2 15.6 16.0 16.4 16.7

Rating 18.2 18.2 18.2 18.2 18.2 20.2 20.2 20.2 20.2 20.2

Load 10.8 11.0 11.3 11.5 11.8 12.5 12.9 13.2 13.5 13.8

Rating 18.0 18.0 18.0 18.0 18.0 19.0 19.0 19.0 19.0 19.0

Load 9.6 9.9 10.1 10.3 10.5 11.2 11.5 11.8 12.0 12.3

Rating 19.7 19.7 19.7 19.7 19.7 21.2 21.2 21.2 21.2 21.2

Load 10.5 11.4 11.8 12.0 12.1 8.3 9.7 10.3 10.6 10.7

Rating 17.6 17.6 17.6 17.6 17.6 19.2 19.2 19.2 19.2 19.2

Load 10.4 11.4 11.8 11.9 12.1 8.3 9.7 10.3 10.6 10.7

Rating 17.5 17.5 17.5 17.5 17.5 19.0 19.0 19.0 19.0 19.0

Load 9.1 9.1 9.1 9.1 9.1 6.5 6.5 6.5 6.5 6.5

Rating 15.0 15.0 15.0 15.0 15.0 16.9 16.9 16.9 16.9 16.9

Load 9.0 9.0 9.0 9.0 9.0 6.5 6.5 6.5 6.5 6.5

Rating 15.0 15.0 15.0 15.0 15.0 16.9 16.9 16.9 16.9 16.9

Load 10.4 11.4 11.8 12.0 12.1 8.3 9.7 10.3 10.6 10.7

Rating 16.2 16.2 16.2 16.2 16.2 17.5 17.5 17.5 17.5 17.5

Load 9.4 10.2 10.6 10.8 10.9 7.4 8.7 9.3 9.5 9.6

Rating 16.6 16.6 16.6 16.6 16.6 18.4 18.4 18.4 18.4 18.4

Load 3.3 3.3 3.3 3.3 3.3 2.3 2.3 2.3 2.3 2.3

Rating 29.7 29.7 29.7 29.7 29.7 31.5 31.5 31.5 31.5 31.5

Load 3.4 3.8 4.2 4.3 4.3 3.9 4.2 4.5 4.6 4.6

Rating 27.1 27.1 27.1 27.1 27.1 28.6 28.6 28.6 28.6 28.6

Load 8.5 8.7 8.9 9.1 9.3 9.9 10.2 10.4 10.6 10.9

Rating 15.1 15.1 15.1 15.1 15.1 17.7 17.7 17.7 17.7 17.7

Load 11.5 12.5 12.9 13.2 13.3 9.1 10.7 11.4 11.6 11.8

Rating 17.1 17.1 17.1 17.1 17.1 18.7 18.7 18.7 18.7 18.7

Load 16.7 16.7 16.7 16.7 16.7 12.1 12.1 12.1 12.1 12.1

Rating 16.4 16.4 16.4 16.4 16.4 17.8 17.8 17.8 17.8 17.8

Load 8.7 8.9 9.0 9.2 9.3 7.6 7.6 7.6 7.5 7.6

Rating 13.1 13.1 13.1 13.1 13.1 14.6 14.6 14.6 14.6 14.6

Load 3.4 3.8 4.2 4.3 4.3 3.9 4.2 4.5 4.6 4.6

Rating 27.1 27.1 27.1 27.1 27.1 28.6 28.6 28.6 28.6 28.6

Load 8.7 8.9 9.1 9.2 9.3 7.6 7.6 7.6 7.7 7.8

Rating 15.1 15.1 15.1 15.1 15.1 16.4 16.4 16.4 16.4 16.4

Load 7.9 8.1 8.3 8.4 8.5 6.9 6.9 6.9 7.0 7.1

Rating 16.2 16.2 16.2 16.2 16.2 17.6 17.6 17.6 17.6 17.6

Load 9.0 9.0 9.0 9.0 9.0 6.5 6.5 6.5 6.5 6.5

Rating 15.0 15.0 15.0 15.0 15.0 16.9 16.9 16.9 16.9 16.9

Load 8.3 8.4 8.6 8.7 8.8 7.2 7.2 7.2 7.3 7.4

Rating 17.3 17.4 17.3 17.3 17.3 19.1 19.1 19.1 19.1 19.1

Load 3.4 3.8 4.2 4.3 4.3 3.9 4.2 4.5 4.6 4.6

Rating 27.1 27.1 27.1 27.1 27.1 28.6 28.6 28.6 28.6 28.6

Load 14.3 14.3 14.3 14.3 14.3 13.8 13.8 13.8 13.8 13.8

Rating 58.9 58.9 58.9 58.9 58.9 62.5 62.5 62.5 62.5 62.5Feeder 355 (Bunnerong North STS to APM) 33

Feeder 352 (Bunnerong North STS to Sydney Airport) 33

Feeder 353 (Bunnerong North STS to Botany ZS T4) 33

Feeder 354 (Bunnerong North STS to Port Botany ZS T2) 33

Feeder 349 (Bunnerong North STS to Botany ZS T3) 33

Feeder 350 (Bunnerong North STS to Botany ZS T2) 33

Feeder 347 (Bunnerong North STS to Port Botany ZS ZS T1) 33

Feeder 341 (Bunnerong North STS to Mascot ZS T1) 33

Feeder 345 (Bunnerong North STS to Sydney Airport) 33

Feeder 346 (Bunnerong North STS to Botany ZS T1) 33

Feeder 338 (Sydney Airport to International Terminal ) 33

Feeder 339 (Bunnerong North STS to Port Botany ZS ZS T3) 33

Feeder 340 (Bunnerong North STS to Matraville ZS T5) 33

Feeder 337 (Bunnerong North STS to Mascot ZS T5) 33

Feeder 331 (1) (Bunnerong North STS to Sydney Airport) 33

Feeder 331 (2) (Bunnerong North STS to Sydney Airport) 33

Feeder 332 (Bunnerong North STS to Mascot ZS T2) 33

Feeder 324 (Bunnerong North STS to Matraville ZS T2) 33

Feeder 327 (Bunnerong North STS to Mascot ZS T4) 33

Feeder 328 (Bunnerong North STS to Mascot ZS T3) 33

Feeder 318 (Bunnerong North STS to Matraville ZS T4) 33

Feeder 313 (Bunnerong North STS to Matraville ZS T3) 33

Feeder 315 (1) (Bunnerong North STS to Matraville ZS T1) 33

Feeder 264 (Beaconsfield BSP to Kingsford ZS) 132

Feeder 265 (Bunnerong STSS to Maroubra ZS) 132

Feeder 270 (Kingsford ZS to Maroubra ZS) 132

Feeder 261/1 (Beaconsfield BSP to Zetland ZS) 132

Feeder 261/2 (Zetland ZS to Clovelly ZS) 132

Feeder 262 (Double Bay ZS to Clovelly ZS) 132

Feeder 260/1 (Beaconsfield BSP to Zetland ZS ZS) 132

Feeder 260/2 (Zetland ZS ZS to Clovelly ZS ZSZS) 132

Eastern Suburbs - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D4 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Eastern Suburbs - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 16.1 16.1 16.1 16.1 16.1 11.4 11.4 11.4 11.4 11.4

Rating 16.7 16.7 16.7 16.7 16.7 18.3 18.3 18.3 18.3 18.3

Load 14.5 14.5 14.5 14.5 14.5 14.0 14.0 14.0 14.0 14.0

Rating 59.0 59.0 59.0 59.0 59.0 62.5 62.5 62.5 62.5 62.5

Load 16.2 16.2 16.2 16.2 16.2 11.5 11.5 11.5 11.5 11.5

Rating 16.7 16.7 16.7 16.7 16.7 18.0 18.0 18.0 18.0 18.0

Load 11.5 12.5 12.9 13.2 13.3 9.1 10.7 11.4 11.6 11.8

Rating 17.7 17.7 17.7 17.7 17.7 19.2 19.2 19.2 19.2 19.2

Load 13.6 13.8 13.6 13.6 13.9 12.0 12.2 12.1 12.2 12.5

Rating 30.5 30.5 30.5 30.5 30.5 32.2 32.2 32.2 32.2 32.2

Load 14.4 14.4 14.4 14.4 14.4 8.9 8.9 8.9 8.9 8.9

Rating 17.0 17.0 17.0 17.0 17.0 18.4 18.4 18.4 18.4 18.4

Load 14.4 14.4 14.4 14.4 14.4 8.9 8.9 8.9 8.9 8.9

Rating 16.5 16.5 16.5 16.5 16.5 17.9 17.9 17.9 17.9 17.9

Load 11.2 11.3 11.5 11.7 12.0 11.1 11.1 11.2 11.4 11.7

Rating 29.7 29.7 29.7 29.7 29.7 32.0 32.0 32.0 32.0 32.0

Load 19.9 20.2 20.5 20.9 21.4 19.6 19.7 19.8 20.2 20.8

Rating 29.7 29.7 29.7 29.7 29.7 31.3 31.3 31.3 31.3 31.3

Load 16.6 16.8 17.1 17.4 17.9 16.4 16.5 16.6 16.9 17.4

Rating 29.7 29.7 29.7 29.7 29.7 31.3 31.3 31.3 31.3 31.3

Load 19.8 20.2 19.8 19.8 18.8 17.5 17.7 17.6 17.8 16.9

Rating 27.0 27.0 27.0 27.0 27.0 29.0 29.0 29.0 29.0 29.0

Load 12.2 12.4 12.2 12.2 12.5 10.8 11.0 10.9 11.0 11.2

Rating 30.5 30.5 30.5 30.5 30.5 32.2 32.2 32.2 32.2 32.2

Load 15.0 15.3 15.0 15.0 15.3 13.3 13.5 13.4 13.5 13.8

Rating 29.7 29.7 29.7 29.7 29.7 31.3 31.3 31.3 31.3 31.3

Load 17.8 17.4 17.2 17.3 17.6 14.8 14.7 14.6 14.7 15.0

Rating 27.1 27.1 27.1 27.1 27.1 28.9 28.9 28.9 28.9 28.9

Load 14.0 13.7 13.6 13.7 13.9 11.7 11.6 11.5 11.6 11.8

Rating 29.7 29.7 29.7 29.7 29.7 31.3 31.3 31.3 31.3 31.3

Load 17.8 17.5 17.3 17.3 17.6 14.8 14.8 14.7 14.7 15.1

Rating 29.7 29.7 29.7 29.7 29.7 31.3 31.3 31.3 31.3 31.3

Load 13.6 13.3 13.2 13.2 13.4 11.3 11.2 11.1 11.2 11.4

Rating 27.1 27.1 27.1 27.1 27.1 28.9 28.9 28.9 28.9 28.9

Load 1.9 - - - - 1.8 - - - -

Rating 14.9 - - - - 16.6 - - - -

Load 0.9 - - - - 0.9 - - - -

Rating 14.2 - - - - 16.1 - - - -

Load 1.9 - - - - 1.8 - - - -

Rating 16.9 - - - - 18.5 - - - -

Load 1.8 - - - - 1.7 - - - -

Rating 14.3 - - - - 16.2 - - - -

Load 0.7 - - - - 0.7 - - - -

Rating 15.1 - - - - 17.1 - - - -

Load - - - - - 1.7 - - - -

Rating - - - - - 18.2 - - - -

Load - - - - - 1.6 - - - -

Rating - - - - - 19.7 - - - -

Load - - - - - 1.4 - - - -

Rating - - - - - 18.0 - - - -

Load 0.6 - - - - 0.8 - - - -

Rating 15.6 - - - - 15.6 - - - -

Load 84.7 85.7 86.7 88.2 90.3 107.0 106.8 107.2 108.4 110.6

Rating 139.5 139.5 139.5 139.5 139.5 148.6 148.6 148.6 148.6 148.6

Load 65.2 66.3 66.7 67.5 68.7 67.4 68.2 68.6 69.3 70.6

Rating 132.0 132.0 132.0 132.0 132.0 140.0 140.0 140.0 140.0 140.0

Feeder 90R (Campbell ST ZS to Double Bay ZS) 132

Feeder 9SB/2 (Surrry Hills ZS to Double Bay ZS) 132

Feeder 395 (Surrry Hills STS to Rose Bay ZS T2) 33

Feeder 396 (2) (Surrry Hills STS to Waverley ZS) 33

Feeder 392 (2) (Surrry Hills STS to Waverley ZS T4) 33

Feeder 393 (Surrry Hills STS to Rose Bay ZS T4) 33

Feeder 394 (Surrry Hills STS to Rose Bay ZS T3) 33

Feeder 390 (2) (Surrry Hills STS to Waverley ZS T2) 33

Feeder 391 (Surrry Hills STS to Waverley ZS T3) 33

Feeder 392 (1) (Surrry Hills STS to Waverley ZS T4) 33

Feeder 388 (Surrry Hills STS to Darlinghurst ZS T1) 33

Feeder 389 (Surrry Hills STS to Darlinghurst ZS T3) 33

Feeder 390 (1) (Surrry Hills STS to Waverley ZS T2) 33

Feeder 385 (Surrry Hills STS to Surrry Hills ZS T3) 33

Feeder 386 (Surrry Hills STS to Darlinghurst ZS T4) 33

Feeder 387 (Surrry Hills STS to Darlinghurst ZS T2) 33

Feeder 384 (Surrry Hills STS to Surrry Hills ZS T4) 33

Feeder 381 (Surrry Hills STS to Paddington ZS T3) 33

Feeder 382 (Surrry Hills STS to Paddington ZS T2) 33

Feeder 383 (Surrry Hills STS to Surrry Hills ZS T1) 33

Feeder 377 (Surrry Hills STS to Graving Dock ZS T1) 33

Feeder 378 (Surrry Hills STS to Graving Dock ZS T2) 33

Feeder 380 (Surrry Hills STS to Paddington ZS T4) 33

Feeder 359 (Bunnerong North STS to International Terminal ) 33

Feeder 360 (Bunnerong North STS to Mascot ZS T6) 33

Feeder 376 (Surrry Hills STS to Surrry Hills ZS T2) 33

Feeder 356 (Bunnerong North STS to International Terminal ) 33

Feeder 358 (Bunnerong North STS to APM) 33

Page D5 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 6.7 6.7 7.1 7.1 7.1 5.1 5.1 5.0 5.1 5.2

Rating 21.6 20.7 20.7 20.7 20.7 24.2 24.2 20.7 20.7 20.7

Load 8.3 8.2 8.2 8.2 8.2 13.0 12.9 12.7 12.7 12.8

Rating 21.6 20.7 20.7 20.7 20.7 24.2 24.2 20.7 20.7 20.7

Load 37.7 37.7 37.9 38.2 38.5 34.7 34.5 31.9 32.2 33.4

Rating 43.5 40.3 40.3 40.3 40.3 45.7 45.7 40.3 40.3 40.3

Load 38.3 37.0 37.5 37.7 38.3 35.6 35.6 31.4 31.6 31.8

Rating 43.5 40.3 40.3 40.3 40.3 45.7 45.7 40.3 40.3 40.3

Load 41.4 40.3 41.0 41.2 41.6 35.5 35.3 32.7 33.0 33.3

Rating 43.5 43.5 43.5 43.5 43.5 48.9 48.9 48.9 48.9 48.9

Load 21.4 21.6 21.8 21.9 22.2 15.5 15.5 14.3 14.4 14.6

Rating 49.2 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 20.1 20.2 20.4 20.6 20.7 13.8 13.8 13.7 13.9 14.0

Rating 49.2 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 5.8 5.9 6.1 6.2 6.2 4.2 4.2 4.1 4.2 4.3

Rating 30.0 30.0 30.0 30.0 30.0 41.4 41.4 41.4 41.4 41.4

Load 0.6 0.6 0.6 0.6 0.6 0.5 0.5 0.5 0.5 0.5

Rating 21.6 21.6 21.6 21.6 21.6 24.2 24.2 24.2 24.2 24.2

Load 6.0 6.1 6.3 6.4 6.4 4.4 4.4 4.4 4.5 4.6

Rating 14.1 14.1 14.1 14.1 14.1 15.7 15.7 15.7 15.7 15.7

Load 5.7 5.8 6.0 6.1 6.1 4.2 4.2 4.1 4.2 4.2

Rating 30.0 30.0 30.0 30.0 30.0 41.4 41.4 41.4 41.4 41.4

Load 5.9 5.9 6.2 6.3 6.3 4.4 4.4 4.4 4.5 4.5

Rating 13.6 13.6 13.6 13.6 13.6 15.1 15.1 15.1 15.1 15.1

Load 0.4 0.5 0.4 0.4 0.5 0.1 0.0 0.0 0.0 0.1

Rating 49.2 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 41.6 41.5 41.6 42.2 42.6 37.4 37.3 34.3 34.7 35.3

Rating 43.5 43.5 43.5 43.5 43.5 48.9 48.9 48.9 48.9 48.9

FEEDER KU1(2) tee to Tomalpin 33kV

FEEDER KU1(1) Kurri STS to Cessnock and Tomalpin 33kV

FEEDER 30092(5) tee to Paxton 33kV

FEEDER 30092(9) tee to Paxton TX2 33kV

FEEDER 30092(6) tee to Paxton 33kV

FEEDER KU6(4) Kurri STS to Cessnock and Nulkaba(tee Nulkaba) 33kV

FEEDER 30092(8) tee to Paxton TX1 33kV

FEEDER 30092(7) tee to Austar Kitchener 33kV

FEEDER KU6(1) Kurri STS to Cessnock and Nulkaba (tee Kurri STS) 33kV

FEEDER KU9 Kurri STS to Nulkaba 33kV

FEEDER KU6(5) Kurri STS to Cessnock and Nulkaba (tee Cessnock) 33kV

FEEDER 30092(1) Cessnock to Paxton and Austar Kitchener 33kV

FEEDER 30095(1) Cessnock to Austar 33kV

FEEDER KU1(3) Kurri STS to Cessnock tee Cessnock 33kV

Greater Cessnock Area - Feeder Load ForecastSummer (MVA) Winter (MVA)

Feeder Name Voltage (MVA)

Page D6 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 89.5 91.4 92.8 92.8 94.5 61.1 63.2 64.5 65.8 66.1

Rating 142.4 142.4 142.4 142.4 142.4 151.1 151.1 151.1 151.1 151.1

Load 89.4 91.4 92.7 93.2 94.8 61.1 63.8 64.5 66.0 66.3

Rating 152.9 152.9 152.9 152.9 152.9 151.0 151.0 151.0 151.0 151.0

Load 12.8 12.6 12.5 12.5 12.7 7.1 7.2 7.3 7.4 7.5

Rating 32.2 32.2 32.2 32.2 32.2 34.9 34.9 34.9 34.9 34.9

Load 9.9 10.1 10.3 10.5 10.7 6.8 7.1 7.3 7.6 7.8

Rating 16.8 16.8 16.8 16.8 16.8 18.2 18.2 18.2 18.2 18.2

Load 9.8 10.1 10.3 10.5 10.7 6.8 7.1 7.3 7.6 7.8

Rating 16.8 16.8 16.8 16.8 16.8 18.2 18.2 18.2 18.2 18.2

Load 12.0 12.3 12.7 12.8 13.0 8.5 8.8 9.3 9.7 10.0

Rating 16.8 16.8 16.8 16.8 16.8 18.2 18.2 18.2 18.2 18.2

Load 13.0 13.5 13.8 14.1 14.3 10.1 10.5 10.9 11.2 11.5

Rating 15.9 15.9 15.9 15.9 15.9 17.7 17.7 17.7 17.7 17.7

Load 13.4 13.9 14.2 14.6 14.8 10.2 10.7 11.2 11.5 11.7

Rating 18.6 18.6 18.6 18.6 18.6 21.4 21.4 21.4 21.4 21.4

Load 13.0 13.5 13.8 14.1 14.3 10.1 10.5 10.9 11.2 11.5

Rating 24.1 24.1 24.1 24.1 24.1 26.8 26.8 26.8 26.8 26.8

Load 13.0 13.5 13.8 14.1 14.3 10.1 10.5 10.9 11.2 11.5

Rating 22.8 22.8 22.8 22.8 22.8 25.3 25.3 25.3 25.3 25.3

Load - - - - - 14.7 - - - -

Rating - - - - - 20.0 - - - -

Load - - - - - 14.7 - - - -

Rating - - - - - 20.0 - - - -

Load - - - - - 14.9 - - - -

Rating - - - - - 20.0 - - - -

Load 12.7 12.3 12.2 12.2 12.3 7.2 7.3 7.5 7.5 7.7

Rating 18.6 18.6 18.6 18.6 18.6 19.0 19.0 19.0 19.0 19.0

Load 12.6 12.5 12.4 12.4 12.5 7.1 7.2 7.3 7.4 7.5

Rating 18.5 18.5 18.7 18.7 18.7 20.1 20.1 20.1 20.1 20.1

Load - - - - - 14.7 - - - -

Rating - - - - - 20.0 - - - -

Load 0.2 0.2 - - - 0.2 0.2 - - -

Rating 15.6 15.6 - - - 18.2 18.2 - - -

Load 0.4 0.4 - - - 0.4 0.4 - - -

Rating 14.2 14.2 - - - 16.1 16.1 - - -

Load 0.4 0.4 - - - 0.4 0.4 - - -

Rating 14.2 14.2 - - - 16.1 16.1 - - -

Load 34.3 34.5 - - - 39.4 39.2 - - -

Rating 27.4 27.4 - - - 31.1 31.1 - - -

Load 17.2 17.4 - - - 19.8 19.7 - - -

Rating 13.6 13.6 - - - 15.4 15.4 - - -

Load 17.2 17.4 - - - 19.8 19.7 - - -

Rating 13.6 13.6 - - - 15.4 15.4 - - -

Load 8.2 8.2 - - - 9.4 9.3 - - -

Rating 13.6 13.6 - - - 15.4 15.4 - - -

Load 8.2 8.2 - - - 9.4 9.3 - - -

Rating 13.6 13.6 - - - 15.4 15.4 - - -

Load 80.1 81.3 82.4 83.5 84.6 98.2 67.9 66.1 67.3 68.1

Rating 139.0 139.0 139.0 139.0 139.0 145.4 145.4 145.4 145.4 145.4

Load 1.3 1.3 1.2 1.2 1.2 1.5 1.5 1.3 1.4 1.4

Rating 212.0 212.0 212.0 212.0 212.0 218.0 218.0 218.0 218.0 218.0

Load 80.1 81.3 82.4 83.5 84.6 98.2 67.9 66.1 67.3 68.1

Rating 139.0 139.0 139.0 139.0 139.0 145.4 145.4 145.4 145.4 145.4

Load 1.3 1.3 1.2 1.2 1.2 1.5 1.5 1.3 1.4 1.4

Rating 212.0 212.0 212.0 212.0 212.0 218.0 218.0 218.0 218.0 218.0

Load 139.7 146.0 111.4 101.3 102.9 125.6 132.0 93.6 94.6 88.4

Rating 219.5 219.5 219.5 219.5 219.5 219.5 219.5 219.5 219.5 219.5

Load 77.4 83.9 84.0 73.4 74.9 61.4 68.1 68.6 69.7 63.3

Rating 158.9 158.9 158.9 158.9 158.9 168.0 168.0 168.0 168.0 168.0

Load 141.4 147.8 112.1 101.9 103.7 126.4 133.3 94.0 95.0 88.6

Rating 228.4 228.4 228.4 228.4 228.4 257.4 257.4 257.4 257.4 257.4Feeder 924/1 (Mason Park STSS to 924tee) 132

Feeder 90U (Mason Park STSS to Olympic Park ZS) 132

Feeder 923/1 (Mason Park STSS to 923tee) 132

Feeder 923/2 (923tee to Burwood ZS) 132

Feeder 90A (Mason Park STSS to Homebush STS) 132

Feeder 90G (Mason Park STSS to Olympic Park ZS) 132

Feeder 90L (Mason Park STSS to Homebush STS) 132

Feeder 771 (B) (Strathfield STS to 771tee) 33

Feeder 773 (A) (Strathfield STS to Leichhardt ZS) 33

Feeder 773 (B) (Strathfield STS to Leichhardt ZS) 33

Feeder 763 (B) (Rozelle STS to 763tee) 33

Feeder 771 (771tee to Leichhardt ZS) 33

Feeder 771 (A) (Strathfield STS to 771tee) 33

Feeder 617 (Homebush STS to Five Dock ZS) 33

Feeder 763 (763tee to Leichhardt ZS) 33

Feeder 763 (A) (Rozelle STS to 763tee) 33

Feeder 613 (Homebush STS to Five Dock ZS) 33

Feeder 614 (Homebush STS to Auburn ZS) 33

Feeder 615 (Homebush STS to Auburn ZS) 33

Feeder 609 (Homebush STS to Concord ZS) 33

Feeder 610 (Homebush STS to Five Dock ZS) 33

Feeder 612 (Homebush STS to Five Dock ZS) 33

Feeder 606 (Homebush STS to Concord ZS) 33

Feeder 607 (Homebush STS to Concord ZS) 33

Feeder 608 (Homebush STS to Concord ZS) 33

Feeder 602 (Homebush STS to Lidcombe ZS) 33

Feeder 604 (Homebush STS to Lidcombe ZS) 33

Feeder 605 (Homebush STS to Lidcombe ZS) 33

Feeder 200 (Mason Park STSS to Flemington ZS) 132

Feeder 201 (Mason Park STSS to Flemington ZS) 132

Feeder 601 (Homebush STS to Auburn ZS) 33

Inner West Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D7 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner West Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 77.9 84.7 84.7 73.9 75.7 61.8 68.5 68.9 70.1 63.4

Rating 168.0 168.0 168.0 168.0 168.0 177.2 177.2 177.2 177.2 177.2

Load 21.9 31.4 48.4 48.4 49.6 25.3 24.8 54.4 55.1 55.8

Rating 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0

Load 13.6 15.2 15.6 15.9 15.9 16.0 15.8 18.8 19.1 19.4

Rating 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0

Load 8.9 8.3 22.4 22.4 22.7 11.0 10.9 22.0 22.2 22.4

Rating 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0 270.0

Feeder 9P8 (Croydon ZS to Leichardt ZS) 132

Feeder 9P9 (Rozelle STS to Leichardt ZS) 132

Feeder 924/2 (924tee to Burwood ZS) 132

Feeder 9P2 (Mason Park STSS to Croydon ZS) 132

Page D8 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 34.9 34.9 34.9 35.3 35.8 36.7 37.7 37.4 38.2 38.9

Rating 83.6 83.6 83.6 83.6 83.6 115.6 115.6 115.6 115.6 115.6

Load 58.6 58.5 58.5 59.1 59.9 58.6 59.4 59.7 60.9 62.2

Rating 105.6 105.6 105.6 105.6 105.6 130.6 130.6 130.6 130.6 130.6

Load 41.0 40.9 40.9 41.2 41.7 38.1 37.7 39.0 38.6 39.3

Rating 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3

Load 34.8 34.7 34.7 35.1 35.6 36.6 37.4 37.2 37.8 38.5

Rating 83.6 83.6 83.6 83.6 83.6 115.6 115.6 115.6 115.6 115.6

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 30.3 30.3 30.3 30.3 30.3 46.9 46.9 46.9 46.9 46.9

Load 50.1 50.0 50.0 50.5 51.2 48.6 49.7 49.7 50.5 51.5

Rating 105.6 105.6 105.6 105.6 105.6 114.3 114.3 114.3 114.3 114.3

Load 45.9 45.9 46.0 46.5 47.1 47.3 47.7 48.2 49.0 50.0

Rating 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3

Load 21.7 21.7 21.8 22.0 22.3 20.8 22.2 21.9 22.6 23.1

Rating 105.6 105.6 105.6 105.6 105.6 121.4 121.4 121.4 121.4 121.4

Load 16.9 16.9 16.9 17.2 17.5 22.0 23.0 22.2 23.1 23.6

Rating 63.5 63.5 63.5 63.5 63.5 69.1 69.1 69.1 69.1 69.1

Load 16.0 15.9 15.9 16.1 16.3 15.9 17.0 17.2 17.2 17.5

Rating 107.8 107.8 107.8 107.8 107.8 113.5 113.5 113.5 113.5 113.5

Load 28.6 28.7 28.8 29.1 29.5 30.4 30.6 30.2 31.8 32.4

Rating 45.7 45.7 45.7 45.7 45.7 44.7 44.7 44.7 44.7 44.7

Load 35.7 35.7 35.8 36.2 36.7 36.9 37.7 37.5 38.3 39.1

Rating 105.6 105.6 105.6 105.6 105.6 114.3 114.3 114.3 114.3 114.3

Load 22.9 22.8 23.0 23.3 23.7 22.5 22.6 23.0 23.3 23.9

Rating 35.6 35.6 35.6 35.6 35.6 37.9 37.9 37.9 37.9 37.9

Load 22.4 22.4 22.5 22.6 23.2 23.0 22.4 22.8 23.3 23.5

Rating 39.3 39.3 39.3 39.3 39.3 40.0 40.0 40.0 40.0 40.0

Load 18.4 17.8 17.6 17.5 17.5 13.7 13.4 13.4 13.3 13.6

Rating 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9

Load 17.7 17.1 16.9 16.7 16.7 13.6 13.0 12.9 13.1 13.2

Rating 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9

Load 5.1 5.1 5.1 5.1 5.1 2.9 2.8 2.9 2.9 2.9

Rating 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9 22.9

Load 38.6 38.6 39.0 39.7 40.7 48.5 49.5 49.9 52.0 52.8

Rating 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2

Load 43.5 43.5 44.6 44.9 46.3 61.0 61.6 63.0 65.4 68.7

Rating 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3

Lower Central Coast Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 824(2) (Gosford to Erina, Avoca and Wamberal) 66kV

FEEDER 824(1) (Gosford to Tee Erina and Avoca) 66kV

FEEDER 824(3) (Erina to Tee Gosford and Avoca) 66kV

FEEDER 824(5) (Avoca to Tee Gosford and Erina) 66kV

FEEDER 824(4) (Wamberal to Tee Gosford and Avoca) 66kV

FEEDER 826 (Gosford STS to Erina) 66kV

FEEDER 828 (Gosford STS to Woy Woy) 66kV

FEEDER 883 (Avoca to Empire Bay) 66kV

FEEDER 841 (Erina to Avoca) 66kV

FEEDER 884 (Woy Woy to Empire Bay) 66kV

FEEDER 840 (Umina to Woy Woy) 66kV

FEEDER 830 (Gosford STS to Umina) 66kV

FEEDER 799 (Ourimbah STS to Lisarow) 33kV

FEEDER 721 (Gosford STS to Lisarow) 33kV

FEEDER 794 (Ourimbah STS to Peats Ridge) 33kV

FEEDER 88M (Ourimbah to Long Jetty) 66kV

FEEDER 720 (Ourimbah STS to Peats Ridge) 33kV

FEEDER 757 (Peats Ridge to Mangrove Mountain) 33kV

FEEDER 88J (Ourimbah to Long Jetty) 66kV

Page D9 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 141.3 139.2 138.0 139.5 142.1 164.1 148.0 147.6 148.2 152.2

Rating 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1

Load 140.8 138.7 137.6 139.0 141.5 162.7 147.3 146.9 147.7 151.3

Rating 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1 240.1

Load 37.7 37.4 36.7 37.2 37.4 55.7 38.3 38.0 37.6 38.7

Rating 246.0 246.0 246.0 246.0 246.0 259.0 259.0 259.0 259.0 259.0

Load 119.9 117.6 117.2 118.4 120.8 133.7 131.6 131.3 132.7 136.0

Rating 165.5 165.5 165.5 165.5 165.5 175.6 175.6 175.6 175.6 175.6

Load 59.0 59.6 60.6 61.9 63.4 84.0 82.4 81.9 82.6 84.7

Rating 110.9 110.9 110.9 110.9 110.9 130.3 130.3 130.3 130.3 130.3

Load - - - - - - - - - -

Rating - - - - - - - - - -

Load 159.1 156.5 155.6 155.3 159.5 116.3 142.7 142.7 145.1 145.4

Rating 253.0 253.0 253.0 253.0 253.0 268.0 268.0 268.0 268.0 268.0

Load 163.4 160.7 160.0 159.6 163.8 118.8 146.7 146.7 149.2 149.4

Rating 287.0 287.0 287.0 287.0 287.0 302.0 302.0 302.0 302.0 302.0

Load 157.5 155.2 155.3 156.2 159.3 172.0 160.9 160.5 162.1 165.4

Rating 253.0 253.0 253.0 253.0 253.0 268.0 268.0 268.0 268.0 268.0

Load 44.5 44.1 44.7 43.9 45.6 50.9 41.0 40.8 40.3 41.2

Rating 246.0 246.0 246.0 246.0 246.0 259.0 259.0 259.0 259.0 259.0

Load 120.0 118.1 117.6 118.7 120.9 134.0 132.0 131.8 133.2 136.5

Rating 181.8 181.8 181.8 181.8 181.8 188.6 188.6 188.6 188.6 188.6

Load 59.1 59.7 60.7 61.9 63.4 84.2 82.4 82.0 82.8 84.8

Rating 110.9 110.9 110.9 110.9 110.9 130.3 130.3 130.3 130.3 130.3

Load 157.9 154.9 152.7 154.2 156.6 119.5 140.6 140.7 141.3 145.1

Rating 300.0 300.0 300.0 300.0 300.0 320.0 320.0 320.0 320.0 320.0

Load 160.7 157.8 155.7 157.1 159.4 122.6 143.7 143.7 144.3 148.0

Rating 287.0 287.0 287.0 287.0 287.0 302.0 302.0 302.0 302.0 302.0

Load 13.0 12.9 12.9 13.0 13.1 10.1 10.1 10.0 10.1 10.2

Rating 94.9 94.9 94.9 94.9 94.9 107.5 107.5 107.5 107.5 107.5

Load 13.0 12.9 12.9 13.0 13.1 10.1 10.1 10.1 10.1 10.2

Rating 94.9 94.9 94.9 94.9 94.9 107.5 107.5 107.5 107.5 107.5

Load 113.6 111.0 109.3 109.9 112.1 57.6 93.8 94.2 95.3 97.3

Rating 247.0 247.0 247.0 247.0 247.0 223.0 256.0 256.0 256.0 256.0

Load 113.7 111.1 109.6 110.2 112.4 50.7 93.7 94.2 95.2 97.6

Rating 247.0 247.0 247.0 247.0 247.0 256.0 256.0 256.0 256.0 256.0

Load 72.4 69.8 68.2 68.2 69.4 58.9 51.1 51.0 51.2 52.3

Rating 244.6 244.6 244.6 244.6 244.6 221.8 221.8 221.8 221.8 221.8

Load 72.4 69.8 68.4 68.3 69.5 51.6 51.4 51.6 52.0 53.0

Rating 244.6 244.6 244.6 244.6 244.6 258.4 258.4 258.4 258.4 258.4

Load 21.6 20.9 20.4 20.4 20.9 23.3 23.2 23.4 23.7 24.3

Rating 58.1 58.1 58.1 58.1 58.1 61.6 61.6 61.6 61.6 61.6

Load 21.7 20.9 20.5 20.5 21.0 23.5 23.5 23.6 23.9 24.5

Rating 58.0 58.0 58.0 58.0 58.0 61.6 61.6 61.6 61.6 61.6

Load 21.7 20.9 20.5 20.6 21.1 23.5 23.5 23.6 23.9 24.5

Rating 34.5 34.5 34.5 34.5 34.5 38.2 38.2 38.2 38.2 38.2

Load 0.4 - - - - 14.2 - - - -

Rating 19.5 - - - - 20.6 - - - -

Load 0.4 - - - - 14.2 - - - -

Rating 20.2 - - - - 21.4 - - - -

Load 0.4 - - - - 14.1 - - - -

Rating 20.2 - - - - 21.4 - - - -

Load 0.4 - - - - 14.0 - - - -

Rating 20.3 - - - - 18.3 - - - -

Load 20.5 20.4 20.4 20.6 20.8 17.3 16.7 16.4 16.3 16.5

Rating 40.2 40.2 40.2 40.2 40.2 43.6 43.6 43.6 43.6 43.6

Load 20.6 20.5 20.5 20.6 20.9 17.4 16.7 16.4 16.3 16.6

Rating 40.2 40.2 40.2 40.2 40.2 43.6 43.6 43.6 43.6 43.6Feeder 572 (Willoughby STS to Gore Hill ZS T2) 33

Feeder 571 (Willoughby STS to Gore Hill ZS T1) 33

Feeder 564 (Willoughby STS to Crows Nest ZS T3) 33

Feeder 565 (Willoughby STS to Crows Nest ZS T2) 33

Feeder 562 (Willoughby STS to Crows Nest ZS T1) 33

Feeder 563 (Willoughby STS to Crows Nest ZS T4) 33

Feeder 554 (Willoughby STS to Chatswood ZS T3) 33

Feeder 9P5 (Crows Nest ZS to North Sydney ZS) 132

Feeder 551 (Willoughby STS to Chatswood ZS T2) 33

Feeder 552 (Willoughby STS to Chatswood ZS T1) 33

Feeder 9H3 (Willoughby STS to Crows Nest ZS) 132

Feeder 9H5 (Willoughby STS to Crows Nest ZS) 132

Feeder 9P3 (Crows Nest ZS to North Sydney ZS) 132

Feeder 9E5(2) (Lindfield STSS to Willoughby STS T2) 132

Feeder 9H1 (Willoughby STS to RNSH ZS T1) 132

Feeder 9H2 (Willoughby STS to RNSH ZS T2) 132

Feeder 9E5(1) (Sydney East BSP to Lindfield STSS) 132

Feeder 9Y4 (Lindfield STSS to Willoughby STS T1) (ex 9E4/2) 132

Feeder 9Y9/1 (Lindfield STSS to Castle Cove ZS) (ex 9E4/3) 132

Feeder 9Y9/2 (Castle Cove ZS to Mosman ZS) (ex 9E4/4) 132

Feeder 9E3(1) (Sydney East BSP to Lindfield STSS) 132

Feeder 9E3(2) (Lindfield STSS to Willoughby STS T3) 132

Feeder 9E4 (Sydney East BSP to Lindfield STSS) (ex 9E4/1) 132

Feeder 9Y7/1 (Lindfield STSS to Castle Cove ZS) (ex 925/3) 132

Feeder 9Y7/2 (Castle Cove ZS to Mosman ZS) (ex 925/4) 132

Feeder 9P7 (Mosman ZS to Willoughby STS T4) (ex 925/6) 132

Feeder 925 series reactor 132Feeder 925 (Feeder 925 series reactor to Lindfield STSS) (ex 925/1) 132

Feeder 9Y5 (Lindfield STSS to Willoughby STS T 4 ) (ex 925/2) 132

Lower North Shore Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D10 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Lower North Shore Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 20.6 20.5 20.6 20.6 20.9 17.4 16.7 16.4 16.3 16.6

Rating 40.2 40.2 40.2 40.2 40.2 43.6 43.6 43.6 43.6 43.6

Load 20.6 20.6 20.5 20.6 20.9 17.4 16.7 16.4 16.3 16.6

Rating 40.2 40.2 40.2 40.2 40.2 43.6 43.6 43.6 43.6 43.6

Feeder 573 (Willoughby STS to Gore Hill ZS T3) 33

Feeder 574 (Willoughby STS to Gore Hill ZS T4) 33

Page D11 of D40

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Load 27.0 27.1 27.2 27.1 27.5 20.7 21.6 22.4 22.8 22.8

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 22.7 22.4 22.3 22.4 22.7 17.5 17.8 18.3 18.4 18.8

Rating 52.0 52.0 52.0 52.0 52.0 55.2 55.2 55.2 55.2 55.2

Load 10.7 10.8 10.9 11.0 11.1 7.6 8.0 8.1 8.3 8.5

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 26.9 26.9 28.0 28.3 28.6 21.1 22.4 22.3 22.8 23.4

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 25.2 25.3 25.5 25.6 26.0 16.9 17.6 18.0 18.5 19.0

Rating 27.8 27.8 27.8 27.8 27.8 31.1 31.1 31.1 31.1 31.1

Load 15.5 15.6 15.7 15.8 16.0 10.1 10.5 10.8 11.0 11.4

Rating 20.2 20.2 20.2 20.2 20.2 22.6 22.6 22.6 22.6 22.6

Load 5.3 5.3 5.3 5.3 5.3 0.0 0.0 0.0 0.0 0.0

Rating 35.1 35.1 35.1 35.1 35.1 37.3 37.3 37.3 37.3 37.3

Load 38.4 38.2 38.2 38.4 38.9 22.8 22.3 22.3 22.7 23.4

Rating 60.0 60.0 60.0 60.0 60.0 65.2 65.2 65.2 65.2 65.2

Load 28.2 28.4 28.9 29.2 29.5 16.4 16.7 17.2 17.5 17.9

Rating 39.8 39.8 39.8 39.8 39.8 42.2 42.2 42.2 42.2 42.2

Load 5.1 5.1 5.1 5.1 5.1 4.9 4.9 4.9 4.9 4.9

Rating 20.2 20.2 20.2 20.2 20.2 22.6 22.6 22.6 22.6 22.6

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 11.6 11.6 11.6 11.6 11.6 21.0 21.0 21.0 21.0 21.0

Load 32.5 32.3 32.3 32.4 32.6 21.6 21.3 21.4 21.8 22.2

Rating 35.1 35.1 35.1 35.1 35.1 37.2 37.2 37.2 37.2 37.2

Load 23.2 22.9 22.8 22.9 23.3 17.7 17.9 18.6 18.7 19.1

Rating 32.7 32.7 32.7 32.7 32.7 34.7 34.7 34.7 34.7 34.7

Load 32.9 32.8 32.8 32.8 33.1 21.6 21.3 21.5 21.8 22.2

Rating 38.3 38.3 38.3 38.3 38.3 40.6 40.6 40.6 40.6 40.6

Load 33.6 33.9 34.3 34.5 35.0 21.6 22.3 23.0 23.4 24.1

Rating 39.8 39.8 39.8 39.8 39.8 42.2 42.2 42.2 42.2 42.2

Load 3.1 3.1 3.1 3.1 3.1 6.2 6.2 6.2 6.2 6.2

Rating 21.0 21.0 21.0 21.0 21.0 22.4 22.4 22.4 22.4 22.4

Load 28.9 29.2 29.6 30.0 30.4 16.6 16.9 17.1 17.5 17.9

Rating 33.4 33.4 33.4 33.4 33.4 37.5 37.5 37.5 37.5 37.5

Load 38.9 38.7 38.7 38.9 39.3 23.0 22.5 22.6 23.0 23.7

Rating 60.0 60.0 60.0 60.0 60.0 65.2 65.2 65.2 65.2 65.2

Load 22.8 22.5 22.4 22.5 22.7 17.5 17.7 18.3 18.4 18.8

Rating 35.1 35.1 35.1 35.1 35.1 37.3 37.3 37.3 37.3 37.3

Maitland Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER KU8 Kurri STS to Rutherford 33kV

FEEDER 33904(2) Beresfield STS to Tarro and Hunter Water Corptee Tarro 33kV

FEEDER KU4(2) Kurri STS to Telarah and Maitland (tee to Telarah) 33kV

FEEDER 30012 Telarah to Rutherford 33kV

FEEDER KU13 Kurri STS to Telarah 33kV

FEEDER KU5 Kurri STS to Telarah 33kV

FEEDER 34099(1) Thornton to Essential Energy 33kV

FEEDER 33899 Beresfield STS to Thornton 33kV

FEEDER KU4(3) Kurri STS to Telarah and Maitland(tee to Maitland) 33kV

FEEDER KU2 Kurri STS to Bloomfield 33kV

FEEDER 33904(3) Beresfield STS to Hunter Water Corp 33kV

FEEDER 34116 Thornton to Metford 33kV

FEEDER 33904(1) Beresfield STS to Tarro and Hunter Water Corp 33kV

FEEDER 33874 Beresefield STS to Metford 33kV

FEEDER KU4(1) Kurri STS to Telarah and Maitland 33kV

FEEDER 33854 Beresfield STS to Tarro 33kV

FEEDER 33884 Beresfield STS to Abel Mine 33kV

FEEDER KU3(1) Kurri STS to Maitland 33kV

FEEDER 33859 Beresfield STS to Thornton 33kV

Page D12 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 164.2 165.1 167.0 169.8 172.5 201.0 201.6 203.4 207.0 210.9

Rating 454.1 454.1 454.1 454.1 454.1 454.1 454.1 454.1 454.1 454.1

Load 164.1 165.1 167.0 169.7 172.5 201.0 201.5 203.4 206.9 210.8

Rating 503.9 503.9 503.9 503.9 503.9 503.9 503.9 503.9 503.9 503.9

Load 23.6 23.9 24.4 25.0 25.6 35.0 35.2 35.8 36.6 37.5

Rating 198.0 198.0 198.0 198.0 198.0 208.5 208.5 208.5 208.5 208.5

Load 23.0 23.2 23.7 24.2 24.7 33.5 33.8 34.2 34.9 35.7

Rating 37.4 37.4 37.4 37.4 37.4 50.9 50.9 50.9 50.9 50.9

Load 23.7 23.8 24.0 24.4 24.8 27.7 27.8 28.0 28.6 29.1

Rating 51.4 51.4 51.4 51.4 51.4 57.2 57.2 57.2 57.2 57.2

Load 11.1 11.0 11.1 11.3 11.5 13.2 13.3 13.5 13.7 14.0

Rating 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3

Load 21.0 21.1 21.4 21.7 22.0 24.3 24.4 24.5 25.0 25.5

Rating 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4

Load 21.2 21.3 21.5 21.8 22.1 24.6 24.5 24.7 25.2 25.7

Rating 37.4 37.4 37.4 37.4 37.4 50.9 50.9 50.9 50.9 50.9

Load 21.1 21.2 21.4 21.7 22.0 24.4 24.3 24.6 25.0 25.5

Rating 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4

Load 33.6 34.6 35.5 36.3 37.1 40.9 40.8 41.1 42.1 43.0

Rating 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2 57.2

Load 33.2 34.1 35.0 35.7 36.5 40.3 40.2 40.6 41.5 42.4

Rating 68.8 68.8 68.8 68.8 68.8 71.4 71.4 71.4 71.4 71.4

Load 33.2 34.1 34.9 35.7 36.5 40.3 40.2 40.6 41.5 42.4

Rating 56.9 56.9 56.9 56.9 56.9 62.9 62.9 62.9 62.9 62.9

Load 26.0 26.1 26.3 26.8 27.2 35.3 35.4 36.0 36.5 37.2

Rating 64.5 64.5 64.5 64.5 64.5 71.4 71.4 71.4 71.4 71.4

Load 10.4 10.4 10.4 10.5 10.6 9.9 10.0 10.1 10.2 10.3

Rating 43.3 43.3 43.3 43.3 43.3 46.0 46.0 46.0 46.0 46.0

Load 18.4 18.5 18.7 19.1 19.3 27.9 27.9 28.4 28.8 29.3

Rating 47.6 47.6 47.6 47.6 47.6 55.0 55.0 55.0 55.0 55.0

Load 18.8 18.9 19.1 19.5 19.8 26.7 26.8 27.2 27.6 28.2

Rating 39.8 39.8 39.8 39.8 39.8 54.3 54.3 54.3 54.3 54.3

Load 14.2 14.3 14.4 14.6 14.8 18.1 17.9 18.3 18.5 19.0

Rating 42.1 42.1 42.1 42.1 42.1 46.8 46.8 46.8 46.8 46.8

Load 14.0 14.1 14.3 14.6 15.0 23.8 23.9 24.1 24.7 25.1

Rating 47.2 47.2 47.2 47.2 47.2 52.3 52.3 52.3 52.3 52.3

Load 19.4 19.4 19.5 19.8 20.1 15.4 15.2 15.3 15.5 15.8

Rating 41.0 41.0 41.0 41.0 41.0 43.2 43.2 43.2 43.2 43.2

Load 19.5 19.5 19.7 20.1 20.4 27.7 27.6 27.8 28.5 28.8

Rating 51.4 51.4 51.4 51.4 51.4 62.1 62.1 62.1 62.1 62.1

Load 19.5 19.5 19.7 20.2 20.4 27.7 27.5 27.8 28.5 28.7

Rating 37.1 37.1 37.1 37.1 37.1 42.8 42.8 42.8 42.8 42.8

Load 10.8 10.8 10.8 10.9 11.0 13.8 13.8 13.8 14.0 14.1

Rating 22.9 22.9 22.9 22.9 22.9 24.6 24.6 24.6 24.6 24.6

Load 14.1 14.1 14.2 14.7 14.7 18.2 17.9 18.3 18.5 19.0

Rating 53.9 53.9 53.9 53.9 53.9 57.2 57.2 57.2 57.2 57.2

Load 19.4 19.4 19.5 19.8 20.0 15.3 15.2 15.2 15.5 15.8

Rating 40.5 40.5 40.5 40.5 40.5 42.6 42.6 42.6 42.6 42.6

Load 11.1 11.0 11.1 11.3 11.5 13.2 13.3 13.5 13.8 14.0

Rating 25.7 25.7 25.7 25.7 25.7 34.3 34.3 34.3 34.3 34.3

Feeder S10(5) (Kangaroo Park Terminal to Manly ZS) 33

Feeder S12 (Warringah STS to Beacon Hill ZS) 33

Feeder S14 (Warringah STS to Killarney ZS) 33

Feeder S10(1) (Warringah STS to Tee Kangaroo Park ) 33

Feeder S10(3) (Tee Warringah STS to Kangaroo Park Terminal) 33

Feeder S10(4) (Kangaroo Park Terminal to North Head ZS) 33

Feeder S08(2) (Tee warringah STS/Manly/Harbord ZS to Manly ZS) 33Feeder S08(3) (Tee warringah STS/Manly/Harbord ZS to Harbord ZS) 33

Feeder S09 (Warringah STS to Beacon Hill ZS) 33

Feeder S07(2) (Tee Warringah STS/Brrokvale/Harbord ZS to Brookvale ZS) 33Feeder S07(3) (Tee Warringah STS/Brookvale/Harbord ZS to Harbord ZS) 33

Feeder S08(1) (Warringah STS to Tee Manly/Harbord ZS) 33

Feeder S05(2) (Tee Warringah STS/CP/Dee Why West ZS to Dee Why West ZS) 33

Feeder S06 (Warringah STS to Dee Why West ZS) 33

Feeder S07(1) (Warringah STS to Tee Brookvale/Harbord ZS) 33

Feeder S03(1) (Warringah STS to tee CP Oxford Falls/Belrose ZS) 33Feeder S03(2) (Tee Warringah/CP/Belrose ZS to Belrose ZS) 33

Feeder S05(1) (Warringah STS to Tee CP/Dee Why West ZS) 33

Feeder S02(1) (Warringah STS to tee Killarney/Belrose ZS) 33Feeder S02(2) (Tee Warringah STS/Killarney/Belrose ZS to Killarney ZS) 33Feeder S02(3) (Tee Warringah STS /Killarney/Belrose ZS to Belrose ZS) 33

Feeder 9M4 (Sydney East BSP to Warringah STS) 132

Feeder 9M5 (Warringah STS to Balgowlah North ZS) 132

Feeder S01 (Warringah STS to Balgowlah North ZS) 33

Feeder 9M3 (Sydney East BSP to Warringah STS) 132

Manly Warringah Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D13 of D40

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Manly Warringah Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 19.9 19.8 19.9 20.1 20.4 18.4 18.7 19.0 19.3 19.5

Rating 36.3 36.3 36.3 36.3 36.3 38.3 38.3 38.3 38.3 38.3

Load 19.9 19.8 19.9 20.1 20.4 18.5 18.8 19.1 19.3 19.6

Rating 36.3 36.3 36.3 36.3 36.3 38.3 38.3 38.3 38.3 38.3

Load 10.8 10.8 10.9 10.9 11.0 13.8 13.9 13.9 14.0 14.2

Rating 26.6 26.6 26.6 26.6 26.6 28.6 28.6 28.6 28.6 28.6

Feeder S16 (Warringah STS to Brookvale ZS) 33

Feeder S17 (Warringah STS to Brookvale ZS) 33

Feeder S18 (Harbord ZS to North Head ZS) 33

Page D14 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 18.1 - - - - 17.1 21.3 - - -

Rating 26.2 - - - - 29.1 29.1 - - -

Load 12.7 - - - - 10.3 10.3 - - -

Rating 28.7 - - - - 31.9 31.9 - - -

Load 25.8 26.9 26.9 27.1 27.5 20.9 14.5 21.5 21.7 22.2

Rating 47.6 35.0 35.0 35.0 35.0 50.8 35.0 35.0 35.0 35.0

Load 27.1 27.0 27.0 27.1 27.5 21.3 21.2 21.5 21.7 22.2

Rating 37.2 37.2 37.2 37.2 37.2 39.2 39.2 39.2 39.2 39.2

Load 13.1 13.0 13.0 13.1 13.2 10.8 10.7 10.7 10.8 11.0

Rating 37.2 37.2 37.2 37.2 37.2 39.2 39.2 39.2 39.2 39.2

Load 16.1 17.4 17.2 17.4 17.6 9.3 9.0 9.7 9.8 10.1

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 23.0 22.5 22.2 22.2 22.5 16.2 16.0 17.8 17.9 18.3

Rating 26.5 26.5 26.5 26.5 26.5 28.9 28.9 28.9 28.9 28.9

Load 23.0 22.5 22.2 22.2 22.5 16.2 16.0 17.8 17.9 18.3

Rating 26.5 26.5 26.5 26.5 26.5 28.9 28.9 28.9 28.9 28.9

Load 16.1 17.4 17.2 17.4 17.5 9.3 9.0 9.8 9.8 10.1

Rating 18.8 18.8 18.8 18.8 18.8 20.9 20.9 20.9 20.9 20.9

Load 18.1 - - - - 17.1 21.3 - - -

Rating 26.2 - - - - 29.1 29.1 - - -

Load - 24.2 24.1 24.1 24.4 - - 24.1 24.1 24.0

Rating - 42.5 42.5 42.5 42.5 - - 45.2 45.2 45.2

Load - 24.2 24.1 24.1 24.4 - - 24.1 24.1 24.0

Rating - 42.5 42.5 42.5 42.5 - - 45.2 45.2 45.2

Newcastle Inner City Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER H769 Merewether STS to Carrington 33kV

FEEDER 3809 Carrington to Newcastle CBD 33kV

FEEDER H770 Merewether STS to Newcastle CBD 33kV

FEEDER H764 Merewether STS to Newcastle CBD 33kV

FEEDER H776 Merewether STS to Newcastle CBD 33kV

FEEDER 762 Merewether STS to New Lambton 33kV

FEEDER H773 Merewether STS to Kotara 33kV

FEEDER H775 Merewether STS to Kotara 33kV

FEEDER H768 Merewether STS to New Lambton 33kV

FEEDER H763 Merewether STS to Carrington 33kV

FEEDER H763 Merewether STS to Tighes Hill 33kV

FEEDER H769 Merewether STS to Tighes Hill 33kV

Page D15 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 37.0 36.3 35.9 35.6 35.7 36.3 35.7 35.3 35.3 35.5

Rating 249.0 249.0 249.0 249.0 249.0 271.0 271.0 271.0 271.0 271.0

Load 38.0 37.3 36.8 36.5 36.6 36.4 35.8 36.2 36.2 36.4

Rating 214.0 214.0 214.0 214.0 214.0 240.0 240.0 240.0 240.0 240.0

Load 36.9 36.2 35.8 35.5 35.6 36.3 35.6 35.2 34.8 35.4

Rating 214.0 214.0 214.0 214.0 214.0 240.0 240.0 240.0 240.0 240.0

Load 8.1 8.1 8.1 8.1 8.1 9.2 9.2 9.3 9.3 9.3

Rating 214.0 214.0 214.0 214.0 214.0 240.0 240.0 240.0 240.0 240.0

Load 8.1 8.1 8.1 8.1 8.1 9.2 9.2 9.3 9.3 9.3

Rating 214.0 214.0 214.0 214.0 214.0 240.0 240.0 240.0 240.0 240.0

Load 8.3 8.3 8.3 8.3 8.3 8.5 8.5 8.5 8.5 8.5

Rating 30.4 30.4 30.4 30.4 30.4 33.8 33.8 33.8 33.8 33.8

FEEDER 96Y Waratah West BSP to Mayfield West 132kV

FEEDER 97M Kooragang STS to Mayfield West 132kV

Newcastle Ports Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 97W Mayfield West to BHP Onesteel 132kV

FEEDER 33730 Kooragang STS to Hexham SS 33kV

FEEDER 96X Waratah West BSP to Kooragang 132kV

FEEDER 97Z Mayfield West to BHP Onesteel 132kV

Page D16 of D40

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Load 23.9 24.6 24.9 25.3 25.5 14.9 16.4 16.9 17.1 17.4

Rating 33.5 33.5 33.5 33.5 33.5 37.0 37.0 37.0 37.0 37.0

Load 4.3 4.3 4.3 4.3 4.3 3.4 3.4 3.4 3.4 3.4

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 29.7 30.5 31.1 31.5 31.9 17.7 18.1 18.7 19.1 19.4

Rating 33.5 33.5 33.5 33.5 33.5 37.0 37.0 37.0 37.0 37.0

Load 29.0 29.8 30.4 30.7 31.1 17.6 18.0 18.5 18.9 19.2

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 4.2 4.2 4.2 4.2 4.2 3.4 3.4 3.2 3.3 3.2

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 4.2 4.3 4.2 4.2 4.2 3.4 3.4 3.4 3.4 3.4

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 23.5 24.2 24.6 24.9 25.2 14.9 16.4 16.7 16.9 17.2

Rating 33.5 33.5 33.5 33.5 33.5 37.0 37.0 37.0 37.0 37.0

Load 28.8 29.5 30.1 30.7 30.8 17.6 18.0 19.3 19.7 20.0

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

FEEDER 80266 Argenton STS to Cardiff 33kV

FEEDER 80258 Argenton STS to Edgeworth 33kV

FEEDER 80262(2) tee to Edgeworth 33kV

FEEDER 80262(3) tee to Stockton Borehole 33kV

FEEDER H732 Awaba STS to Stockton Borehole 33kV

FEEDER 80252 Argenton STS to Cardiff 33kV

FEEDER 3587 Edgeworth to West Wallsend Colliery 33kV

FEEDER 80262(1) Argenton STS to Edgeworth and Stockton Borehole 33kV

Newcastle Western Corridor Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Page D17 of D40

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Load 20.5 20.6 20.7 21.0 21.2 16.0 15.4 15.8 15.8 16.2

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 24.8 24.9 25.1 25.4 25.9 23.1 22.8 22.7 23.1 23.6

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 28.7 28.3 28.2 28.4 28.8 27.5 27.2 26.7 26.9 27.4

Rating 42.1 42.1 42.1 42.1 42.1 45.0 45.0 45.0 45.0 45.0

Load 24.5 24.6 25.0 25.1 25.6 22.6 22.3 22.5 22.9 23.4

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 22.9 22.6 22.5 22.7 23.0 21.6 21.3 21.1 21.2 21.7

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 20.2 20.3 20.6 20.7 20.8 16.1 15.5 15.5 15.5 15.8

Rating 49.3 49.3 49.3 49.3 49.3 53.7 53.7 53.7 53.7 53.7

Load 20.0 20.0 20.3 20.3 20.4 15.6 15.3 15.7 15.8 16.1

Rating 29.5 29.5 29.5 29.5 29.5 32.2 32.2 32.2 32.2 32.2

Load 12.1 12.3 12.5 12.7 12.9 11.5 11.4 11.7 11.9 12.1

Rating 16.8 16.8 16.8 16.8 16.8 18.7 18.7 18.7 18.7 18.7

Load 11.8 12.0 12.3 12.5 12.7 11.4 11.3 11.5 11.7 11.9

Rating 16.8 16.8 16.8 16.8 16.8 18.7 18.7 18.7 18.7 18.7

Load 24.0 24.2 24.3 24.6 25.1 22.7 22.5 22.1 22.5 23.0

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 23.8 23.6 23.7 23.9 24.4 22.3 22.0 21.5 21.7 22.1

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 27.3 26.9 26.8 26.9 27.3 25.7 25.4 25.1 25.4 25.9

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 18.8 18.8 19.0 19.0 19.2 14.7 14.4 14.8 14.8 15.1

Rating 29.5 29.5 29.5 29.5 29.5 32.2 32.2 32.2 32.2 32.2

North East Lake Macquarie Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 80255 Argenton STS to Croudace Bay 33kV

FEEDER 3239(2) Gateshead to Pelican and Croudace Bay 33kV

FEEDER 766 Merewether STS to Gateshead 33kV

FEEDER 3231 Jewells to Pelican 33kV

FEEDER 760 Merewether STS to Jewells 33kV

FEEDER 34405 Mt Hutton to Croudace Bay 33kV

FEEDER 80249 Argenton STS to Mt Hutton 33kV

FEEDER 3691 Pelican to Swansea 33kV

FEEDER 3240 Pelican to Swansea 33kV

FEEDER 80263 Argenton STS to Mt Hutton 33kV

FEEDER 3239(1) Gateshead to Pelican 33kV

FEEDER 3431 Gateshead to Jewells 33kV

FEEDER 772 Merewether STS to Gateshead 33kV

Page D18 of D40

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Load 209.1 246.7 249.2 218.8 222.3 171.9 201.0 199.8 171.9 175.7

Rating 275.0 275.0 275.0 275.0 275.0 302.0 302.0 302.0 302.0 302.0

Load 205.1 239.1 241.6 213.5 216.8 170.1 198.0 196.5 170.0 173.7

Rating 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6

Load 168.0 203.4 206.2 177.8 180.6 136.0 164.3 163.2 136.4 139.6

Rating 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6 228.6

Load 113.3 121.6 122.2 116.5 118.6 105.2 111.5 111.3 106.1 108.5

Rating 275.0 275.0 275.0 275.0 275.0 285.8 285.8 285.8 285.8 285.8

Load 11.4 11.9 12.2 12.4 12.6 9.7 9.7 9.7 9.8 10.0

Rating 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6

Load 11.4 11.9 12.2 12.4 12.6 9.7 9.7 9.7 9.8 10.0

Rating 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6 68.6

North West Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

250 (Sydney North to Berowra) 132

251 (Sydney North to Pennant Hills) 132

252 (Berowra to Hornsby) 132

253 (Pennant Hills to Hornsby) 132

257 (Sydney North to Galston) 132

258 (Sydney North to Galston) 132

Page D19 of D40

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Load 26.8 27.4 27.8 28.3 28.9 33.1 33.4 33.9 34.7 35.6

Rating 54.0 54.0 54.0 54.0 54.0 57.2 57.2 57.2 57.2 57.2

Load 26.4 26.9 27.3 27.8 28.4 33.2 32.9 33.4 34.1 34.9

Rating 61.7 61.7 61.7 61.7 61.7 67.2 67.2 67.2 67.2 67.2

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 37.1 37.1 37.1 37.1 37.1 42.8 42.8 42.8 42.8 42.8

Load 16.1 16.5 16.7 16.9 17.0 20.0 20.0 20.1 20.4 20.7

Rating 47.8 47.8 47.8 47.8 47.8 52.1 52.1 52.1 52.1 52.1

Load 12.5 12.9 13.1 13.4 13.9 14.1 14.3 14.7 15.0 15.6

Rating 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9

Load 32.1 32.7 33.2 33.7 34.4 39.9 40.1 40.7 41.6 42.5

Rating 53.8 53.8 53.8 53.8 53.8 57.2 57.2 57.2 57.2 57.2

Load 31.7 32.6 33.1 33.7 33.8 39.9 40.2 40.7 40.8 41.7

Rating 60.1 60.1 60.1 60.1 60.1 65.5 65.5 65.5 65.5 65.5

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 61.7 61.7 61.7 61.7 61.7 67.2 67.2 67.2 67.2 67.2

Load 12.4 12.7 13.0 13.3 13.8 14.1 14.3 14.6 15.0 15.4

Rating 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9 42.9

Load 30.9 32.1 32.6 32.9 33.4 39.3 39.5 39.5 40.3 41.1

Rating 61.7 61.7 61.7 61.7 61.7 67.2 67.2 67.2 67.2 67.2

Load 29.3 29.6 29.9 30.5 31.0 31.0 31.1 31.5 32.2 32.8

Rating 51.6 51.6 51.6 51.6 51.6 57.2 57.2 57.2 57.2 57.2

Load 35.0 35.3 35.7 36.3 36.8 37.7 38.0 38.4 39.2 40.1

Rating 66.0 66.0 66.0 66.0 66.0 68.6 68.6 68.6 68.6 68.6

Load 33.7 33.8 34.4 34.8 35.3 42.8 41.8 42.3 43.1 44.0

Rating 55.0 55.0 55.0 55.0 55.0 61.1 61.1 61.1 61.1 61.1

Load 17.7 18.0 18.2 18.6 18.8 27.8 28.0 28.4 28.9 29.4

Rating 44.3 44.3 44.3 44.3 44.3 49.3 49.3 49.3 49.3 49.3

Load 17.6 17.8 18.0 18.3 18.6 27.6 27.8 28.1 28.6 29.1

Rating 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4 51.4

Load 17.2 17.5 17.7 18.0 18.2 17.2 17.0 17.2 17.6 17.9

Rating 31.7 31.7 31.7 31.7 31.7 34.3 34.3 34.3 34.3 34.3

Load 17.6 17.5 17.7 18.1 18.4 27.7 27.9 28.2 28.8 29.3

Rating 39.8 39.8 39.8 39.8 39.8 45.0 45.0 45.0 45.0 45.0

Load 17.1 17.3 17.6 17.7 18.1 17.0 17.1 17.2 17.6 17.9

Rating 31.7 31.7 31.7 31.7 31.7 34.3 34.3 34.3 34.3 34.3

Load 17.0 17.3 17.5 17.9 18.1 17.1 17.1 17.3 17.6 18.0

Rating 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3

Load 8.5 8.5 8.5 8.7 8.9 13.2 13.4 13.6 13.8 14.0

Rating 20.0 20.0 20.0 20.0 20.0 26.7 26.7 26.7 26.7 26.7

Load 8.7 8.6 8.7 8.9 9.0 13.3 13.4 13.6 13.9 14.1

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Pittwater & Terrey Hills Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Feeder S20(1) (Sydney East BSP to S20 Tee1) 33

Feeder S20(2) (S20 Tee1 to S20 Tee2) 33

Feeder S20(3) (S20 Tee1 to CP Belrose ZS) 33

Feeder S20(4) (S20 Tee2 to Warriewood STSS) 33

Feeder S20(5) (S20 Tee2 to Narrabeen ZS) 33

Feeder S21(1) (Sydney East BSP to S21 Tee1) 33

Feeder S21(2) (S21 Tee1 to S21 Tee2) 33

Feeder S21(3) (S21 Tee1 to CP Belrose ZS) 33

Feeder S21(4) (S21 Tee 2 to Narrabeen ZS) 33

Feeder S21(5) (S21 Tee 2 to Warriewood STSS) 33

Feeder S22 (Sydney East BSP to Terrey Hills ZS) 33

Feeder S24 (Sydney East BSP to Terrey Hills ZS) 33

Feeder S40 (Warriewood STSS to Terrey Hills ZS) 33

Feeder S42(1) (Warriewood STSS to S42 Tee) 33

Feeder S42(2) (S42 Tee to Newport ZS) 33

Feeder S43 (Warriewood STSS to Mona Vale ZS) 33

Feeder S44 (Warriewood STSS to Newport ZS) 33

Feeder S45 (Warriewood STSS to Mona Vale ZS) 33

Feeder S46 (Warriewood STSS to Mona Vale ZS) 33

Feeder S47 (Newport ZS to Careel Bay ZS) 33

Feeder S50 (Newport ZS to Careel Bay ZS) 33

Page D20 of D40

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Load 17.6 17.7 17.8 18.1 17.6 16.5 16.0 15.9 16.0 15.8

Rating 44.8 44.8 44.8 44.8 44.8 47.5 47.5 47.5 47.5 47.5

Load 14.3 14.4 14.6 15.3 15.2 13.5 13.1 13.0 13.1 12.4

Rating 37.7 37.7 37.7 37.7 37.7 40.0 40.0 40.0 40.0 40.0

Load 8.3 8.3 8.8 8.9 9.2 6.5 6.6 6.8 7.0 6.9

Rating 19.5 19.5 19.5 19.5 19.5 21.4 21.4 21.4 21.4 21.4

Load 8.2 8.8 8.6 8.8 9.0 6.5 6.6 6.8 7.0 8.0

Rating 11.6 11.6 11.6 11.6 11.6 20.0 20.0 20.0 20.0 20.0

Load 8.2 8.4 8.7 8.9 8.9 7.3 7.4 7.5 7.7 7.8

Rating 20.0 20.0 20.0 20.0 20.0 25.0 25.0 25.0 25.0 25.0

Load 26.9 27.2 27.4 27.1 27.4 17.4 22.2 22.2 22.6 23.4

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 20.3 20.7 20.3 20.6 21.3 15.9 16.0 16.2 16.7 17.5

Rating 26.6 26.6 26.6 26.6 26.6 30.8 30.8 30.8 30.8 30.8

Load 12.1 12.1 12.2 12.4 12.7 9.5 9.4 9.5 9.6 10.3

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 6.1 6.0 5.9 5.9 5.9 6.3 6.2 6.2 6.3 6.6

Rating 43.3 43.3 43.3 43.3 43.3 46.0 46.0 46.0 46.0 46.0

Load 1.2 1.2 1.2 1.2 1.2 1.4 1.4 1.4 1.4 1.4

Rating 11.8 11.8 11.8 11.8 11.8 20.0 20.0 20.0 20.0 20.0

Load 1.5 1.5 1.5 1.5 1.5 1.2 1.2 1.2 1.2 1.2

Rating 11.8 11.8 11.8 11.8 11.8 20.0 20.0 20.0 20.0 20.0

Load 5.4 5.4 5.4 5.5 5.4 3.9 3.9 3.9 3.9 3.9

Rating 18.8 18.8 18.8 18.8 18.8 20.9 20.9 20.9 20.9 20.9

Load 4.4 4.4 4.4 4.4 4.4 2.3 2.3 2.3 2.4 2.6

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 20.2 20.1 20.3 20.9 21.1 19.0 17.6 17.4 17.5 17.2

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 8.4 8.8 9.1 9.1 9.5 7.4 7.5 7.6 7.8 8.1

Rating 19.8 19.8 19.8 19.8 19.8 22.1 22.1 22.1 22.1 22.1

Load 11.1 11.1 11.2 11.3 11.5 10.2 10.2 10.0 10.1 10.3

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 17.7 18.0 18.3 18.9 18.9 16.9 16.4 16.3 16.5 16.7

Rating 49.2 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 5.2 5.3 5.3 5.3 5.4 3.2 3.1 3.2 3.2 3.4

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 12.1 12.2 12.3 12.5 12.8 9.4 9.4 9.4 9.6 10.4

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 6.1 6.0 5.9 5.9 6.0 6.3 6.2 6.2 6.3 6.7

Rating 43.3 43.3 43.3 43.3 43.3 46.0 46.0 46.0 46.0 46.0

Load 19.9 20.3 20.6 20.7 21.4 - 16.0 16.2 16.6 17.3

Rating 31.1 31.1 31.1 31.1 31.1 - 41.3 41.3 41.3 41.3

Load 27.3 26.8 27.0 27.3 27.7 18.0 22.4 22.4 22.8 23.7

Rating 30.2 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Port Stephens Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER TM9 Tomago STS to Nelson Bay 33kV

FEEDER 33366 Nelson Bay to Tomaree 33kV

FEEDER 3305 Williamtown to Stockton 33kV

FEEDER 3301 Williamtown to Stockton 33kV

FEEDER 81401 Medowie to Tanilba Bay 33kV

FEEDER TM7 Tomago STS to Williamtown 33kV

FEEDER TM4 Tomago STS to Medowie 33kV

FEEDER TM12 Tomago STS to Raymond Terrace 33kV

FEEDER TM3 Tomago STS to Tomago 33kV

FEEDER TM8 Tomago STS to Hunter Water Corp 33kV

FEEDER TM11 Tomago STS to Hunter Water Corp 33kV

FEEDER 34084 Williamtown to Williamtown RAAF 33kV

FEEDER 83241 AGL Tomago SS to Raymond Terrace 33kV

FEEDER TM2 Tomago STS to Nelson Bay 33kV

FEEDER 3300(3) tee to Tanilba Bay 33kV

FEEDER 3300(2) tee to Tomaree 33kV

FEEDER 3300(1) Williamtown to Tomaree and Tanilba Bay 33kV

FEEDER TM5 Tomago STS to AGL Tomago SS 33kV

FEEDER TM10 Tomago STS to Williamtown 33kV

FEEDER TM1 Tomago STS to Raymond Terrace 33kV

FEEDER TM6 Tomago STS to Tomago 33kV

FEEDER TM13 Tomago STS to Medowie 33kV

Page D21 of D40

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Load 12.8 12.8 12.9 13.0 13.3 8.9 9.0 9.1 9.4 9.6

Rating 42.1 42.1 42.1 42.1 42.1 55.0 55.0 55.0 55.0 55.0

Load 39.2 39.2 39.2 39.1 39.5 43.6 43.6 43.8 43.8 43.6

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 36.7 36.8 36.8 36.7 37.0 41.4 41.4 41.5 41.5 41.4

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 0.5 0.5 0.4 0.6 0.5 0.3 0.3 0.3 0.3 0.3

Rating 39.1 39.1 39.1 39.1 39.1 51.2 51.2 51.2 51.2 51.2

Load 76.4 76.4 76.4 76.8 76.7 69.6 73.1 73.0 73.3 73.7

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 23.8 23.8 23.8 23.8 23.7 25.2 25.2 25.2 25.2 25.1

Rating 93.7 93.7 93.7 93.7 93.7 127.3 127.3 127.3 127.3 127.3

Load 9.7 9.8 9.8 9.8 9.7 9.9 9.6 9.7 9.6 9.6

Rating 15.0 15.0 15.0 15.0 15.0 38.3 38.3 38.3 38.3 38.3

Load 38.0 38.0 37.8 38.0 38.2 42.2 42.2 42.2 42.2 42.2

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 19.6 19.6 19.5 19.6 19.7 23.7 23.7 23.7 23.7 23.7

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 14.8 14.8 14.8 14.8 14.8 20.5 20.3 20.4 20.3 20.3

Rating 114.0 114.0 114.0 114.0 114.0 124.0 124.0 124.0 124.0 124.0

Load 47.8 47.9 47.9 48.4 48.6 41.7 38.5 38.5 38.7 39.4

Rating 83.1 83.1 83.1 83.1 83.1 112.0 112.0 112.0 112.0 112.0

Load 39.1 39.1 39.3 40.0 40.0 27.3 27.4 27.6 27.9 28.5

Rating 93.7 93.7 93.7 93.7 93.7 127.3 127.3 127.3 127.3 127.3

Load 30.1 30.3 30.3 30.5 30.6 29.3 26.5 26.6 26.8 27.2

Rating 83.0 83.0 83.0 83.0 83.0 112.0 112.0 112.0 112.0 112.0

Load 11.9 12.0 12.0 12.0 11.9 13.2 12.9 13.0 12.9 12.9

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load - - - - - 34.7 - - - -

Rating - - - - - 82.9 - - - -

Load 2.2 2.2 2.2 2.2 2.2 4.3 4.2 4.2 4.2 4.2

Rating 39.1 39.1 39.1 39.1 39.1 51.2 51.2 51.2 51.2 51.2

Load 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6

Rating 72.0 72.0 72.0 72.0 72.0 89.7 89.7 89.7 89.7 89.7

Load 2.0 2.0 2.0 2.0 2.0 2.6 2.5 2.5 2.5 2.5

Rating 34.3 34.3 34.3 34.3 34.3 45.7 45.7 45.7 45.7 45.7

Load 9.7 9.4 9.7 8.3 8.4 7.4 7.4 7.7 7.7 8.0

Rating 39.1 39.1 39.1 39.1 39.1 51.2 51.2 51.2 51.2 51.2

Load 8.2 8.3 8.3 8.3 8.2 8.4 8.3 8.4 8.4 8.3

Rating 109.0 109.0 109.0 109.0 109.0 138.0 138.0 138.0 138.0 138.0

Load 5.9 5.9 5.9 5.9 5.9 5.8 5.7 5.8 5.7 5.7

Rating 15.0 15.0 15.0 15.0 15.0 38.3 38.3 38.3 38.3 38.3

Load 9.0 9.1 9.1 9.1 9.0 8.6 8.4 8.4 8.4 8.4

Rating 21.1 21.1 21.1 21.1 21.1 62.0 62.0 62.0 62.0 62.0

Load 3.1 3.1 3.1 3.1 3.1 3.3 3.2 3.2 3.2 3.2

Rating 42.1 42.1 42.1 42.1 42.1 55.0 55.0 55.0 55.0 55.0

Load 0.0 0.0 0.0 0.0 0.0 0.2 0.2 0.2 0.2 0.2

Rating 39.1 39.1 39.1 39.1 39.1 51.2 51.2 51.2 51.2 51.2

Singleton Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 66011(4) Singleton to Branxton and Mt Thorley(tee Branxton) 66kV

FEEDER 6011(7) Singleton STS to Lemington (tee Lemington) 66kV

FEEDER 60208(5) Newdell to Lemington(tee Lemington) 66kV

FEEDER 66011(3) Singleton to Branxton and Mt Thorley(tee Mitchells Flat) 66kV

FEEDER Singleton STS to Mt Thorley 66kV

FEEDER 66090 Mt Thorley to Warkworth Mine 66kV

FEEDER 66092 Mt Thorley to Mt Thorley Mine 66kV

FEEDER 6017(5) Singleton STS to Newdell(tee Newdell) 66kV

FEEDER 60208(1) Newdell to Lemington(tee to Newdell) 66kV

FEEDER 60200 Newdell to Ravensworth North Mine 66kV

FEEDER 6012(9) Singleton STS to Singleton North (tee Singleton North) 66kV

FEEDER 66011(1) Singleton to Branxton and Mt Thorley(tee Singleton) 66kV

FEEDER 33474 Singleton to Singleton North 66kV

FEEDER 6017(2) Singleton STS to Newdell(tee to Ashton Mine) 66kV

FEEDER 66011(7) Singleton to Branxton and Mt Thorley(tee to Bulga Coal) 66kV

FEEDER 6012(5) Singleton STS to Singleton North(tee to Camberwell Coal) 66kV

FEEDER 6017(4) Singleton STS to Newdell(tee to Glendell Mine) 66kV

FEEDER 6012(7) Singleton STS to Singleton North(tee to Glennies Ck Mine) 66kV

FEEDER 6012(8) Singleton STS to Singleton North(tee to Glennies Ck Generator) 66kV

FEEDER 60208(6) Newdell to Lemington(tee to Hunter Valley CPP) 66kV

FEEDER 6011(2) Singleton STS to Lemington(tee to Lemington Mine) 66kV

FEEDER 60208(2) Newdell to Lemington(tee to Newdell Mine) 66kV

FEEDER 6012(2) Singleton STS to Singleton North(tee to Rixs Creek Coal) 66kV

FEEDER 6011(10) Singleton STS to Lemington(tee to South Lemington Mine) 66kV

Page D22 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Singleton Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Load 0.7 0.7 0.7 0.7 0.7 0.6 0.6 0.6 0.6 0.6

Rating 42.1 42.1 42.1 42.1 42.1 55.0 55.0 55.0 55.0 55.0

Load 19.9 20.0 20.0 20.0 19.9 19.6 19.3 19.3 19.3 19.3

Rating 42.1 42.1 42.1 42.1 42.1 55.0 55.0 55.0 55.0 55.0

Load 61.1 61.1 61.1 61.1 61.6 65.0 65.0 65.4 65.3 65.1

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 66.5 66.5 66.6 66.5 67.0 70.1 70.1 70.5 70.4 70.2

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 20.2 20.2 20.2 20.3 20.2 20.1 19.7 19.7 19.7 19.7

Rating 37.0 37.0 37.0 37.0 37.0 48.6 48.6 48.6 48.6 48.6

Load 40.7 40.7 40.7 40.6 41.1 45.1 45.1 45.4 45.3 45.1

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 45.8 45.8 45.8 46.2 46.3 42.1 38.8 38.8 39.1 39.6

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 48.9 48.9 48.9 49.3 49.4 45.3 42.0 42.0 42.3 42.8

Rating 94.0 94.0 94.0 94.0 94.0 127.0 127.0 127.0 127.0 127.0

Load 7.0 6.9 6.8 6.7 6.3 7.7 6.7 6.5 6.9 6.9

Rating 39.1 39.1 39.1 39.1 39.1 51.2 51.2 51.2 51.2 51.2

Load 7.8 7.5 7.7 6.7 6.4 6.8 6.3 6.2 6.6 6.5

Rating 34.3 34.3 34.3 34.3 34.3 48.1 48.1 48.1 48.1 48.1

Load 39.3 39.3 39.1 39.3 39.5 43.6 43.6 43.6 43.6 43.6

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 51.0 51.0 50.8 51.0 51.2 56.3 56.3 56.3 56.3 56.3

Rating 83.0 83.0 83.0 83.0 83.0 112.0 112.0 112.0 112.0 112.0

Load 77.7 77.7 77.7 78.0 78.1 70.5 74.0 74.0 74.4 74.8

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 28.0 28.0 27.9 27.9 28.2 32.5 32.5 32.6 32.5 32.5

Rating 88.4 88.4 88.4 88.4 88.4 120.0 120.0 120.0 120.0 120.0

Load 52.5 52.7 52.7 53.7 53.9 36.3 36.5 36.9 37.3 38.2

Rating 93.7 93.7 93.7 93.7 93.7 127.3 127.3 127.3 127.3 127.3

Load 13.5 13.5 13.5 13.8 13.9 9.2 9.3 9.4 9.7 10.0

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 0.0 0.0 0.0 0.0 0.0 35.2 0.0 0.0 0.0 0.0

Rating 39.1 39.1 39.1 39.1 39.1 51.3 51.3 51.3 51.3 51.3

Load 54.2 54.5 54.5 55.4 55.6 72.1 37.1 38.2 37.9 38.8

Rating 93.7 93.7 93.7 93.7 93.7 127.3 127.3 127.3 127.3 127.3

Load 75.6 75.7 75.6 75.9 75.9 68.9 72.3 72.3 72.6 73.0

Rating 93.6 93.6 93.6 93.6 93.6 127.0 127.0 127.0 127.0 127.0

Load 32.8 32.7 32.6 32.8 32.6 - 35.5 35.6 35.5 35.6

Rating 62.3 62.3 62.3 62.3 62.3 - 82.9 82.9 82.9 82.9

FEEDER 6011(6) Singleton STS to Lemington(tee to United Colliery) 66kV

FEEDER 6011(8) Singleton STS to Lemington(tee to Wambo Mine) 66kV

Lemington(tee to Wambo, United and Lemington) 66kV

FEEDER 6011(1) Singleton STS to Lemington 66kV

Lemington (tee to Wambo and South Lemington) 66kV

FEEDER 6011(5) Singleton STS to Lemington(tee to United and Lemington) 66kV

Singleton North(tee to Camberwell and Singleton North) 66kV

FEEDER 6012(1) Singleton STS to Singleton North 66kV

Singleton North(tee to Camberwell and Glennies Creek) 66kV

Singleton North(tee to Glennies Ck Mine and Generator) 66kV

FEEDER 6017(3) Singleton STS to Newdell(tee Glendell and Newdell) 66kV

FEEDER 6017(1) Singleton STS to Newdell 66kV

FEEDER 6018 Singleton STS to Mt Thorley 66kV

Lemington(tee to Hunter Valley and Lemington) 66kV

FEEDER 66011(5) Singleton to Branxton and Mt Thorley(tee to Bulga and Mt Thorley) 66kV

FEEDER 6019 Singleton STS to Mt Thorley 66kV

FEEDER 66227 Mt Thorley to Bulga Coal 66kV

FEEDER 66011(2) Singleton to Branxton and Mt Thorley(tee to Mitchells Flat and Branxton) 66kV

FEEDER 66011(6) Singleton to Branxton and Mt Thorley(tee to Bulga Coal) 66kV

FEEDER 66011(10) Singleton to Branxton and Mt Thorley(tee to Mt Thorley) 66kV

Page D23 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 116.5 143.2 154.1 155.2 158.5 94.6 97.9 134.3 131.0 134.0

Rating 296.0 296.0 296.0 296.0 296.0 312.0 312.0 312.0 312.0 312.0

Load 116.5 143.2 154.1 155.1 158.5 94.5 97.9 134.3 131.0 134.0

Rating 296.0 296.0 296.0 296.0 296.0 312.0 312.0 312.0 312.0 312.0

Load 67.8 67.5 66.7 66.9 68.1 71.7 72.7 72.8 73.7 74.9

Rating 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0

Load 67.7 83.3 86.1 86.5 88.5 71.7 72.5 83.7 83.0 84.8

Rating 197.0 197.0 197.0 197.0 197.0 208.0 208.0 208.0 208.0 208.0

Load 56.6 53.9 62.3 62.9 63.8 43.8 47.8 53.9 51.7 52.7

Rating 197.0 197.0 197.0 197.0 197.0 208.0 208.0 208.0 208.0 208.0

Load 55.1 52.9 61.8 62.1 63.8 42.6 46.0 53.3 50.5 51.7

Rating 253.0 253.0 253.0 253.0 253.0 260.0 260.0 260.0 260.0 260.0

Load 16.2 15.5 15.2 15.2 15.6 18.9 18.8 18.9 19.2 19.6

Rating 26.9 26.9 26.9 26.9 26.9 28.3 28.3 28.3 28.3 28.3

Load 16.2 15.5 15.3 15.2 15.6 18.9 18.8 18.9 19.2 19.6

Rating 26.8 26.8 26.8 26.8 26.8 28.2 28.2 28.2 28.2 28.2

Load 11.9 11.6 11.6 11.6 11.8 14.4 14.1 14.0 14.1 14.4

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 11.8 11.2 10.8 10.8 11.0 11.0 10.6 10.5 10.5 10.7

Rating 34.3 34.3 34.3 34.3 34.3 37.2 37.2 37.2 37.2 37.2

Load 11.8 11.2 10.8 10.8 11.0 11.0 10.6 10.5 10.5 10.7

Rating 34.3 34.3 34.3 34.3 34.3 37.2 37.2 37.2 37.2 37.2

Load 11.7 11.0 10.7 10.9 10.9 11.2 10.7 10.5 10.6 10.8

Rating 34.3 34.3 34.3 34.3 34.3 37.2 37.2 37.2 37.2 37.2

Load 18.7 17.6 17.0 16.9 17.2 20.6 19.9 19.7 19.7 20.1

Rating 35.4 35.4 35.4 35.4 35.4 37.3 37.3 37.3 37.3 37.3

Load 18.5 17.5 17.0 16.7 17.1 20.5 19.8 19.6 19.6 20.0

Rating 35.4 35.4 35.4 35.4 35.4 37.3 37.3 37.3 37.3 37.3

Load 18.7 17.9 17.0 16.9 17.3 20.6 20.0 19.7 19.7 20.1

Rating 35.4 35.4 35.4 35.4 35.4 37.3 37.3 37.3 37.3 37.3

Load 12.2 11.9 11.8 11.8 12.1 14.7 14.3 14.3 14.3 14.6

Rating 26.9 26.9 26.9 26.9 26.9 28.6 28.6 28.6 28.6 28.6

Load 15.3 14.8 14.6 14.7 15.0 15.6 15.4 15.3 15.4 15.7

Rating 21.0 21.0 21.0 21.0 21.0 22.1 22.1 22.1 22.1 22.1

Load 15.4 15.0 14.8 14.9 15.1 15.9 15.5 15.4 15.6 15.9

Rating 21.0 21.0 21.0 21.0 21.0 22.1 22.1 22.1 22.1 22.1

Load 18.8 18.0 17.4 17.3 17.7 20.9 20.7 20.1 20.0 20.4

Rating 36.1 36.1 36.1 36.1 36.1 44.3 44.3 44.3 44.3 44.3

Load 18.8 17.9 17.4 17.3 17.6 20.8 20.6 20.1 20.0 20.4

Rating 36.1 36.1 36.1 36.1 36.1 44.3 44.3 44.3 44.3 44.3

St George Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Feeder 907 (Canterbury STS to Kogarah ZS) 132

Feeder 91W/1 (Hurstville Nth ZS to Kogarah ZS) 132

Feeder 91C (Peakhurst STS to Hurstville Nth ZS) 132

Feeder 91R (Peakhurst STS to Hurstville Nth ZS) 132

Feeder 91H/1 (Hurstville Nth ZS to 91Htee) 132

Feeder 91H/2 (91Htee to Rockdale ZS) 132

Feeder 769 (Peakhurst STS to Blakehurst ZS) 33

Feeder 770 (Peakhurst STS to Blakehurst ZS) 33

Feeder 777 (Blakehurst to Sans Souci ZS) 33

Feeder 778 (Peakhurst STS to Riverwood ZS) 33

Feeder 670 (Peakhurst STS to Riverwood ZS) 33

Feeder 779 (Peakhurst STS to Riverwood ZS) 33

Feeder 785 (Peakhurst STS to Mortdale ZS) 33

Feeder 765 (Peakhurst STS to Mortdale ZS) 33

Feeder 786 (Peakhurst STS to Mortdale ZS) 33

Feeder 706 (Peakhurst STS to Sans Souci ZS) 33

Feeder 767 (Peakhurst STS to Arncliffe ZS) 33

Feeder 768 (Peakhurst STS to Arncliffe ZS) 33

Feeder 775 (Peakhurst STS to Rockdale ZS) 33

Feeder 776 (Peakhurst STS to Rockdale ZS) 33

Page D24 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 80.8 83.4 84.6 86.1 88.0 101.3 102.8 103.3 104.5 106.9

Rating 260.0 260.0 260.0 260.0 260.0 283.7 283.7 283.7 283.7 283.7

Load 45.9 47.6 47.9 48.6 49.8 60.6 62.3 62.7 63.3 64.8

Rating 275.0 275.0 275.0 275.0 275.0 340.4 340.4 340.4 340.4 340.4

Load 163.0 165.0 166.3 168.3 171.5 131.9 164.3 165.2 167.2 170.8

Rating 239.6 239.6 239.6 239.6 239.6 259.0 259.0 259.0 259.0 259.0

Load 32.0 31.3 31.2 31.3 31.9 13.4 30.5 30.7 31.0 31.6

Rating 41.2 41.2 41.2 41.2 41.2 41.5 44.6 44.6 44.6 44.6

Load 37.0 38.4 39.1 39.7 40.3 30.3 30.8 31.1 31.5 32.1

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 32.0 31.3 31.2 31.3 31.9 13.1 30.5 30.7 31.0 31.6

Rating 44.0 44.0 44.0 44.0 44.0 44.4 45.7 45.7 45.7 45.7

Load 10.7 10.8 11.0 11.3 11.6 12.5 12.6 12.8 13.1 13.4

Rating 46.8 46.8 46.8 46.8 46.8 57.3 57.3 57.3 57.3 57.3

Load 10.8 10.9 11.1 11.4 11.7 12.6 12.7 12.9 13.2 13.5

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 7.9 8.0 8.0 8.0 7.9 4.4 8.7 8.7 8.7 8.7

Rating 16.8 16.8 16.8 16.8 16.8 15.8 20.5 20.5 20.5 20.5

Load 6.2 6.2 6.2 6.2 6.1 2.3 6.5 6.5 6.5 6.5

Rating 16.2 16.2 16.2 16.2 16.2 14.6 17.6 17.6 17.6 17.6

Load 2.1 2.1 2.1 2.1 2.1 2.3 2.3 2.3 2.3 2.3

Rating 20.0 20.0 20.0 20.0 20.0 23.7 23.7 23.7 23.7 23.7

Load 169.1 172.6 174.1 176.5 179.7 169.4 188.1 189.4 191.6 195.9

Rating 194.3 220.6 220.6 220.6 220.6 204.6 204.6 257.1 257.1 257.1

Load 161.0 162.9 188.2 191.2 196.4 156.9 161.5 177.9 181.5 185.3

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 109.9 106.6 129.3 131.7 134.2 110.0 107.4 114.3 115.7 118.0

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 82.8 85.5 86.8 88.5 90.2 103.9 105.4 106.0 107.2 109.7

Rating 242.6 242.6 242.6 242.6 242.6 318.0 318.0 318.0 318.0 318.0

Load 144.8 145.7 170.8 173.6 178.1 132.9 134.5 148.0 150.7 153.8

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 118.4 116.1 139.3 141.8 144.9 116.7 116.0 126.1 128.0 130.6

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 35.7 36.8 37.7 38.4 38.9 28.4 28.3 28.5 28.9 29.5

Rating 280.0 280.0 280.0 280.0 280.0 295.0 295.0 295.0 295.0 295.0

Load 119.3 121.0 121.8 123.2 125.6 89.9 122.2 123.2 124.8 127.5

Rating 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0

Load 7.3 7.3 7.3 7.3 7.3 5.0 5.0 5.0 5.0 5.0

Rating 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0

Load 86.6 88.2 88.8 89.8 91.6 84.5 86.2 86.8 87.9 89.8

Rating 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0

Load 1.3 1.3 1.3 1.3 1.3 1.4 1.4 1.4 1.4 1.4

Rating 8.6 8.6 8.6 8.6 8.6 8.6 8.6 8.6 8.6 8.6

Load 6.2 6.2 6.2 6.2 6.1 6.5 6.5 6.5 6.5 6.5

Rating 21.7 21.7 21.7 21.7 21.7 22.9 22.9 22.9 22.9 22.9

Load 9.5 10.1 10.2 10.3 10.4 8.2 8.8 8.8 8.9 9.1

Rating 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3

Load 22.8 24.4 24.5 24.8 24.9 19.5 20.9 21.1 21.3 21.7

Rating 45.1 45.1 45.1 45.1 45.1 45.7 45.7 45.7 45.7 45.7

Sutherland Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Feeder 280 (Port Hacking STS to Kirrawee ZS) 132

Feeder 281 (Cronulla ZS to Kirrawee ZS) 132

Feeder 284 (Sydney South BSP to Menai ZS) 132

Feeder 738 (Port Hacking STS to Jannali ZS) 33

Feeder 730 (Port Hacking STS to Jannali ZS) 33

Feeder 724 (Port Hacking STS to Miranda ZS) 33

Feeder 725 (Port Hacking STS to Gwawley Bay ZS) 33

Feeder 726 (Port Hacking STS to Miranda ZS) 33

Feeder 749/3 (749 tee to Lucas Heights gen) 33

Feeder 749/1 (Jannali ZS to 749 tee) 33

Feeder 749/2 (749 tee to Lucas Heights) 33

Feeder 912 (Sydney South BSP to Port Hacking STS) 132

Feeder 916/1 (Sydney South BSP to 916 tee) 132

Feeder 916/2 (916 tee to Kurnell STS) 132

Feeder 916/3 (916 tee to Cronulla ZS) 132

Feeder 917 (1) (Sydney South BSP to 917 tee)

Feeder 917 (2) (917 tee to Kurnell STS)

Feeder 917 (3) (917 tee to Gwawley Bay ZS)

Feeder 285_NEW (Menai ZS to Engadine ZS)

Feeder 286 (Engadine ZS to RAC Heathcote)

Feeder 745_NEW (Gwawley Bay ZS to Caringbah ZS)

Feeder 728_NEW (Port Hacking STS to Caringbah ZS) [post kurnell busbar retirement]

Feeder 289 (Engadine ZS to Port Hacking STS)

Feeder 747_NEW (Port Hacking STS to Woronora Dam)

Feeder 750_NEW (Miranda ZS to Lucas Heights ZS)

Page D25 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 8.8 8.6 8.5 8.6 8.5 5.4 5.3 5.2 5.1 5.2

Rating 17.7 17.7 17.7 17.7 17.7 19.2 19.2 19.2 19.2 19.2

Load 8.8 8.6 8.4 8.4 8.5 5.3 5.2 5.1 5.0 5.1

Rating 14.9 14.9 14.9 14.9 14.9 16.6 16.6 16.6 16.6 16.6

Load 8.6 8.2 8.0 8.1 8.1 5.2 5.0 4.9 4.9 4.9

Rating 16.8 16.8 16.8 16.8 16.8 18.3 18.3 18.3 18.3 18.3

Load 9.0 8.6 8.5 8.5 8.5 5.4 5.3 5.1 5.1 5.1

Rating 16.8 16.8 16.8 16.8 16.8 18.3 18.3 18.3 18.3 18.3

Load 8.9 8.7 8.5 8.6 8.6 5.5 5.3 5.2 5.2 5.2

Rating 13.8 13.8 13.8 13.8 13.8 15.6 15.6 15.6 15.6 15.6

Load 8.5 8.2 8.0 8.1 8.0 5.1 5.0 4.9 4.8 4.9

Rating 17.7 17.7 17.7 17.7 17.7 19.2 19.2 19.2 19.2 19.2

Sydney CBD Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Feeder 507 (Surry Hills STS to City East ZS TxA) 33

Feeder 508 (Surry Hills STS to City East ZS TxB) 33

Feeder 509 (Surry Hills STS to City East ZS TxD) 33

Feeder 510 (Surry Hills STS to City East ZS TxF) 33

Feeder 511 (Surry Hills STS to City East ZS TxC) 33

Feeder 513 (Surry Hills STS to City East ZS TxE) 33

Page D26 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 13.6 13.5 13.5 13.6 13.7 16.3 16.3 16.5 16.6 16.9

Rating 46.7 46.7 46.7 46.7 46.7 52.8 52.8 52.8 52.8 52.8

Load 3.2 3.2 3.2 3.2 3.2 3.8 3.8 3.8 3.8 3.8

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 16.8 - - - - 19.9 - - - -

Rating 48.6 - - - - 53.0 - - - -

Load - 16.5 16.5 16.6 16.7 - 19.8 19.9 20.1 20.4

Rating - 48.6 48.6 48.6 48.6 - 53.0 53.0 53.0 53.0

Load 13.7 13.7 13.8 13.8 14.0 16.2 16.6 16.7 16.8 16.8

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 3.1 3.2 3.2 3.2 3.2 3.7 3.8 3.8 3.8 3.8

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 18.7 - - - - 20.9 - - - -

Rating 49.6 - - - - 52.1 - - - -

Load - 18.1 17.9 18.0 18.1 - 21.6 21.7 21.9 21.9

Rating - 49.6 49.6 49.6 49.6 - 52.1 52.1 52.1 52.1

Upper Central Coast Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 743/3 (Noraville to Tee Munmorah and Vales Pt) 33kV

FEEDER 743/2 (Vales Pt to Tee Munmonrah and Noraville) 33kV

FEEDER 743/1 (Munmorah South to tee) 33kV

FEEDER 744/1 (Munmorah South to Tee) 33kV

FEEDER 744/1 (Munmorah STS to Tee Vales Pt and Noraville) 33kV

FEEDER 743/1 (Munmorah STS to Tee Vales Pt and Noraville) 33kV

FEEDER 744/3 (Noraville to Tee Munmorah and Vales Pt) 33kV

FEEDER 744/2 (Vales Pt to Tee Munmorah and Noraville) 33kV

Page D27 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 0.8 0.8 0.8 0.8 0.8 0.5 0.5 0.5 0.5 0.5

Rating 5.1 5.1 5.1 5.1 5.1 10.8 10.8 10.8 10.8 10.8

Load 20.6 20.5 20.4 20.6 20.6 18.6 18.5 18.5 18.7 18.7

Rating 29.6 29.6 29.6 29.6 29.6 38.4 38.4 38.4 38.4 38.4

Load 10.7 10.8 10.7 10.7 10.7 11.6 11.5 11.5 11.5 11.5

Rating 74.2 74.2 74.2 74.2 74.2 80.8 80.8 80.8 80.8 80.8

Load 3.3 3.3 3.2 3.3 3.3 2.8 2.7 2.7 2.7 2.7

Rating 5.1 5.1 5.1 5.1 5.1 10.8 10.8 10.8 10.8 10.8

Load 0.9 0.9 0.9 0.9 0.9 1.1 1.1 1.1 1.1 1.1

Rating 5.1 5.1 5.1 5.1 5.1 7.9 7.9 7.9 7.9 7.9

Load 12.8 13.1 13.4 13.6 13.9 9.7 10.5 10.4 10.3 10.4

Rating 33.4 33.4 33.4 33.4 33.4 37.5 37.5 37.5 37.5 37.5

Load 4.5 4.5 4.4 4.5 4.5 3.5 3.4 3.4 3.4 3.4

Rating 27.1 27.1 27.1 27.1 27.1 29.4 29.4 29.4 29.4 29.4

Load 1.3 1.3 1.3 1.4 1.3 0.8 0.8 0.8 0.9 0.9

Rating 21.6 21.6 21.6 21.6 21.6 24.2 24.2 24.2 24.2 24.2

Load 21.6 21.9 22.5 22.7 23.2 16.2 16.1 16.3 17.1 17.4

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 2.2 2.2 2.2 2.2 2.2 0.9 0.9 0.9 0.9 0.9

Rating 21.6 21.6 21.6 21.6 21.6 24.2 24.2 24.2 24.2 24.2

Load 15.9 16.3 16.8 17.0 17.2 12.6 12.6 12.7 13.0 13.2

Rating 64.6 64.6 64.6 64.6 64.6 72.5 72.5 72.5 72.5 72.5

Load 21.6 22.1 22.5 22.8 23.2 16.3 16.3 16.4 16.7 17.0

Rating 64.6 64.6 64.6 64.6 64.6 72.5 72.5 72.5 72.5 72.5

Load 20.9 - - - - 21.2 - - - -

Rating 62.3 - - - - 82.9 - - - -

Load 13.7 13.8 13.7 13.7 13.7 14.1 14.1 14.1 14.1 14.1

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 1.4 1.4 1.4 1.4 1.4 2.1 2.1 2.1 2.1 2.1

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 2.9 2.9 2.9 3.0 2.9 1.7 1.7 1.7 1.7 1.7

Rating 21.6 21.6 21.6 21.6 21.6 24.2 24.2 24.2 24.2 24.2

Load 1.7 1.7 1.7 1.7 1.7 1.4 1.4 1.4 1.4 1.4

Rating 8.7 8.7 8.7 8.7 8.7 14.5 14.5 14.5 14.5 14.5

Load 21.1 26.6 26.5 26.5 26.5 21.4 26.7 26.7 26.7 26.7

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 37.5 37.8 38.6 38.7 39.4 32.5 32.3 32.6 34.0 34.3

Rating 63.9 63.9 63.9 63.9 63.9 85.7 85.7 85.7 85.7 85.7

Load 23.7 23.9 24.7 24.8 25.5 18.3 18.1 18.3 19.5 19.8

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

Load 21.1 21.1 21.0 21.2 21.2 19.1 19.0 19.0 19.2 19.2

Rating 63.9 63.9 63.9 63.9 63.9 85.7 85.7 85.7 85.7 85.7

Load 13.0 13.3 13.7 13.9 14.2 9.8 10.5 10.4 10.4 10.6

Rating 32.3 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 20.2 20.2 20.2 20.2 20.2 22.6 22.6 22.6 22.6 22.6

Load 22.1 22.3 22.0 22.2 22.1 19.0 18.9 18.9 20.2 20.2

Rating 62.3 62.3 62.3 62.3 62.3 82.9 82.9 82.9 82.9 82.9

FEEDER MS10(1) Muswellbrook STS to Muswellbrook 33kV

FEEDER MS5 Muswellbrook STS to Rouchel 33kV

FEEDER 6027 Mitchell Line STS to Denman 66kV

FEEDER 6028(1) Mitchell Line STS to Scone, Bengalla and Dartbrook 66kV

FEEDER 6028(5) Mitchell Line STS to Scone, Bengalla and Dartbrook 66kV

FEEDER 6025(1) Mitchell Line STS to Denman 66kV

FEEDER 89047(5) tee to Glenbawn Dam Hydro 33kV

FEEDER MS4 Muswellbrook STS to Muswellbrook Coal 33kV

FEEDER 6023(1) Mitchell Line STS to Mt Arthur Coal and Drayton South 66kV

FEEDER 6023(2) Mitchell Line STS to Mt Arthur Coal 66kV

FEEDER 6028(4) tee to Bengalla Mine 66kV

FEEDER 6028(6) tee to Dartbrook Coal 66kV

FEEDER 89047(1) Scone to Moonan and Rouchel 33kV

FEEDER 82244 Aberdeen to Scone 66kV

FEEDER 6022 Mitchell Line STS to Aberdeen 66kV

FEEDER 60334(2) Denman to Baerami and Merriwa 33kV

FEEDER 89047(4) Scone to Moonan and Rouchel(tee to Rouchel) 33kV

FEEDER 6028(7) Mitchell Lin STS to Scone, Bengalla and Dartbrook(tee to Scone) 66kV

FEEDER 60334(5) Denman to Baerami and Merriwa(tee to Merriwa) 33kV

FEEDER 89047(3) Scone to Moonan and Rouchel(tee to Moonan) 33kV

FEEDER MS1 Muswellbrook STS to Muswellbrook 33kV

FEEDER 60334(4) Denman to Baerami and Merriwa(tee to Baerami) 33kV

FEEDER 6025 Mitchell Line STS to Denman 66kV

FEEDER 89136 Denman to Mangoola Mine 33kV

Upper Hunter Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Page D28 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Upper Hunter Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Load 3.2 3.2 3.2 3.2 3.2 1.7 1.7 1.7 1.9 1.9

Rating 21.6 21.6 21.6 21.6 21.6 24.2 24.2 24.2 24.2 24.2

Load 12.5 12.3 12.3 12.4 12.5 8.3 8.0 7.9 8.0 8.1

Rating 131.0 131.0 131.0 131.0 131.0 143.0 143.0 143.0 143.0 143.0

Load 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rating 131.0 131.0 131.0 131.0 131.0 143.0 143.0 143.0 143.0 143.0

Load - 21.0 20.9 20.9 20.9 - 21.2 21.2 21.2 21.2

Rating - 62.3 62.3 62.3 62.3 - 81.0 81.0 81.0 81.0

Load - 7.5 7.5 7.5 7.5 - 7.5 7.5 7.5 7.5

Rating - 77.0 77.0 77.0 77.0 - 101.0 101.0 101.0 101.0

FEEDER 6023(4) tee to Mt Arthur Coal 66kV

FEEDER 6023(5) tee to Drayton South 66kV

FEEDER 89047(2) Scone to Moonan and Rouchel 33kV

FEEDER 6031 Mitchell Line STS to Mitchell Line 66kV

FEEDER 6030 Mitchell Line STS to Mitchell Line 66kV

Page D29 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 141.4 142.2 144.4 147.9 151.0 148.8 150.6 152.7 155.9 161.3

Rating 260.0 260.0 260.0 260.0 260.0 286.0 286.0 286.0 286.0 286.0

Load 141.4 142.2 144.4 147.8 150.8 148.8 150.6 152.6 155.7 161.0

Rating 260.0 260.0 260.0 260.0 260.0 286.0 286.0 286.0 286.0 286.0

Load 17.7 18.0 18.3 18.6 18.9 16.5 16.7 16.9 17.3 17.6

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 17.7 18.0 18.3 18.6 18.9 16.5 16.7 16.9 17.3 17.6

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 17.8 18.1 18.4 18.7 19.0 16.9 16.5 17.2 17.1 17.6

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 15.0 15.1 15.3 15.6 15.9 17.1 17.3 17.5 17.7 18.2

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 15.3 15.5 15.7 16.0 16.3 17.5 17.5 17.8 18.2 18.0

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 14.9 15.0 15.2 15.5 15.9 17.0 17.1 17.3 17.6 18.1

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 15.0 15.1 15.3 15.6 15.9 17.1 17.1 17.3 17.7 18.1

Rating 31.4 31.4 31.4 31.4 31.4 31.4 31.4 31.4 31.4 31.4

Load 16.1 16.2 16.4 16.8 17.0 17.6 17.3 17.9 17.9 18.3

Rating 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6 28.6

Load 16.3 16.4 16.6 17.0 17.2 17.3 17.4 17.6 18.0 18.5

Rating 25.4 25.4 25.4 25.4 25.4 28.6 28.6 28.6 28.6 28.6

Load 16.3 16.3 16.5 16.9 17.2 17.3 17.4 17.6 18.1 18.5

Rating 23.6 23.6 23.6 23.6 23.6 28.6 28.6 28.6 28.6 28.6

Load 21.5 21.4 21.7 22.1 22.5 23.1 23.3 23.6 24.2 24.8

Rating 31.3 31.3 28.9 28.9 28.9 33.2 32.8 32.8 31.4 31.4

Load 21.6 21.6 21.8 21.9 22.5 23.3 23.5 23.9 24.4 24.7

Rating 28.9 28.9 28.9 28.9 28.9 31.4 31.4 31.4 31.4 31.4

Load 21.5 21.5 21.7 22.1 22.5 23.2 23.4 23.7 24.2 24.8

Rating 28.9 28.9 28.9 28.9 28.9 31.4 31.4 31.4 31.4 31.4

Upper North Shore Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Feeder 9E1 (Sydney East BSP to Kuringai STS) 132

Feeder 9E2 (Sydney East BSP to Kuringai STS) 132

Feeder 530 (Kuringai STS to Pymble ZS T4) 33

Feeder 532 (Kuringai STS to Pymble ZS T2) 33

Feeder 533 (Kuringai STS to Pymble ZS T1) 33

Feeder 534 (Kuringai STS to Lindfield ZS T2) 33

Feeder 535 (Kuringai STS to Lindfield ZS T3) 33

Feeder 536/1 (Kuringai STS to Gordon SRA) 33

Feeder 536/2 (GORDON SRA to Lindfield ZS T4) 33

Feeder 537 (Kuringai STS to Turramurra ZS T1) 33

Feeder 538 (Kuringai STS to Turramurra ZS T2) 33

Feeder 539 (Kuringai STS to Turramurra ZS T3) 33

Feeder 540 (Kuringai STS to St Ives ZS T3) 33

Feeder 541 (Kuringai STS to St Ives ZS T2) 33

Feeder 542 (Kuringai STS to St Ives ZS T1) 33

Page D30 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 26.6 12.3 12.6 12.9 13.0 25.7 25.6 10.0 10.2 10.4

Rating 29.7 26.5 26.5 26.5 26.5 29.7 29.7 29.7 29.7 29.7

Load 5.8 6.0 6.0 6.0 6.0 6.2 6.2 6.2 6.2 6.2

Rating 36.2 32.3 32.3 32.3 32.3 36.2 36.2 36.2 36.2 36.2

Load 5.8 6.0 6.0 6.0 6.0 6.2 6.2 6.2 6.2 6.2

Rating 37.5 33.4 33.4 33.4 33.4 37.5 37.5 37.5 37.5 37.5

Load 17.4 - - - - 11.2 - - - -

Rating 33.8 - - - - 33.8 - - - -

Load 14.5 - - - - 15.6 15.5 - - -

Rating 36.2 - - - - 36.2 36.2 - - -

Load 3.4 3.6 3.6 3.6 3.6 3.5 3.5 3.7 3.7 3.7

Rating 33.8 30.2 30.2 30.2 30.2 33.8 33.8 33.8 33.8 33.8

Load 3.4 2.9 2.9 2.8 2.9 3.5 2.9 3.0 2.9 2.9

Rating 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7 45.7

Load 17.2 12.9 13.2 13.5 13.5 18.4 18.2 10.3 10.5 10.8

Rating 22.1 19.8 19.8 19.8 19.8 22.1 22.1 22.1 22.1 22.1

Load 0.4 0.5 0.5 0.5 0.5 0.6 0.6 0.7 0.7 0.7

Rating 22.1 19.8 19.8 19.8 19.8 22.1 22.1 22.1 22.1 22.1

Load 29.0 14.7 14.8 15.2 15.2 28.1 28.1 12.4 12.6 12.7

Rating 55.3 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 0.4 0.4 0.4 0.4 0.4 0.6 0.6 0.6 0.6 0.6

Rating 19.8 17.8 17.8 17.8 17.8 19.8 19.8 19.8 19.8 19.8

Load 17.4 0.0 0.0 0.0 0.0 11.2 0.0 0.0 0.0 0.0

Rating 30.8 26.6 26.6 26.6 26.6 30.8 30.8 30.8 30.8 30.8

Load 29.2 14.7 15.0 15.3 15.4 28.3 28.2 12.3 12.6 12.7

Rating 55.3 49.2 49.2 49.2 49.2 55.3 55.3 55.3 55.3 55.3

Load 35.7 40.1 40.2 39.5 39.0 35.2 27.8 32.6 32.7 36.0

Rating 219.5 170.6 170.6 170.6 170.6 219.5 219.5 219.5 219.5 219.5

Load - 14.5 14.5 14.2 14.3 - - 15.6 15.3 15.6

Rating - 32.0 32.0 32.0 32.0 - - 32.0 32.0 32.0

Load - 14.6 14.6 14.3 14.4 - - 15.7 15.4 15.7

Rating - 32.0 32.0 32.0 32.0 - - 32.0 32.0 32.0

Load - 27.1 27.1 27.2 27.1 - - 28.3 28.3 28.3

Rating - 128.0 128.0 128.0 128.0 - - 128.0 128.0 128.0

FEEDER tee to Mandalong Mine 33kV

FEEDER Morisset to Mandalong and Mandalong South 33kV

FEEDER 784 Eraring STS to Cooranbong 33kV

FEEDER 957/2 Vales Pt to Morriset and Ourimbah(tee Morisset) 132kV

FEEDER tee to Mandalong South Mine 33kV

FEEDER H738 Awaba STS to Awaba State Mine 33kV

FEEDER H734 Awaba STS to Newstan 33kV

FEEDER 733 Awaba STS to Toronto 33kV

FEEDER 3710(1) Avondale to Cooranbong and Mandalong Mine 33kV

FEEDER H730 Awaba STS to Awaba State Mine 33kV

FEEDER H783 Eraring STS to Avondale 33kV

FEEDER H736 Awaba STS to Toronto 33kV

FEEDER 3710(7) tee to Mandalong Mine 33kV

FEEDER H735 Awaba STS to Newstan 33kV

FEEDER 3710(2) Avondale to Cooranbong and Mandalong(tee to Cooranbong) 33kV

FEEDER H786 Eraring STS to Myuna 33kV

FEEDER H785 Eraring STS to Myuna 33kV

West Lake Macquarie Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Page D31 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 81.4 92.6 126.6 127.7 129.0 51.6 50.1 109.8 110.6 112.0

Rating 155.5 155.5 155.5 155.5 155.5 164.6 164.6 164.6 164.6 164.6

Load 107.5 112.7 128.4 129.3 131.1 92.2 91.3 114.4 115.0 116.9

Rating 186.3 186.3 186.3 186.3 186.3 197.8 197.8 197.8 197.8 197.8

Load 107.7 112.9 128.6 129.5 131.3 92.3 91.5 114.6 115.2 117.0

Rating 186.3 186.3 186.3 186.3 186.3 197.8 197.8 197.8 197.8 197.8

Load 186.8 178.9 239.1 240.9 247.6 178.2 198.1 233.2 234.9 238.0

Rating 304.0 304.0 304.0 304.0 304.0 324.0 324.0 324.0 324.0 324.0

Load 116.7 118.5 120.3 122.0 123.7 79.9 80.6 81.1 82.4 84.5

Rating 246.0 246.0 246.0 246.0 246.0 259.0 259.0 259.0 259.0 259.0

Load 297.2 291.1 349.5 353.2 355.1 253.2 275.2 310.3 312.6 318.8

Rating 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0

Load 186.7 178.8 239.0 240.7 247.5 178.1 198.0 233.0 234.8 237.8

Rating 304.0 304.0 304.0 304.0 304.0 324.0 324.0 324.0 324.0 324.0

Load 116.7 118.5 120.3 122.0 123.7 79.9 80.6 81.2 82.4 84.5

Rating 246.0 246.0 246.0 246.0 246.0 259.0 259.0 259.0 259.0 259.0

Load 297.2 291.0 349.5 353.2 355.0 253.2 275.1 310.2 312.5 318.6

Rating 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0

Load 159.2 147.6 184.1 186.2 183.8 115.9 139.3 152.1 154.4 158.6

Rating 219.0 219.0 219.0 219.0 219.0 228.6 228.6 228.6 228.6 228.6

Load 159.5 147.9 184.5 186.7 184.2 116.1 139.7 152.4 154.8 159.0

Rating 220.0 220.0 220.0 220.0 220.0 230.0 230.0 230.0 230.0 230.0

Load 57.5 64.1 65.1 66.1 67.3 58.0 60.1 61.9 62.9 64.2

Rating 111.0 111.0 111.0 111.0 111.0 99.0 99.0 99.0 99.0 99.0

Load 81.7 88.3 89.6 91.0 92.8 84.6 88.9 92.6 94.3 96.2

Rating 111.0 111.0 111.0 111.0 111.0 118.0 118.0 118.0 118.0 118.0

Load 52.1 52.5 53.2 54.2 55.5 69.2 68.8 69.0 69.7 71.1

Rating 89.2 89.2 89.2 89.2 89.2 83.4 83.4 83.4 83.4 83.4

Load 52.1 52.5 53.2 54.2 55.5 69.2 68.8 69.0 69.7 71.1

Rating 179.5 179.5 179.5 179.5 179.5 182.9 182.9 182.9 182.9 182.9

Load 81.1 79.8 79.5 80.3 82.3 98.8 97.4 97.0 97.7 100.0

Rating 251.0 251.0 251.0 251.0 251.0 265.7 265.7 265.7 265.7 265.7

Load 79.6 78.3 78.0 78.8 80.6 98.3 96.9 96.4 97.2 99.4

Rating 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3 114.3

Load 45.5 44.1 43.5 43.6 44.5 56.0 55.7 56.0 56.8 58.1

Rating 250.4 250.4 250.4 250.4 250.4 265.2 265.2 265.2 265.2 265.2

Load 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3

Rating 185.0 185.0 185.0 185.0 185.0 195.0 195.0 195.0 195.0 195.0

Load 61.6 63.0 63.7 64.5 65.5 38.8 39.5 39.2 39.5 40.5

Rating 134.0 134.0 134.0 134.0 134.0 142.0 142.0 142.0 142.0 142.0

Load 59.7 60.9 61.5 62.3 63.1 38.3 38.9 38.7 39.0 39.9

Rating 134.0 134.0 134.0 134.0 134.0 142.0 142.0 142.0 142.0 142.0

Load 48.9 48.7 48.9 49.4 50.3 33.1 32.8 32.9 33.5 34.5

Rating 242.6 242.6 242.6 242.6 242.6 284.0 284.0 284.0 284.0 284.0

Load 46.8 46.7 46.9 47.3 48.1 32.5 32.1 32.2 32.8 33.7

Rating 206.0 206.0 206.0 206.0 206.0 256.0 256.0 256.0 256.0 256.0

Load 46.8 46.7 46.9 47.3 48.1 32.5 32.1 32.3 32.8 33.7

Rating 243.0 243.0 243.0 243.0 243.0 284.0 284.0 284.0 284.0 284.0132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

FEEDER 296 ( 2 ): [SEFTON - SEFTON]

FEEDER 291/1: [GREENACRE PARK - POTTS HILL]

FEEDER 292: [GREENACRE PARK - POTTS HILL]

FEEDER 295: [POTTS HILL - SEFTON]

FEEDER 296 ( 1 ): [ROOKWOOD BSP - SEFTON]

FEEDER 262: [DOUBLE BAY - CLOVELLY]

FEEDER 264: [BEACONSFIELD BSP - KINGSFORD]

FEEDER 265: [BUNNERONG - MAROUBRA]

FEEDER 270: [MAROUBRA - KINGSFORD]

FEEDER 290: [LANE COVE - LANE COVE TEST]

FEEDER 246: [KURNELL - BUNNERONG]

FEEDER 260/1: [BEACONSFIELD BSP - ZETLAND]

FEEDER 261/1: [BEACONSFIELD BSP - ZETLAND]

FEEDER 261/2: [CLOVELLY - ZETLAND]

FEEDER 240 ( 3 ): [ROOKWOOD BSP - CHULLORA]

FEEDER 241 ( 1 ): [CHULLORA - CHULLORA]

FEEDER 241 ( 2 ): [POTTS HILL - CHULLORA]

FEEDER 241 ( 3 ): [ROOKWOOD BSP - CHULLORA]

FEEDER 245: [KURNELL - BUNNERONG]

FEEDER 202: [DRUMMOYNE - ROZELLE]

FEEDER 203: [MASON PARK - DRUMMOYNE]

FEEDER 204: [MASON PARK - DRUMMOYNE]

FEEDER 240 ( 1 ): [CHULLORA - CHULLORA]

FEEDER 240 ( 2 ): [POTTS HILL - CHULLORA]

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Page D32 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load - - 77.9 79.0 79.2 - - - 77.9 79.9

Rating - - 200.0 200.0 200.0 - - - 200.0 200.0

Load 126.2 128.9 173.6 175.7 168.1 132.4 135.4 140.8 142.9 147.6

Rating 251.0 251.0 251.0 251.0 251.0 255.0 255.0 255.0 255.0 255.0

Load 74.3 73.4 - - - 75.3 75.7 76.4 - -

Rating 200.0 200.0 - - - 200.0 200.0 200.0 - -

Load - - 89.6 90.5 92.4 - - - 90.8 93.2

Rating - - 200.0 200.0 200.0 - - - 200.0 200.0

Load 96.8 95.2 93.1 93.9 93.9 59.4 58.1 57.1 56.7 57.2

Rating 240.1 240.1 240.1 240.1 240.1 251.5 251.5 251.5 251.5 251.5

Load 65.1 63.8 62.3 63.3 62.8 39.2 38.4 37.6 37.3 37.7

Rating 147.5 147.5 147.5 147.5 147.5 156.6 156.6 156.6 156.6 156.6

Load 61.7 60.9 59.7 59.8 60.2 39.0 38.1 37.6 37.4 37.6

Rating 77.3 77.3 77.3 77.3 77.3 104.0 104.0 104.0 104.0 104.0

Load 84.2 85.3 86.1 87.3 88.9 98.9 98.8 99.1 100.2 102.2

Rating 139.5 139.5 139.5 139.5 139.5 148.6 148.6 148.6 148.6 148.6

Load 145.9 123.4 154.9 156.0 158.0 122.7 125.5 130.8 131.8 134.4

Rating 221.0 221.0 221.0 221.0 221.0 235.0 235.0 235.0 235.0 235.0

Load - 124.7 153.1 154.1 156.2 - - 123.7 124.8 127.2

Rating - 259.0 259.0 259.0 259.0 - - 272.0 272.0 272.0

Load 140.2 - - - - 109.9 113.1 - - -

Rating 259.0 - - - - 273.2 273.2 - - -

Load 85.5 83.9 82.7 82.9 83.5 53.4 52.2 51.6 51.2 51.5

Rating 240.1 240.1 240.1 240.1 240.1 251.5 251.5 251.5 251.5 251.5

Load 41.8 40.6 40.3 40.7 40.7 26.1 25.6 25.1 25.2 25.2

Rating 147.5 147.5 147.5 147.5 147.5 156.6 156.6 156.6 156.6 156.6

Load 65.3 64.0 70.2 68.8 70.9 40.0 38.8 46.7 47.0 47.1

Rating 77.3 77.3 77.3 77.3 77.3 104.0 104.0 104.0 104.0 104.0

Load 85.1 83.4 82.3 82.5 83.0 53.1 52.0 51.3 51.0 51.2

Rating 240.1 240.1 240.1 240.1 240.1 251.5 251.5 251.5 251.5 251.5

Load 41.8 40.6 40.3 40.6 40.7 26.1 25.6 25.1 25.1 25.2

Rating 147.5 147.5 147.5 147.5 147.5 156.6 156.6 156.6 156.6 156.6

Load 63.8 62.9 70.0 68.6 70.7 40.2 38.9 46.6 46.9 47.0

Rating 77.3 77.3 77.3 77.3 77.3 104.0 104.0 104.0 104.0 104.0

Load 62.8 62.0 69.2 67.9 69.9 39.2 38.0 46.0 46.3 46.5

Rating 139.9 139.9 139.9 139.9 139.9 147.2 147.2 147.2 147.2 147.2

Load 139.8 132.0 131.0 135.0 136.8 170.6 162.4 130.5 124.2 122.6

Rating 209.0 209.0 209.0 209.0 209.0 223.0 223.0 223.0 223.0 223.0

Load 67.5 127.3 129.2 132.9 134.7 83.1 78.9 127.1 121.4 119.8

Rating 113.0 313.0 313.0 313.0 313.0 121.0 121.0 323.0 323.0 323.0

Load 67.5 - - - - 83.1 78.9 - - -

Rating 113.0 - - - - 121.0 121.0 - - -

Load - 124.4 179.0 180.1 182.4 - - 151.8 152.9 155.9

Rating - 248.0 248.0 248.0 248.0 - - 262.0 262.0 262.0

Load 61.4 61.0 60.0 59.8 60.5 37.8 38.0 37.7 37.5 37.7

Rating 240.1 240.1 240.1 240.1 240.1 251.5 251.5 251.5 251.5 251.5

Load 21.1 21.7 21.0 21.0 21.2 12.8 13.7 13.6 13.5 13.6

Rating 155.0 155.0 155.0 155.0 155.0 179.9 179.9 179.9 179.9 179.9132

132

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FEEDER 90Z/1: [HAYMARKET - CITY SOUTH]

FEEDER 90Z/2: [CITY SOUTH - CITY NORTH]

FEEDER 90W/3: [CITY CENTRAL -PYRMONT]

FEEDER 90W/4: [ROZELLE - PYRMONT]

FEEDER 90X: [MASON PARK - HOMEBUSH BAY TP]

FEEDER 90XA: [HOMEBUSH BAY TP - MEADOWBANK]

FEEDER 90XB: [HOMEBUSH BAY TP - MEADOWBANK]

FEEDER 90V/3: [ROZELLE - CITY CENTRAL]

FEEDER 90W/1: [HAYMARKET - CITY SOUTH]

FEEDER 90W/2: [CITY CENTRAL -CITY SOUTH]

FEEDER 90P/3: [CITY CENTRAL - DARLING HARBOUR]

FEEDER 90R: [CAMPBELL ST - DOUBLE BAY]

FEEDER 90T/1: [HAYMARKET - GREEN SQUARE]

FEEDER 90T/2: [ALEXANDRIA - GREEN SQUARE]

FEEDER 90T/2: [BEACONSFIELD BSP - GREEN SQUARE]

FEEDER 90Y: [BEACONSFIELD BSP - BELMORE PARK]

FEEDER 907: [ROCKDALE - CANTERBURY]

FEEDER 90P/1: [HAYMARKET - CITY SOUTH]

FEEDER 90P/2: [CITY CENTRAL - CITY SOUTH]

FEEDER 905: [KOGARAH - ROCKDALE]

FEEDER 906: [CANTERBURY - MARRICKVILLE]

FEEDER 907: [CANTERBURY - KOGARAH]

FEEDER 90V/1: [HAYMARKET - CITY SOUTH]

FEEDER 90V/2: [CITY CENTRAL - CITY SOUTH]

Page D33 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 69.5 151.2 177.4 180.2 178.8 68.4 68.8 156.3 159.4 163.7

Rating 244.9 244.9 244.9 244.9 244.9 246.9 246.9 246.9 246.9 246.9

Load 69.1 150.4 175.9 178.5 177.8 67.9 68.3 155.7 158.7 162.8

Rating 242.6 242.6 242.6 242.6 242.6 274.4 274.4 274.4 274.4 274.4

Load 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1

Rating 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9

Load 195.7 151.2 177.4 180.2 178.8 162.2 184.6 156.3 159.4 163.7

Rating 244.9 244.9 244.9 244.9 244.9 246.9 246.9 246.9 246.9 246.9

Load 193.9 150.3 175.8 178.5 177.8 161.5 183.6 155.6 158.6 162.8

Rating 224.7 224.7 224.7 224.7 224.7 252.9 252.9 252.9 252.9 252.9

Load 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1

Rating 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9

Load 97.4 98.6 99.2 100.2 101.2 84.1 85.5 86.2 87.8 89.9

Rating 226.3 226.3 226.3 226.3 226.3 254.9 254.9 254.9 254.9 254.9

Load 97.4 98.6 99.2 100.2 101.2 84.1 85.5 86.2 87.8 89.9

Rating 226.3 226.3 226.3 226.3 226.3 254.9 254.9 254.9 254.9 254.9

Load 234.0 222.6 264.7 268.8 264.1 200.8 228.1 243.0 246.8 253.7

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 177.6 164.8 204.0 206.5 204.4 126.7 152.3 166.4 169.0 173.6

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 56.8 58.7 59.4 60.4 61.8 77.2 78.8 79.2 80.1 81.8

Rating 242.6 242.6 242.6 242.6 242.6 284.0 284.0 284.0 284.0 284.0

Load 222.5 210.3 256.3 260.6 253.2 168.0 194.7 212.0 212.9 220.8

Rating 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0 439.0

Load 33.2 34.3 35.2 35.9 36.4 27.7 27.2 27.3 27.7 28.0

Rating 280.0 280.0 280.0 280.0 280.0 295.0 295.0 295.0 295.0 295.0

Load 190.1 177.3 220.1 223.3 217.8 141.1 167.6 184.1 185.8 191.8

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

Load 38.0 36.1 58.4 59.7 63.7 41.3 46.4 57.0 57.7 57.7

Rating 97.0 97.0 97.0 97.0 97.0 105.0 105.0 105.0 105.0 105.0

Load 38.8 36.7 59.2 60.5 64.5 41.9 47.1 57.8 58.5 58.6

Rating 100.6 100.6 100.6 100.6 100.6 109.0 109.0 109.0 109.0 109.0

Load 164.0 195.9 202.2 205.0 202.4 123.7 140.7 190.5 172.8 178.1

Rating 296.0 296.0 296.0 296.0 296.0 312.0 312.0 312.0 312.0 312.0

Load 279.3 312.3 344.2 349.3 348.9 293.3 260.1 308.7 314.0 323.1

Rating 494.8 494.8 494.8 494.8 494.8 571.6 571.6 571.6 571.6 571.6

Load 21.4 21.4 21.4 21.3 21.1 12.8 13.6 13.6 13.5 13.7

Rating 225.0 225.0 225.0 225.0 225.0 260.0 260.0 260.0 260.0 260.0

Load 125.8 104.5 138.5 139.6 135.4 89.6 113.7 113.5 115.1 119.0

Rating 196.6 196.6 196.6 196.6 196.6 208.1 208.1 208.1 208.1 208.1

Load 126.4 105.3 139.9 141.0 135.9 90.6 114.1 114.6 116.3 120.3

Rating 253.0 253.0 253.0 253.0 253.0 260.0 260.0 260.0 260.0 260.0

Load 125.9 105.5 138.6 139.6 135.3 91.3 113.9 114.5 116.2 119.9

Rating 253.0 253.0 253.0 253.0 253.0 260.0 260.0 260.0 260.0 260.0

Load 279.4 312.5 344.4 349.5 349.1 293.6 260.2 308.9 314.2 323.2

Rating 494.8 494.8 494.8 494.8 494.8 571.6 571.6 571.6 571.6 571.6

Load - - - - - 119.8 - - - -

Rating - - - - - 196.0 - - - -

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FEEDER 91J: [SYDNEY SOUTH BSP - PEAKHURST]

FEEDER 91M/1: [BEACONSFIELD - PEAKHURST]

FEEDER 91F: [SYDNEY SOUTH BSP - PEAKHURST]

FEEDER 91G: [HAYMARKET - CITY NORTH]

FEEDER 91H/1: [HURSTVILLE NORTH - HURSTVILLE NORTH]

FEEDER 91H/2 ( 1 ): [HURSTVILLE NORTH - ROCKDALE]

FEEDER 91H/2 ( 2 ): [ROCKDALE - MARRICKVILLE]

FEEDER 917 ( 2 ): [GWAWLEY BAY - GWAWLEY BAY]

FEEDER 917 ( 3 ): [KURNELL - GWAWLEY BAY]

FEEDER 91A: [BEACONSFIELD BSP - ST PETERS]

FEEDER 91B: [BEACONSFIELD BSP - ST PETERS]

FEEDER 91C: [PEAKHURST - HURSTVILLE NORTH]

FEEDER 915: [SYDNEY SOUTH BSP - BANKSTOWN]

FEEDER 916 ( 1 ): [SYDNEY SOUTH BSP - CRONULLA]

FEEDER 916 ( 2 ): [KURNELL - CRONULLA]

FEEDER 916 ( 3 ): [CRONULLA - CRONULLA]

FEEDER 917 ( 1 ): [SYDNEY SOUTH BSP - GWAWLEY BAY]

FEEDER 910 ( 3 ): [CHULLORA - SYDNEY SOUTH]

FEEDER 911 ( 1 ): [SYDNEY SOUTH BSP - SYDNEY SOUTH]

FEEDER 911 ( 2 ): [SYDNEY SOUTH - CANTERBURY]

FEEDER 911 ( 3 ): [CHULLORA - SYDNEY SOUTH]

FEEDER 914: [SYDNEY SOUTH BSP - BANKSTOWN]

FEEDER 910 ( 1 ): [SYDNEY SOUTH BSP - SYDNEY SOUTH]

FEEDER 910 ( 2 ): [SYDNEY SOUTH - CANTERBURY]

Page D34 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 116.7 127.4 134.8 135.0 111.4 130.7 134.0 125.3 127.6 129.9

Rating 224.0 224.0 224.0 224.0 224.0 196.0 240.0 240.0 240.0 240.0

Load 163.9 195.9 202.2 205.0 202.4 123.7 140.7 190.5 172.8 178.1

Rating 296.0 296.0 296.0 296.0 296.0 312.0 312.0 312.0 312.0 312.0

Load 51.3 52.6 53.8 55.0 56.1 67.6 68.6 68.8 69.6 71.0

Rating 203.0 203.0 203.0 203.0 203.0 214.0 214.0 214.0 214.0 214.0

Load 126.4 106.3 139.5 140.5 135.6 92.3 114.4 115.5 117.2 120.9

Rating 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0

Load 74.3 118.5 145.7 147.7 147.9 75.3 75.8 116.5 134.9 138.7

Rating 197.0 197.0 197.0 197.0 197.0 208.0 208.0 208.0 208.0 208.0

Load 47.4 46.1 62.2 63.2 66.5 39.3 45.4 57.1 57.6 58.8

Rating 99.0 99.0 99.0 99.0 99.0 106.0 106.0 106.0 106.0 106.0

Load 76.4 69.8 91.3 92.8 96.7 74.5 77.5 89.2 90.2 90.3

Rating 100.0 100.0 100.0 100.0 100.0 110.0 110.0 110.0 110.0 110.0

Load 47.3 45.9 62.3 63.3 66.7 39.4 45.9 57.2 57.8 58.6

Rating 99.0 99.0 99.0 99.0 99.0 106.0 106.0 106.0 106.0 106.0

Load 76.4 69.9 91.2 92.7 96.6 74.5 78.1 89.2 90.1 90.2

Rating 100.6 100.6 100.6 100.6 100.6 110.0 110.0 110.0 110.0 110.0

Load 373.1 377.7 317.3 324.2 328.8 296.0 302.4 261.8 253.2 253.9

Rating 456.8 456.8 456.8 456.8 456.8 514.8 514.8 514.8 514.8 514.8

Load 364.1 368.0 309.1 314.5 319.0 290.6 297.1 256.4 249.2 250.0

Rating 407.0 407.0 407.0 407.0 407.0 434.4 434.4 434.4 434.4 434.4

Load 355.5 359.9 302.7 309.7 314.1 281.3 287.9 249.8 241.5 242.2

Rating 456.6 456.6 456.6 456.6 456.6 514.7 514.7 514.7 514.7 514.7

Load 346.5 350.3 294.4 299.8 304.1 276.2 282.6 244.0 237.3 238.0

Rating 407.0 407.0 407.0 407.0 407.0 434.4 434.4 434.4 434.4 434.4

Load 70.4 69.7 26.1 26.0 26.5 44.5 59.5 15.6 15.3 15.8

Rating 128.0 128.0 128.0 128.0 128.0 135.4 135.4 135.4 135.4 135.4

Load 98.8 96.9 - - - 69.2 80.3 - - -

Rating 121.2 121.2 - - - 130.3 130.3 - - -

Load - - 70.3 70.4 72.3 - - 55.5 56.0 56.6

Rating - - 337.0 337.0 337.0 - - 352.1 352.1 352.1

Load 81.8 81.5 - - - 66.5 65.1 - - -

Rating 121.2 121.2 - - - 130.3 130.3 - - -

Load 55.6 54.0 26.0 26.0 26.5 47.0 50.1 15.6 15.3 15.7

Rating 130.6 130.6 130.6 130.6 130.6 140.6 140.6 140.6 140.6 140.6

Load - - 80.3 80.6 81.3 - - 62.0 61.7 62.8

Rating - - 212.0 212.0 212.0 - - 218.0 218.0 218.0

Load 299.0 302.3 237.7 243.0 246.5 234.3 239.7 193.5 187.7 188.5

Rating 457.0 457.0 457.0 457.0 457.0 514.9 514.9 514.9 514.9 514.9

Load 264.8 262.7 199.0 202.5 205.6 214.8 219.0 169.1 164.8 165.3

Rating 365.8 365.8 365.8 365.8 365.8 365.8 365.8 365.8 365.8 365.8

Load 80.9 86.2 96.8 97.6 98.5 48.0 51.4 60.5 60.3 60.9

Rating 171.5 171.5 171.5 171.5 171.5 181.8 181.8 181.8 181.8 181.8

Load 305.4 305.7 244.9 250.4 253.9 239.0 244.7 198.5 192.6 193.4

Rating 457.0 457.0 457.0 457.0 457.0 512.1 512.1 512.1 512.1 512.1

Load 245.6 242.0 174.0 177.1 180.0 203.9 207.2 153.8 149.6 150.0

Rating 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0 457.0

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FEEDER 92B ( 1 ): [SYDNEY NORTH - MACQUARIE PARK]

FEEDER 92B ( 2 ): [LANE COVE - MACQUARIE PARK]

FEEDER 929/1: [LANE COVE - DALLEY ST]

FEEDER 929/2: [DALLEY ST - SURRY HILLS]

FEEDER 929/3: [SURRY HILLS - BELMORE PARK]

FEEDER 92A ( 1 ): [SYDNEY NORTH - MACQUARIE PARK]

FEEDER 92A ( 2 ): [LANE COVE - MACQUARIE PARK]

FEEDER 927 ( 3 ): [CARLINGFORD - HOMEBUSH BAY]

FEEDER 928/1: [SURRY HILLS - DALLEY ST]

FEEDER 928/3: [LANE COVE - DALLEY ST]

FEEDER 928/4: [CAMPBELL ST - SURRY HILLS]

FEEDER 91Y/2: [MARRICKVILLE - CHULLORA]

FEEDER 926 ( 1 ): [SYDNEY NORTH - CARLINGFORD]

FEEDER 926 ( 3 ): [CARLINGFORD - MASON PARK]

FEEDER 927 ( 1 ): [SYDNEY NORTH - CARLINGFORD]

FEEDER 92A ( 3 ): [MACQUARIE PARK - MACQUARIE PARK]

FEEDER 91U: [MARRICKVILLE - BEACONSFIELD BSP]

FEEDER 91W: [HURSTVILLE NORTH - KOGARAH]

FEEDER 91X/1: [BEACONSFIELD BSP - MARRICKVILLE]

FEEDER 91X/2: [CHULLORA - MARRICKVILLE]

FEEDER 91Y/1: [BEACONSFIELD BSP - MARRICKVILLE]

FEEDER 91M/3: [BEACONSFIELD - BUNNERONG]

FEEDER 91R: [PEAKHURST - HURSTVILLE NORTH]

FEEDER 91T: [CAMPBELL ST - ROSE BAY]

Page D35 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 80.9 86.2 96.8 97.6 98.6 48.0 51.4 60.5 60.3 61.0

Rating 171.5 171.5 171.5 171.5 171.5 181.8 181.8 181.8 181.8 181.8

Load 68.3 67.3 85.7 87.1 91.0 66.7 72.5 83.0 83.9 83.9

Rating 104.0 104.0 104.0 104.0 104.0 113.0 113.0 113.0 113.0 113.0

Load 45.9 46.0 45.4 45.2 45.5 27.4 28.6 28.3 28.1 28.3

Rating 225.0 225.0 225.0 225.0 225.0 260.0 260.0 260.0 260.0 260.0

Load 148.4 130.6 169.9 174.8 177.8 171.5 163.3 159.5 150.5 150.2

Rating 209.2 209.2 209.2 209.2 209.2 222.9 222.9 222.9 222.9 222.9

Load 72.1 126.0 168.3 173.0 175.9 83.6 79.4 157.4 148.9 148.6

Rating 114.0 313.0 313.0 313.0 313.0 122.0 122.0 323.0 323.0 323.0

Load 72.1 - - - - 83.6 79.4 - - -

Rating 114.0 - - - - 122.0 122.0 - - -

Load 158.8 154.2 215.1 219.1 222.4 161.5 159.9 190.5 185.6 185.9

Rating 494.8 494.8 494.8 494.8 494.8 571.6 571.6 571.6 571.6 571.6

Load 85.1 82.8 110.0 112.4 114.1 86.7 85.6 98.1 94.7 94.9

Rating 121.0 121.0 121.0 121.0 121.0 134.0 134.0 134.0 134.0 134.0

Load 85.1 82.8 110.0 112.4 114.1 86.6 85.6 98.1 94.7 94.9

Rating 121.0 121.0 121.0 121.0 121.0 134.0 134.0 134.0 134.0 134.0

Load 161.6 164.6 195.5 198.9 202.3 164.7 159.4 169.8 169.7 170.1

Rating 415.6 415.6 415.6 415.6 415.6 520.6 520.6 520.6 520.6 520.6

Load 87.6 89.0 102.2 104.5 106.3 94.7 91.9 91.5 90.4 90.6

Rating 115.0 115.0 115.0 115.0 115.0 122.0 122.0 122.0 122.0 122.0

Load 87.6 89.0 102.2 104.5 106.3 94.7 91.9 91.5 90.4 90.6

Rating 115.0 115.0 115.0 115.0 115.0 122.0 122.0 122.0 122.0 122.0

Load 53.9 56.0 25.5 25.3 25.0 50.3 49.9 15.2 15.1 15.3

Rating 129.2 129.2 129.2 129.2 129.2 137.2 137.2 137.2 137.2 137.2

Load - - 74.3 74.2 76.3 - - 58.8 59.1 59.8

Rating 152.5 152.5 152.5 152.5 152.5 161.9 161.9 161.9 161.9 161.9

Load 27.0 26.2 25.5 25.3 25.0 16.0 15.5 15.2 15.1 15.3

Rating 274.4 274.4 274.4 274.4 274.4 274.4 274.4 274.4 274.4 274.4

Load 77.6 79.3 - - - 60.0 59.6 - - -

Rating 128.0 128.0 - - - 136.0 136.0 - - -

Load 108.2 107.5 - - - 61.7 84.3 - - -

Rating 128.0 128.0 - - - 136.0 136.0 - - -

Load 83.0 83.8 26.6 26.8 27.8 52.5 71.2 16.2 15.9 16.1

Rating 144.0 144.0 144.0 144.0 144.0 153.2 153.2 153.2 153.2 153.2

Load - - 78.3 78.0 80.3 - - 62.1 62.1 63.0

Rating - - 240.1 240.1 240.1 - - 251.9 251.9 251.9

Load 125.3 90.4 125.7 126.5 128.1 106.0 108.5 107.2 108.1 110.1

Rating 137.0 137.0 137.0 137.0 137.0 149.0 149.0 149.0 149.0 149.0

Load 69.3 68.1 86.4 87.8 91.7 67.0 73.0 83.6 84.6 84.6

Rating 104.0 104.0 104.0 104.0 104.0 113.0 113.0 113.0 113.0 113.0

Load 301.3 300.5 242.7 248.1 251.8 246.1 249.1 210.1 202.9 203.3

Rating 407.0 407.0 407.0 407.0 407.0 434.4 434.4 434.4 434.4 434.4

Load 21.4 21.4 21.4 21.3 21.1 12.8 13.6 13.6 13.5 13.7

Rating 225.0 225.0 225.0 225.0 225.0 260.0 260.0 260.0 260.0 260.0

Load 89.7 159.2 198.1 199.2 211.7 103.3 110.7 201.1 199.4 201.8

Rating 265.0 265.0 265.0 265.0 265.0 280.0 280.0 280.0 280.0 280.0132

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FEEDER 93H: [BELMORE PARK - HAYMARKET]

FEEDER 92M/3: [CAMPBELL ST - SURRY HILLS]

FEEDER 92P: [BEACONSFIELD BSP - BELMORE PARK]

FEEDER 92X: [ST PETERS - CHULLORA]

FEEDER 935: [HOMEBUSH BAY - MASON PARK]

FEEDER 93C: [HAYMARKET - CITY NORTH]

FEEDER 92L/1 (1): [SURRY HILLS - DALLEY ST]

FEEDER 92L/2: [DALLEY ST - DALLEY ST]

FEEDER 92L/3: [LANE COVE - DALLEY ST]

FEEDER 92M/1: [LANE COVE - DALLEY ST]

FEEDER 92M/2: [DALLEY ST - SURRY HILLS]

FEEDER 92L/1 (2): [SURRY HILLS - SURRY HILLS ANNEXE]

FEEDER 92GA: [EAST RYDE TP - TOP RYDE]

FEEDER 92GB: [EAST RYDE TP - TOP RYDE]

FEEDER 92J: [LANE COVE - EAST RYDE TP]

FEEDER 92JA: [MEADOWBANK - EAST RYDE TP]

FEEDER 92JB: [MEADOWBANK - EAST RYDE TP]

FEEDER 92E: [HAYMARKET - CITY NORTH]

FEEDER 92F: [MASON PARK - HOMEBUSH BAY TP]

FEEDER 92FA: [HOMEBUSH BAY TP - TOP RYDE]

FEEDER 92FB: [HOMEBUSH BAY TP - TOP RYDE]

FEEDER 92G: [LANE COVE - EAST RYDE TP]

FEEDER 92B ( 3 ): [MACQUARIE PARK - MACQUARIE PARK]

FEEDER 92C: [CHULLORA - ST PETERS]

Page D36 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Inner Metropolitan Area - Feeder Load Forecast

Feeder name (KV)

Summer (MVA) Winter (MVA)

Load 127.2 129.7 174.4 176.6 168.3 133.8 136.7 141.8 143.9 148.6

Rating 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0

Load 123.7 150.6 183.5 184.3 186.2 46.5 82.3 146.2 146.6 148.2

Rating 320.0 320.0 320.0 320.0 320.0 338.0 338.0 338.0 338.0 338.0

Load 125.2 115.6 148.1 149.1 150.3 47.7 83.2 109.0 108.9 110.2

Rating 265.0 265.0 265.0 265.0 265.0 280.0 280.0 280.0 280.0 280.0

Load 126.5 116.9 114.6 115.1 115.8 48.9 84.0 75.9 77.0 78.0

Rating 320.0 320.0 320.0 320.0 320.0 338.0 338.0 338.0 338.0 338.0

Load 33.9 32.8 45.7 46.0 47.8 41.7 42.0 47.1 47.0 47.8

Rating 212.0 212.0 212.0 212.0 212.0 223.0 223.0 223.0 223.0 223.0

Load - 124.5 153.0 154.0 156.1 - - 123.6 124.6 127.1

Rating - 259.0 259.0 259.0 259.0 - - 272.0 272.0 272.0

Load 127.9 106.5 131.6 132.6 134.3 106.7 109.2 111.1 112.0 114.1

Rating 225.0 225.0 225.0 225.0 225.0 240.0 240.0 240.0 240.0 240.0

Load 154.1 130.5 161.6 162.7 164.8 128.9 131.8 135.7 136.8 139.5

Rating 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0

Load 183.5 189.7 191.7 194.6 196.5 140.3 157.7 158.5 161.2 165.1

Rating 214.0 214.0 214.0 214.0 214.0 229.0 229.0 229.0 229.0 229.0

Load 83.4 87.4 87.7 87.8 88.7 56.8 64.2 63.0 63.8 64.8

Rating 320.1 320.1 320.1 320.1 320.1 340.7 340.7 340.7 340.7 340.7

Load 46.3 45.6 45.2 45.0 45.3 28.8 29.2 28.7 28.5 28.9

Rating 77.3 77.3 77.3 77.3 77.3 104.0 104.0 104.0 104.0 104.0

Load 17.5 17.4 17.5 17.2 17.4 10.6 11.5 11.3 11.3 11.4

Rating 225.0 225.0 225.0 225.0 225.0 260.0 260.0 260.0 260.0 260.0

Load 158.1 164.2 166.5 169.4 171.0 123.6 141.4 142.5 145.2 148.9

Rating 229.0 229.0 229.0 229.0 229.0 242.0 242.0 242.0 242.0 242.0

Load 88.6 90.1 89.3 89.3 90.2 58.0 61.1 60.1 60.3 61.0

Rating 320.1 320.1 320.1 320.1 320.1 340.7 340.7 340.7 340.7 340.7

Load 129.2 107.2 168.7 170.5 174.9 111.1 113.5 156.1 157.2 159.9

Rating 137.0 137.0 137.0 137.0 137.0 148.0 148.0 148.0 148.0 148.0

Load 82.3 83.4 151.1 152.6 155.1 94.0 94.3 147.2 148.3 150.9

Rating 295.0 295.0 295.0 295.0 295.0 315.0 315.0 315.0 315.0 315.0

Load 84.2 85.3 86.0 87.3 88.9 95.4 95.7 96.1 97.1 99.0

Rating 132.0 132.0 132.0 132.0 132.0 140.0 140.0 140.0 140.0 140.0

Load 118.5 117.9 221.7 222.8 231.4 137.1 142.2 212.1 212.4 216.0

Rating 298.4 298.4 298.4 298.4 298.4 317.8 317.8 317.8 317.8 317.8

Load 86.5 116.5 143.1 144.1 146.0 68.5 70.5 115.6 116.6 118.9

Rating 227.0 227.0 227.0 227.0 227.0 242.0 242.0 242.0 242.0 242.0

Load 53.5 53.3 66.3 67.2 69.9 67.6 68.6 73.3 73.6 75.0

Rating 203.0 203.0 203.0 203.0 203.0 214.0 214.0 214.0 214.0 214.0132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

132

FEEDER 9SL: [BELMORE PARK - WAVERLEY]

FEEDER 9SA: [CAMPBELL ST - BEACONSFIELD BSP]

FEEDER 9SB/1: [BELMORE PARK - SURRY HILLS ANNEXE]

FEEDER 9SB/2: [SURRY HILLS ANNEXE - DOUBLE BAY]

FEEDER 9SC: [HAYMARKET - CAMPBELL ST]

FEEDER 9SE: [BEACONSFIELD BSP - GREEN SQUARE]

FEEDER 9S6/2: [PYRMONT - DARLING HARBOUR]

FEEDER 9S6/3: [CITY CENTRAL - DARLING HARBOUR]

FEEDER 9S6/4: [CITY CENTRAL - CITY NORTH]

FEEDER 9S9/1: [HAYMARKET - PYRMONT]

FEEDER 9S9/2: [PYRMONT - DARLING HARBOUR]

FEEDER 9R8: [ROSE BAY - WAVERLEY]

FEEDER 9RF: [BEACONSFIELD BSP - ALEXANDRIA]

FEEDER 9S2: [HAYMARKET - BEACONSFIELD BSP]

FEEDER 9S4: [HAYMARKET - BEACONSFIELD BSP]

FEEDER 9S6/1: [HAYMARKET - PYRMONT]

FEEDER 9F6: [MARRICKVILLE - BEACONSFIELD BSP]

FEEDER 9P2: [MASON PARK - CROYDON]

FEEDER 9P8: [CROYDON - LEICHHARDT]

FEEDER 9P9: [ROZELLE - LEICHHARDT]

Page D37 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 44.7 49.8 49.7 49.0 49.9 36.7 35.7 39.3 42.4 43.8

Rating 155.2 155.2 155.2 155.2 155.2 182.9 182.9 182.9 182.9 182.9

Load 78.8 77.9 78.3 78.8 80.3 86.7 86.8 86.6 88.1 88.3

Rating 160.0 160.0 160.0 160.0 160.0 179.5 179.5 179.5 179.5 179.5

Load 34.3 30.3 30.8 31.5 32.1 51.1 52.3 47.2 45.9 45.0

Rating 170.6 170.6 170.6 170.6 170.6 219.5 219.5 219.5 219.5 219.5

Load 192.0 194.1 195.9 198.4 201.7 194.7 200.9 205.4 206.4 211.7

Rating 254.0 254.0 254.0 254.0 254.0 285.0 285.0 285.0 285.0 285.0

Load 8.9 9.0 9.1 9.3 9.5 12.9 12.9 12.9 13.2 13.4

Rating 124.0 124.0 124.0 124.0 124.0 130.0 130.0 130.0 130.0 130.0

Load 198.2 199.8 201.3 203.0 206.5 196.3 200.3 203.2 204.8 207.9

Rating 229.0 229.0 229.0 229.0 229.0 229.0 229.0 229.0 229.0 229.0

Load 55.1 59.2 61.0 61.0 62.4 53.0 56.6 57.7 58.3 59.8

Rating 260.0 260.0 260.0 260.0 260.0 283.7 283.7 283.7 283.7 283.7

Load 93.1 - - - - 88.0 - - - -

Rating 275.0 - - - - 340.0 - - - -

Load 77.5 93.7 94.9 96.3 97.8 63.9 81.4 82.7 84.4 86.5

Rating 275.0 275.0 275.0 275.0 275.0 286.0 286.0 286.0 286.0 286.0

Load 22.2 22.3 22.5 22.8 23.2 16.2 19.2 19.4 19.7 20.1

Rating 240.0 240.0 240.0 240.0 240.0 257.0 257.0 257.0 257.0 257.0

Load 22.7 - - - - 16.8 - - - -

Rating 240.0 - - - - 257.0 - - - -

Load 154.8 156.7 157.9 159.3 161.9 159.9 162.8 165.1 166.2 168.3

Rating 275.0 275.0 275.0 275.0 275.0 334.0 334.0 334.0 334.0 334.0

Load 58.0 60.8 61.6 62.1 63.2 56.8 58.5 59.6 59.7 59.8

Rating 141.7 141.7 141.7 141.7 141.7 162.3 162.3 162.3 162.3 162.3

Load 202.5 204.1 205.8 207.7 211.2 200.7 205.1 208.5 209.8 213.2

Rating 254.0 254.0 254.0 254.0 254.0 286.0 286.0 286.0 286.0 286.0

Load 21.4 21.3 21.3 21.5 21.7 19.0 19.1 19.4 19.6 19.9

Rating 275.0 275.0 275.0 275.0 275.0 340.4 340.4 340.4 340.4 340.4

Load 42.9 42.8 42.5 42.9 43.4 38.2 38.4 38.8 39.2 39.8

Rating 275.0 275.0 275.0 275.0 275.0 338.1 338.1 338.1 338.1 338.1

Load - 97.5 100.0 100.1 102.3 - 89.3 91.1 92.5 95.0

Rating - 238.9 238.9 238.9 238.9 - 306.4 306.4 306.4 306.4

Load - 22.9 23.0 23.4 23.8 - 19.7 19.9 20.0 20.7

Rating - 238.9 238.9 238.9 238.9 - 306.4 306.4 306.4 306.4

Load - 119.4 122.3 122.5 124.9 - 112.4 114.7 116.3 119.4

Rating - 400.0 400.0 400.0 400.0 - 400.0 400.0 400.0 400.0

Load 45.8 48.4 48.9 49.5 50.3 45.3 46.7 47.4 47.8 47.7

Rating 170.6 170.6 170.6 170.6 170.6 221.8 221.8 221.8 221.8 221.8

FEEDER 97U (Munmorah PS to Munmorah STS) 132kV

FEEDER 95Z (Somersby to Mt Colah) 132kV

FEEDER 94L (Tuggerah BSP to Berkeley Vale) 132kV

FEEDER 97E (Munmorah STS to Charmhaven) 132kV

FEEDER 97J (Munmorah STS to Lake Munmorah STS) 132kV

FEEDER 95E (Gosford STS to Somersby) 132kV

FEEDER 958 (Tuggerah BSP to Gosford STS) 132kV

FEEDER 954 (Tuggerah BSP to Berkeley Vale) 132kV

FEEDER 95T (Vales Point to Lake Munomrah) 132kV

FEEDER 97E(3) (Lake Munmorah to Tee Vales Pt and Munmorah) 132kV

FEEDER 956 (Gosford STS to West Gosford ZS) 132kV

FEEDER 98B (Charmhaven to Wyong) 132kV

FEEDER 97E(2) (Charmhaven to Tee Munmorah and Lake Munmorah) 132kV

FEEDER 99C (Tuggerah BSP to Wyong) 132kV

FEEDER 95C (Tuggerah BSP to Ourimbah STS) 132kV

FEEDER 268 (Ourimbah STS to Wamberal) 132kV

FEEDER 951 (Ourimbah STS to West Gosford ZS) 132kV

FEEDER 957/3 (Vales Pt to Tee Ourimbah and Morisset) 132kV

FEEDER 957/1 (Ourimbah to Tee Morisset and Vales Point) 132kV

FEEDER 957/2 (Morisset to Tee Vales Pt and Ourimbah) 132kV

Central Coast Transmission Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Page D38 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Load 94.8 95.6 96.6 96.5 98.1 68.9 68.9 70.6 71.4 72.7

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load 102.0 103.6 103.9 104.4 105.6 74.2 74.2 76.1 77.0 78.4

Rating 128.0 128.0 128.0 128.0 128.0 143.0 143.0 143.0 143.0 143.0

Load 105.0 105.9 106.7 108.2 110.2 86.2 85.3 85.3 86.7 88.6

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load 104.9 105.8 106.7 108.2 110.1 86.2 85.2 85.2 86.7 88.6

Rating 290.0 290.0 290.0 290.0 290.0 308.0 308.0 308.0 308.0 308.0

Load 36.4 38.3 38.4 38.8 38.9 24.7 25.0 26.1 26.5 27.1

Rating 290.0 290.0 290.0 290.0 290.0 308.0 308.0 308.0 308.0 308.0

Load 35.1 36.9 37.0 37.3 37.4 23.8 24.1 25.1 25.5 26.1

Rating 249.0 249.0 249.0 249.0 249.0 271.0 271.0 271.0 271.0 271.0

Load 19.7 19.2 19.5 19.4 19.9 13.4 13.7 15.0 15.3 15.6

Rating 223.0 223.0 223.0 223.0 223.0 237.0 237.0 237.0 237.0 237.0

Load 100.1 101.7 102.8 101.8 103.2 103.0 105.0 107.5 108.2 107.2

Rating 166.9 166.9 166.9 166.9 166.9 186.3 186.3 186.3 186.3 186.3

Load 51.7 54.2 54.3 54.7 54.9 35.2 35.7 37.1 37.8 38.7

Rating 249.0 249.0 249.0 249.0 249.0 271.0 271.0 271.0 271.0 271.0

Load 97.4 98.9 99.9 99.0 100.3 102.6 101.5 103.8 104.5 103.7

Rating 154.0 154.0 154.0 154.0 154.0 171.0 171.0 171.0 171.0 171.0

Load 70.3 69.7 70.8 71.8 72.9 46.0 45.8 45.4 46.2 47.3

Rating 154.0 154.0 154.0 154.0 154.0 172.0 172.0 172.0 172.0 172.0

Load 70.2 69.7 70.8 71.7 72.9 46.0 45.8 45.4 46.2 47.4

Rating 154.0 154.0 154.0 154.0 154.0 172.0 172.0 172.0 172.0 172.0

Load 66.3 69.9 70.0 70.7 70.9 44.6 45.2 47.2 48.1 49.3

Rating 290.0 290.0 290.0 290.0 290.0 308.0 308.0 308.0 308.0 308.0

Load 67.3 70.9 71.1 71.8 72.0 45.2 45.8 47.9 48.8 50.0

Rating 290.0 290.0 290.0 290.0 290.0 308.0 308.0 308.0 308.0 308.0

Load 142.2 145.1 145.5 146.3 147.2 131.9 134.5 134.1 134.6 135.5

Rating 238.0 238.0 238.0 238.0 238.0 254.0 254.0 254.0 254.0 254.0

Load 144.4 143.9 144.2 144.4 145.1 137.8 137.5 137.6 138.0 138.9

Rating 290.0 290.0 290.0 290.0 290.0 306.0 306.0 306.0 306.0 306.0

Load 119.9 123.5 124.0 124.8 125.7 109.3 112.8 112.7 112.4 113.2

Rating 290.0 290.0 290.0 290.0 290.0 306.0 306.0 306.0 306.0 306.0

Load 160.7 160.9 161.2 162.3 164.4 124.3 121.4 121.7 123.0 125.5

Rating 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0

Load 104.3 104.0 103.7 104.2 105.6 83.9 83.0 83.2 84.0 85.8

Rating 329.0 329.0 329.0 329.0 329.0 348.0 348.0 348.0 348.0 348.0

Load 119.2 120.5 121.7 123.0 124.3 86.0 82.1 82.0 83.0 84.4

Rating 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0

Load 160.4 160.6 160.9 162.0 164.1 124.1 121.2 121.5 122.8 125.3

Rating 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0 549.0

Load 98.0 97.7 97.4 97.9 99.1 80.2 79.4 79.6 80.2 81.9

Rating 274.0 274.0 274.0 274.0 274.0 274.0 274.0 274.0 274.0 274.0

Load 119.1 120.4 121.6 122.9 124.3 86.0 82.1 82.0 83.0 84.4

Rating 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0 282.0

Load 79.0 78.7 78.4 78.8 79.7 66.5 66.0 66.1 66.5 67.8

Rating 329.0 329.0 329.0 329.0 329.0 348.0 348.0 348.0 348.0 348.0

FEEDER 98R Tomago BSP to Beresfield STS 132kV

FEEDER 98N Tomago BSP to Beresfield STS 132kV

FEEDER 98A Tomago BSP to Tomago STS 132kV

Hunter Transmission Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

FEEDER 9NA Newcastle BSP to Beresfield STS 132kV

FEEDER 952 Newcastle BSP to Rathmines 132kV

FEEDER 96U Newcastle BSP to Kurri ZS 132kV

FEEDER 9F4 Tomago BSP to Tomago STS 132kV

FEEDER 96B Newcastle BSP to Hydro Aluminium 132kV

FEEDER 96W Newcastle BSP to Hydro Aluminium 132kV

FEEDER 96A Newcastle BSP to Kurri STS 132kV

FEEDER 95L Kurri STS to Hydro Aluminium 132kV

FEEDER 95M Muswellbrook BSP to Mitchell Line STS 132kV

FEEDER 95A Newcastle BSP to Awaba STS 132kV

FEEDER 950 Newcastle BSP to Jesmond 132kV

FEEDER 96Z Necastle BSP to Maryland 132kV

FEEDER 960(2) Newcastle BSP to Argenton and Charlestown tee to Charlestown 132kV

FEEDER 960(3) Newcastle BSP to Argenton and Charlestown tee to Argenton 132kV

FEEDER 961(1) Newcastle BSP to Tee Argenton and Merewether 132kV

FEEDER 95U Muswellbrook BSP to Singleton STS 132kV

FEEDER 95H Muswellbrook BSP to Muswellbrook STS 132kV

FEEDER 960(1) Newcastle BSP to Tee Argenton and Charlestown 132kV

FEEDER 961(2) Newcastle BSP to Argenton and Merewether tee to Merewether 132kV

FEEDER 961(3) Newcastle BSP to Argenton and Merewether tee to Argenton 132kV

FEEDER 9F9 Charlestown to Merewether 132kV

Page D39 of D40

2016/17 2017/18 2018/19 2019/20 2020/21 2016 2017 2018 2019 2020

Hunter Transmission Area - Feeder Load Forecast

Feeder Name Voltage (MVA)

Summer (MVA) Winter (MVA)

Load 179.9 181.3 181.9 183.0 185.3 142.2 140.9 142.5 144.1 146.9

Rating 230.0 230.0 230.0 230.0 230.0 256.0 256.0 256.0 256.0 256.0

Load 180.0 181.4 182.0 183.1 185.4 142.3 141.0 142.6 144.2 147.0

Rating 273.0 273.0 273.0 273.0 273.0 292.0 292.0 292.0 292.0 292.0

Load - - - - - - - - - -

Rating 264.0 264.0 264.0 264.0 264.0 264.0 264.0 264.0 264.0 264.0

Load 39.2 39.0 39.1 38.7 39.1 30.2 30.4 30.5 31.0 31.5

Rating 249.0 249.0 249.0 249.0 249.0 271.0 271.0 271.0 271.0 271.0

Load 9.2 9.0 8.9 8.9 9.0 4.8 4.8 4.8 5.0 5.1

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load 106.1 109.3 109.5 110.1 110.7 98.1 100.3 100.3 101.0 101.5

Rating 171.0 171.0 171.0 171.0 171.0 181.0 181.0 181.0 181.0 181.0

Load 147.9 147.3 147.3 147.8 148.7 141.0 140.7 140.0 141.3 142.3

Rating 290.0 290.0 290.0 290.0 290.0 306.0 306.0 306.0 306.0 306.0

Load 9.2 9.0 8.8 8.8 9.0 5.1 5.1 5.0 5.2 5.3

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load 55.2 57.7 58.2 58.4 59.2 42.9 43.2 45.3 46.1 46.9

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load 159.5 161.2 161.9 163.1 165.2 124.0 122.6 124.1 125.6 128.2

Rating 240.0 240.0 240.0 240.0 240.0 266.0 266.0 266.0 266.0 266.0

Load 9.7 9.7 9.8 9.9 10.1 8.0 7.9 7.8 7.9 8.1

Rating 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0

Load 9.8 9.8 9.9 10.0 10.2 8.0 7.9 7.9 7.9 8.2

Rating 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0 191.0

Load 25.1 47.0 47.5 47.9 48.0 44.4 44.0 39.5 39.7 40.0

Rating 170.6 170.6 170.6 170.6 170.6 219.5 219.5 219.5 219.5 219.5

Load 43.7 42.9 43.5 44.0 44.6 31.4 31.3 30.6 31.0 31.6

Rating 154.0 154.0 154.0 154.0 154.0 172.0 172.0 172.0 172.0 172.0

Load 46.6 45.8 46.4 46.9 47.5 34.6 34.5 33.9 34.3 34.9

Rating 154.0 154.0 154.0 154.0 154.0 172.0 172.0 172.0 172.0 172.0

Load 68.7 72.7 73.7 73.0 74.0 85.2 83.6 88.1 88.8 87.7

Rating 134.0 134.0 134.0 134.0 134.0 148.0 148.0 148.0 148.0 148.0

Load 45.5 54.9 55.6 55.0 56.0 61.6 60.5 71.1 71.5 70.5

Rating 134.0 134.0 134.0 134.0 134.0 148.0 148.0 148.0 148.0 148.0

Load 28.4 21.7 22.0 22.2 22.4 27.4 27.4 20.1 20.3 20.5

Rating 59.4 59.4 59.4 59.4 59.4 64.0 64.0 64.0 64.0 64.0

Load 28.4 20.5 20.7 20.9 21.1 27.5 27.4 19.0 19.1 19.5

Rating 59.0 59.0 59.0 59.0 59.0 64.0 64.0 64.0 64.0 64.0

Load 9.5 9.1 9.0 9.0 9.2 4.8 4.7 4.5 4.7 4.8

Rating 166.0 166.0 166.0 166.0 166.0 186.0 186.0 186.0 186.0 186.0

Load - - - - - 84.8 - - - -

Rating - - - - - 171.0 - - - -

Load 89.9 91.4 92.4 91.6 92.8 - 94.2 96.6 97.3 96.5

Rating 153.6 153.6 153.6 153.6 153.6 - 171.0 171.0 171.0 171.0

Load 68.1 70.0 70.9 70.2 71.3 - 78.7 81.1 81.7 80.8

Rating 153.6 153.6 153.6 153.6 153.6 - 171.0 171.0 171.0 171.0

Load - 23.6 23.5 23.5 23.5 - - 23.4 23.4 23.3

Rating - 128.0 128.0 128.0 128.0 - - 128.0 128.0 128.0

FEEDER 9N9(1) Broadmeadow to Waratah West BSP 132kV

FEEDER 9N9(2) Waratah West to Broadmeadow 132kV

FEEDER 9N9(3) Waratah STS to Tee Broadmeadow and Waratah West BSP 132kV

FEEDER 95X Mitchell Line STS to Singleton STS 132kV

FEEDER 955 Redbank to Rothbury 132kV

FEEDER 99Y Beresfield STS to Kurri STS 132kV

FEEDER 96E Kurri ZS to Kurri STS 132kV

FEEDER 95R Kurri STS to Rothbury 132kV

FEEDER 95F Muswellbrook STS to Mitchell Line STS 132kV

FEEDER 9P1 Merewether STS to Adamstown 132kV

FEEDER 957/2 Morisset to Tee Vales Point and Ourimbah 132kV

FEEDER 9F5 Jesmond to Waratah STS 132kV

FEEDER 9F8 Merewether STS to Broadmeadow 132kV

FEEDER 9P0 Merewether STS to Adamstown 132kV

FEEDER 95Y(1) Rathmines to Morisset and Eraring tee to Eraring 132kV

FEEDER 9F3 Rathmines to Eraring 132kV

FEEDER 96J Maryland to Waratah STS 132kV

FEEDER 95Y(3) Rathmines to Morisset and Eraring tee to Rathmines 132kV

FEEDER 95Y(2) Rathmines to Morisset and Eraring tee to Morisset 132kV

FEEDER 9FC Toronto West to Rathmines 132kV

FEEDER 9F7 Morisset to Morisset Annex 132kV

FEEDER 95G Awaba STS to Rathmines 132kV

FEEDER 95G Awaba STS to Toronto West 132kV

FEEDER 953 Singleton STS to Redbank 132kV

Page D40 of D40

December 2016

Annexure E – Compliance Checklists

NER Clause NER RequirementsSection in

DTPAR

5.12.2 (a)Subject to paragraph 5.12.2 (b), by 30 June each year all TNSP's must publish an TAPR setting out the results of the annual planning review conducted in accordance with clause 5.12.1.

Throughout

5.12.2 (b)If a Network Service Provider is a TNSP only because it owns, operates or controls dual function assets then it may publish its TAPR in the same document and at the same time as its DAPR.

Throughout

5.12.2 (c) The TAPR must set out: see below

5.12.2 (c)(1)the forecast loads submitted by a DNSP in accordance with clause 5.11.1 or as modified in accordance with clause 5.11.1(d);

5.2

5.12.2 (c)(2) planning proposals for future connection points; 5.1.2

5.12.2 (c)(3)a forecast of constraints and inability to meet the network performance requirements set in schedule 5.1 or relevant legislation or regulations of a participating jurisdiction over 1, 3, and 5 years;

5.3.4,5.4.4,5.5.4

5.12.2 (c)(4)in respect of information required by subparagraph 5.12.2 (c)(3), where an estimated reduction in forecast load would defer a forecast constraint for a period of 12 months, include:

5.3.4,5.4.4,5.5.4

5.12.2 (c)(4)(i) the year and months in which a constraint is forecast to occur; "

5.12.2 (c)(4)(ii) the relevant connection points at which the estimated reduction in forecast load may occur; "

5.12.2 (c)(4)(iii) the estimated reduction in forecast load in MW needed; and "

5.12.2 (c)(4)(iv)a statement of whether the TNSP plans to issue a Request For Proposals for augmentation or a non-network option identified by the annual planning review conducted under clause 5.12.1 (b) and if so, the expected date the request will be issued;

"

5.12.2 (c)(5)for all proposed augmentations to the network the following information, in sufficient detail relative to the size or significance of the project and the proposed operational date of the project:

5.3.5,5.4.5,5.5.5

5.12.2 (c)(5)(i) project/asset name and the month and year in which it is proposed that the aset will become operational; "

5.12.2 (c)(5)(ii)the reason for the actual or potential constraint, if any, or inability, if any, to meet the network performance requirements set out in schedule 5.1 or relevant legislation or regulations of a participating jurisdiction, including load forecasts and all assumptions used;

"

5.12.2 (c)(5)(iii)the proposed solution to the constriant or inability to meet the newtork performance requirements identified in subparagraph (ii), if any:

"

5.12.2 (c)(5)(iv) total cost of the proposed solutions; 7.1.4

5.12.2 (c)(5)(v)whether the proposed solution will have a material inter-network impact. In assessing whether an augmentation to the network will have a material inter-network impact a TNSP must have regard to the objective set of criteria published by AMEO in accordance with clause 5.21 (if any such criteria have been published by AEMO); and

5.1.3

5.12.2 (c)(5)(vi)

other reasonable network options and non-network options considered to address the actual or potential constraint or inability to meet the network performance requirements identifield in subparagraph (ii), if any. Other reasonable network and non-network options include, but are not limited to, interconnections, generation options, demand side options, market network service options and options involving other transmission and distribution networks.

5.3, 5.4, 5.5

5.12.2 (c)(6)the manner in which the proposed augmentations relate to the most recent NTNDP (National Transmission Network Development Plan) and the development strategies for current or potential national transmission flow paths (NTFPs) that are specified in that NTNDP.

3.6.1

5.12.2 (c)(7) for all proposed replacement transmission network assets: 7.1.7

5.12.2 (c)(7)(i) a brief description of the new replacement transmission network asset project, including location; "

5.12.2 (c)(7)(ii)the date from which the TNSP proposes that the proposed new replacement transmission network asset will become operational;

"

5.12.2 (c)(7)(iii) the purpose of the proposed new replacement transmission network asset; "

5.12.2 (c)(7)(iv)

a list of any reasonable network options or non-network options to the proposed new replacement transmission network asset which are being, or have been, considered by the TNSP (if any). Those alternatives include, but are not limited to, interconnectiors, generation options, demand side options, maket network service options and options involving other transmission or distribution networks, and

"

5.12.2 (c)(7)(v) the TNSP's estimated total capitalised expenditure on the proposed new replacement transmission network asset; and "

5.12.2 (c)(8)any information requirement to be included in an TAPR under clause 5.16.3(c) in relation to a network investment which is determined to be required to address an urgent and unforeseen network issue.

7.4

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S5.8(a) Information regading the Distribution Network Servcie Provider and its network, including: See belowS5.8(a)(1) provide a description of Ausgrid’s network 2.1 & 2.2S5.8(a)(2) provide a description of Ausgrid's operating environment 2.1 & 2.2S5.8(a)(3) provide a description of the number and types of distribution assets 2.2

S5.8(a)(4)provide methodologies used in preparing the Distribution Annual Planning Report, including methodologies used to identify system limitations and any assumptions applied

2.3 & 2.4

S5.8(a)(5)provide analysis and explanation of any aspects of forecasts and information provided in the Distribution Annual Planning Report that have changed significantly from previous forecasts and information in the preceding year.

2.5, 3.1.2, 4

S5.8(b) Forecasts for the forward planning period, including at least: See belowS5.8(b)(1) a description of the forecasting methodology used, sources of input information, and the assumptions applied; 3.1, 3.3, 3.4S5.8(b)(2) Provide load forecasts: See below

S5.8(b)(2)(i) at the transmission-distribution connection points 3.2

S5.8(b)(2)(ii) for sub-transmission lines, and 3.3, 4.x.3, Annex D

S5.8(b)(2)(iii) for zone substations 4.x.2, Annex C

S5.8(b)(2) Including, where applicable, for each item above: See belowS5.8(b)(2)(iv) total capacity Annex CS5.8(b)(2)(v) firm delivery capacity for summer periods and winter periods Annex C

S5.8(b)(2)(vi) peak load (summer or winter and an estimate of the number of hours per year that 95% of peak is expected to be reached) Annex C

S5.8(b)(2)(vii) power factor at time of peak load Annex CS5.8(b)(2)(viii) load transfer capacities 3.4.1.1, Annex CS5.8(b)(2)(ix) generation capacity of known embedded generating units Annex C

S5.8(b)(3)Provide forecasts of future transmission-distribution connection points (and any associated connection assets), sub-transmission lines and zone substations, including for each future transmission-distribution connection point and zone substation:

6.1 to 6.4

S5.8(b)(3)(i) its location 6.1 to 6.4S5.8(b)(3)(ii) future loading level 6.1 to 6.4S5.8(b)(3)(iii) proposed commissioning time (estimate of month and year) 6.1 to 6.4

S5.8(b)(4) forecasts of Ausgrid’s performance against any reliability targets in a service target performance incentive scheme ; and 9.1.4

S5.8(b)(5) Provide a description of any factors that may have a material impact on Ausgrid’s network , including factors affecting; 3.5

S5.8(b)(5)(i) fault levels 3.5.1S5.8(b)(5)(ii) voltage levels 3.5.2S5.8(b)(5)(iii) other power system security requirements 3.5.3S5.8(b)(5)(iv) the quality of supply to other Network Users (where relevant); and 3.5.4S5.8(b)(5)(v) ageing and potentially unreliable assets 10.4 & 10.5

S5.8(c) Information on system limitations for sub-transmission lines and zone substations, including at least: See belowS5.8(c)(1) estimates of the location and timing (month(s) and year) of the system limitation 4

S5.8(c)(2)analysis of any potential for load transfer capacity between supply points that may decrease the impact of the system limitation or defer the requirement for investment

3.4

S5.8(c)(3) impact of the system limitation, if any, on the capacity at transmission distribution connection points 4

S5.8(c)(4)a brief discussion of the potential solutions that may address the system limitation in the forward planning period, if a solution is required; and

4

S5.8(c)(5)where an estimated reduction in forecast load would defer a forecast system limitation for a period of, at least, 12 months, include:

See below

S5.8(c)(5)(i) an estimate the month and year in which a system limitation is forecast to occur 4S5.8(c)(5)(ii) the relevant connection points at which the estimated reduction in forecast load may occur 4

S5.8(c)(5)(iii) the estimated reduction in forecast load in MW or improvements in power factor needed to defer the forecast system limitation. 4

S5.8(d)for any primary distribution feeders for which Ausgrid has prepared forecasts of maximum demands under NER clause 5.13.1(d)(1)(iii) and which are currently experiencing an overload, or are forecast to experience an overload in the next two years Ausgrid must set out:

4.26

S5.8(d)(1) the location of the primary distribution feeder; 4.26

S5.8(d)(2)the extent to which load exceeds, or is forecast to exceed, 100% (or lower utilisation factor, as appropriate) of the normal cyclic rating under normal conditions (in summer periods or winter periods);

4.26

S5.8(d)(3) the types of potential solutions that may address the overload or forecast overload; and 4.26S5.8(d)(4) where an estimated reduction in forecast load would defer a forecast overload for a period of 12 months, include: 4.26

S5.8(d)(4)(i) an estimate of the month and year in which the overload is forecast to occur; 4.26

S5.8(d)(4)(ii)a summary of the location of relevant connection points at which the estimated reduction in forecast load would defer the overload;

4.26

S5.8(d)(4)(iii) the estimated reduction in forecast load in MW needed to defer the forecast system limitation. 4.26

S5.8(e) A high-level summary of each RIT-D project for which the regulatory investment test for distribution has been completed in the preceding year or is in progress, including:

7.1.1 & 7.1.2

S5.8(e)(1) if the regulatory investment test for distribution is in progress, the current stage in the process 7.1.1 & 7.1.2S5.8(e)(2) a brief description of the identified need 7.1.1 & 7.1.2S5.8(e)(3) a list of credible options assessed or being assessed (to the extent reasonably practicable) 7.1.1 & 7.1.2S5.8(e)(4) If the RIT-D has been completed, a brief description of the conclusion, including: 7.1.1 & 7.1.2

S5.8(e)(4)(i) the net economic benefit of each credible option 7.1.1 & 7.1.2S5.8(e)(4)(ii) the estimated capital cost of the preferred option; and 7.1.1 & 7.1.2S5.8(e)(4)(iii) the estimated construction timetable and commissioning date (where relevant) of the preferred option 7.1.1 & 7.1.2

S5.8(e)(5)Any impacts on Network Users, including any potential material impacts on connection charges and distribution use of system charges that have been estimated.

No RIT-D project completed during the

year

S5.8(f)For each identified system limitation which Ausgrid has determined will require a regulatory investment test for distribution , provide an estimate of the month and year when the test is expected to commence

7.1.3

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S5.8(g)Provide a summary of all committed projects to be carried out within the forward planning period with an estimated capital cost of $2 million or more (as varied by a cost threshold determination) that are to address:

7.3 & 7.4

S5.8(g)(1) a refurbishment or replacement need; or 7.3S5.8(g)(2) an urgent and unforseen network issue as described in clause 5.17.3(a)(1) 7.4

including: (for each of S5.8(g1) and (g2) ) 7.3 & 7.4(1) a brief description of the investment, including its purpose, its location, the estimated capital cost of the investment and an estimate of the date (month and year) the investment is expected to become operational;

7.3 & 7.4

(2) a brief description of the alternative options considered by the Distribution Network Service Provider in deciding on the preferred investment, including an explanation of the ranking of these options to the committed project. Alternative options could include, but are not limited to, generation options, demand side options, and options involving other distribution or transmission networks;

7.3 & 7.4

S5.8(h)Include the results of any joint planning undertaken with the Transmission Network Service Provider in the preceding year, including:

8

S5.8(h)(1)a summary of the process and methodology used by Ausgrid and the relevant Transmission Network Service Provider to undertake joint planning;

8.1.1

S5.8(h)(2)a brief description of any investments that have been planned through this process, including the estimated capital costs of the investment and an estimate of the timing (month and year) of the investment; and

8.1.2 & 8.1.3

S5.8(h)(3) where additional information on the investments may be obtained. 8.1.4

S5.8(i)Include the results of any joint planning undertaken with other Distribution Network Service Providers in the preceding year, including:

8.2

S5.8(i)(1) a summary of the process and methodology used by the Distribution Network Service Providers to undertake joint planning; 8.2.1

S5.8(i)(2)a brief description of any investments that have been planned through this process, including the estimated capital cost of the investment and an estimate of the timing (month and year) of the investment; and

8.2.2 & 8.2.3

S5.8(i)(3) where additional information on the investments may be obtained. 8.2.4

S5.8(j) Provide information on the performance of the Distribution Network Service Providers network, including: 9

S5.8(j)(1) a summary description of the reliability measures and standards in applicable regulatory instruments; 9.1

S5.8(j)(2) a summary description of the quality of supply standards that apply, including the relevant codes, standards and guidelines 9.2

S5.8(j)(3)a summary description of the performance of the distribution network against the reliability measures and standards for the preceding year

9.3

S5.8(j)(4)where the network reliability measures and standards were not met in the preceding year, information on the corrective action taken or planned

9.4 & 9.5

S5.8(j)(5)a summary description of Ausgrid’s processes to ensure compliance with the measures and standards described under subparagraphs (1) and (2) above; and

9.5

S5.8(j)(6)an outline of the information contained Ausgrid’s most recent submission to the AER under the service target performance incentive scheme (RIN).

9.1.3

S5.8(k) Include information on Ausgrid’s asset management approach, including: 10

S5.8(k)(1) a summary of any asset management strategy employed by the DNSP; 10.1 to 10.5

S5.8(k)(1A)an explanation of how the Distribution Network Service Provider takes into account the cost of distribution losses when developing and implementing its asset management and investment strategy

10.6

S5.8(k)(2)a summary of any issues that may impact on the system limitations identified in the Distribution Annual Planning Report that has been identified through carrying out asset management

3.5

S5.8(k)(3)information about where further information on the asset management strategy and methodology adopted by Ausgrid may be obtained.

10.7

S5.8(l) Include information on Ausgrid's demand management activities, including: 11S5.8(l)(1) a qualitative summary of: See below

S5.8(l)(1)(i) non-network solutions that have been considered in the past year, including generation from embedded generating units; 11.3

S5.8(l)(1)(ii) key issues arising from applications to connect embedded generating units received in the past year; 3.5.5

S5.8(l)(1)(iii)actions taken to promote non-network initiatives in the preceding year, including generation from embedded generating units; and

11.5

S5.8(l)(iv)the DNSPs plans for demand management and generation from embedded generating units over the forward planning period (5 years for Distribution).

11.4

S5.8(l)(2) a quantitative summary of: 11.7

S5.8(l)(2)(i) connection enquiries received under clause 5.3A.5; 11.7

S5.8(l)(2)(ii) applications to connect received under clause 5.3A.9; and 11.7

S5.8(l)(2)(iii) the average time taken to complete applications to connect; 11.7

Include information on Ausgrid's investments in metering systems which occurred in the preceding year, and planned investments in metering systems in the forward planning period; and

12.1

Include information on Ausgrid's investments in information technology systems which occurred in the preceding year, and planned investments in information technology systems in the forward planning period

12.2

S5.8(n)Include a regional development plan consisting of a map of Ausgrid's network as a whole or maps by regions in accordance with Ausgrid's planning methodology or as required under any regulatory obligation or requirement identifying:

See below

S5.8(n)(1) sub-transmission lines, zone substations and transmission-distribution connection points; 4

S5.8(n)(2)any system limitations that have been forecast to occur in the forward planning period, including, where they have been identified overloaded primary distribution feeders.

4

S5.8(m)

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