Distribution Annual Planning Report

Transcription

Distribution Annual
Planning Report
2014 DAPR
Endeavour Energy
December 2014
DISCLAIMER
Endeavour Energy is registered as a Distribution Network Service Provider. This Distribution Annual
Planning Report (DAPR) 2014 has been prepared and published by Endeavour Energy 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 network annual planning review and should only be used for
those purposes.
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, Endeavour Energy 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 Endeavour Energy and their employees, agents and
consultants shall have no liability (including liability to any person by reason of negligence or negligent
misstatement) for any statements, opinions, information or matter (expressed or implied) arising out of,
contained in or derived from, or for any omissions from, the information in this document, except insofar
as liability under any New South Wales and Commonwealth statute cannot be excluded.
Contact
For all enquiries regarding the Distribution Annual Planning Report 2014 and for making written
submissions contact:
Endeavour Energy
Manager – Asset and Network Planning
GPO Box 811
Seven Hills NSW 1730
Email: [email protected]
CONTENTS
1.0 EXECUTIVE SUMMARY ..................................................................................................... 1 2.0 INTRODUCTION ................................................................................................................. 2 2.1 ABOUT ENDEAVOUR ENERGY .................................................................................................... 2 2.1.1 OUR OBJECTIVES ............................................................................................................. 2 2.1.2 OUR VALUES ..................................................................................................................... 3 2.1.3 OUR PRINCIPAL ACTIVITIES ............................................................................................ 3 2.1.4 OPERATING ENVIRONMENT ............................................................................................ 3 2.1.5 ENDEAVOUR ENERGY STATISTICS................................................................................. 5 2.2 ENDEAVOUR ENERGY NETWORK .............................................................................................. 5 2.2.1 NUMBER AND TYPES OF DISTRIBUTION ASSETS ......................................................... 6 2.3 ANNUAL PLANNING REVIEW ....................................................................................................... 7 2.3.1 NETWORK PLANNING PROCESS..................................................................................... 7 2.4 SIGNIFICANT CHANGES FROM PREVIOUS DAPR ..................................................................... 9 2.4.1 ANALYSIS AND EXPLANATION OF FORECAST CHANGES ........................................... 9 2.4.2 ANALYSIS AND EXPLANATION OF CHANGES IN PLANNING PROCESS ..................... 9 3.0 FORECASTS FOR THE FORWARD PLANNING PERIOD .............................................. 10 3.1 FORECASTING METHODOLOGY ............................................................................................... 11 3.1.1 FORECAST INPUT INFORMATION SOURCES ............................................................... 11 3.1.2 ASSUMPTIONS APPLIED TO FORECASTS .................................................................... 11 3.2 DEMAND FORECASTS................................................................................................................ 11 3.2.1 BAULKHAM HILLS TRANSMISSION SUBSTATION ....................................................... 13 3.2.2 BELLAMBI TRANSMISSION SUBSTATION .................................................................... 16 3.2.3 BLACKTOWN TRANSMISSION SUBSTATION ............................................................... 19 3.2.4 CAMELLIA TRANSMISSION SUBSTATION .................................................................... 22 3.2.5 CARLINGFORD TRANSMISSION SUBSTATION............................................................. 25 3.2.6 DAPTO BULK SUPPLY POINT......................................................................................... 28 3.2.7 FAIRFAX LANE TRANSMISSION SUBSTATION ............................................................. 31 3.2.8 GUILDFORD TRANSMISSION SUBSTATION.................................................................. 34 3.2.9 HAWKESBURY TRANSMISSION SUBSTATION ............................................................. 37 3.2.10 HOLROYD BULK SUPPLY POINT ................................................................................... 40 3.2.11 ILFORD TRANSMISSION SUBSTATION ......................................................................... 43 3.2.12 INGLEBURN BULK SUPPLY POINT ................................................................................ 46 3.2.13 KATOOMBA NORTH TRANSMISSION SUBSTATION .................................................... 49 3.2.14 LAWSON TRANSMISSION SUBSTATION ....................................................................... 52 3.2.15 LIVERPOOL TRANSMISSION SUBSTATION .................................................................. 55 3.2.16 LIVERPOOL BULK SUPPLY POINT ................................................................................ 58 3.2.17 MACARTHUR BULK SUPPLY POINT .............................................................................. 61 i | 2014 Distribution Annual Planning Report | December 2014
3.2.18 MT DRUITT TRANSMISSION SUBSTATION.................................................................... 65 3.2.19 MOUNT PIPER BULK SUPPLY POINT ............................................................................ 68 3.2.20 MOUNT TERRY TRANSMISSION SUBSTATION ............................................................. 71 3.2.21 NEPEAN TRANSMISSION SUBSTATION ........................................................................ 74 3.2.22 OUTER HARBOUR TRANSMISSION SUBSTATION ....................................................... 78 3.2.23 PENRITH TRANSMISSION SUBSTATION ....................................................................... 81 3.2.24 REGENTVILLE BULK SUPPLY POINT ............................................................................ 84 3.2.25 SHOALHAVEN TRANSMISSION SUBSTATION .............................................................. 87 3.2.26 SPRINGHILL TRANSMISSION SUBSTATION ................................................................. 90 3.2.27 SYDNEY NORTH BULK SUPPLY POINT ......................................................................... 93 3.2.28 SYDNEY WEST BULK SUPPLY POINT ........................................................................... 96 3.2.29 VINEYARD BULK SUPPLY POINT ................................................................................. 100 3.2.30 WALLERAWANG BULK SUPPLY POINT ...................................................................... 103 3.2.31 WARRIMOO TRANSMISSION SUBSTATION ................................................................ 107 3.2.32 WEST LIVERPOOL TRANSMISSION SUBSTATION ..................................................... 110 3.2.33 WEST TOMERONG TRANSMISSION SUBSTATION..................................................... 113 3.2.34 WEST WETHERILL PARK TRANSMISSION SUBSTATION .......................................... 116 3.3 FORECAST OF RELIABILITY TARGET PERFORMANCE ........................................................ 119 3.4 OTHER FACTORS WHICH HAVE A MATERIAL IMPACT ON THE NETWORK ....................... 121 3.4.1 FAULT LEVELS .............................................................................................................. 121 3.4.2 VOLTAGE LEVELS ......................................................................................................... 121 3.4.3 POWER SYSTEM SECURITY REQUIREMENTS ........................................................... 121 3.4.4 QUALITY OF SUPPLY .................................................................................................... 121 3.4.5 AGEING ASSETS ........................................................................................................... 121 3.4.6 POTENTIALLY UNRELIABLE ASSETS ......................................................................... 123 4.0 IDENTIFIED SYSTEM LIMITATIONS ............................................................................. 124 4.1 NOTES ON INDICATIVE NETWORK SOLUTIONS .................................................................... 124 4.2 TRANSMISSION AND ZONE SUBSTATIONS ........................................................................... 125 4.3 SUB-TRANSMISSION FEEDERS............................................................................................... 131 4.4 PRIMARY DISTRIBUTION FEEDERS ........................................................................................ 136 5.0 NETWORK INVESTMENT .............................................................................................. 142 5.1 RIT-D’S COMPLETED OR IN PROGRESS ................................................................................ 142 5.2 UPCOMING RIT-D’S FOR SYSTEM LIMITATIONS ................................................................... 143 5.3 COMMITTED INVESTMENTS .................................................................................................... 144 5.3.1 REFURBISHMENT AND REPLACEMENT INVESTMENTS ........................................... 144 5.3.2 URGENT AND UNFORSEEN INVESTMENTS ................................................................ 147 6.0 JOINT PLANNING .......................................................................................................... 148 6.1 JOINT PLANNING WITH TRANSGRID ...................................................................................... 148 ii | 2014 Distribution Annual Planning Report | December 2014
6.1.1 PROCESS & METHODOLOGY....................................................................................... 148 6.1.2 DESCRIPTION OF INVESTMENTS ................................................................................ 149 6.1.3 ADDITIONAL INFORMATION ......................................................................................... 149 6.2 JOINT PLANNING WITH OTHER DNSP .................................................................................... 149 6.2.1 PROCESS & METHODOLOGY....................................................................................... 150 6.2.2 JOINT DNSP PLANNING COMPLETED IN PRECEEDING YEAR ................................. 150 6.2.3 PLANNED DNSP JOINT NETWORK INVESTMENTS .................................................... 150 6.2.4 ADDITIONAL INFORMATION ......................................................................................... 150 7.0 NETWORK PERFORMANCE ......................................................................................... 151 7.1 NETWORK RELIABILITY ........................................................................................................... 151 7.2 NETWORK QUALITY OF SUPPLY ............................................................................................ 152 7.2.1 NETWORK QUALITY OF SUPPLY CORRECTIVE ACTION .......................................... 152 7.3 COMPLIANCE PROCESSES ..................................................................................................... 153 7.4 SERVICE TARGET PERFORMANCE INCENTIVE SCHEME SUBMISSION ............................. 153 8.0 ASSET MANAGEMENT.................................................................................................. 154 8.1 ENDEAVOUR ENERGY’S ASSET MANAGEMENT APPROACH.............................................. 154 8.1.1 NETWORK STANDARDS ............................................................................................... 154 8.1.2 ASSET RENEWAL .......................................................................................................... 154 8.1.3 OPTIMISING THE UTILISATION OF THE NETWORK ASSETS .................................... 155 8.1.4 FUTURE PROOFING THE NETWORK ........................................................................... 155 8.1.5 CUSTOMER ENGAGEMENT .......................................................................................... 155 8.2 DEMAND MANAGEMENT .......................................................................................................... 156 8.2.1 STRATEGIC ASSET MANAGEMENT PLAN .................................................................. 156 8.3 NETWORK ISSUES IMPACTING IDENTIFIED SYSTEM LIMITATIONS ................................... 157 8.3.1 ASSET RATINGS ............................................................................................................ 157 8.3.2 SOLAR PHOTOVOLTAIC (PV) ....................................................................................... 157 8.3.3 FUTURE IMPACTS OF BATTERY ENERGY STORAGE SYSTEMS .............................. 158 8.3.4 ELECTRIC VEHICLES .................................................................................................... 158 8.3.5 OBTAINING FURTHER INFORMATION ON ENDEAVOUR ENERGY’S ASSET
MANAGEMENT APPROACH ..................................................................................................... 159 9.0 DEMAND MANAGEMENT .............................................................................................. 160 9.1 DEMAND MANAGEMENT ACTIVITIES IN THE PRECEDING YEAR ........................................ 160 9.1.1 SCREENING FOR NON-NETWORK OPTIONS .............................................................. 161 9.2 DETAILS OF IMPLEMENTED NON-NETWORK PROGRAMS .................................................. 162 9.3 PROMOTION OF NON-NETWORK OPTIONS ........................................................................... 162 9.3.1 SUMMARY OF NON-NETWORK OPTIONS REPORTS ................................................. 162 9.3.2 SUMMARY OF DRAFT PROJECT ASSESSMENT REPORTS....................................... 162 9.3.3 SUMMARY OF FINAL PROJECT ASSESSMENT REPORTS ........................................ 162 iii | 2014 Distribution Annual Planning Report | December 2014
9.4 PLANS FOR DEMAND MANAGEMENT AND EMBEDDED GENERATION .............................. 162 10.0 INVESTMENTS IN METERING AND INFORMATION TECHNOLOGY.......................... 164 10.1 INFORMATION TECHNOLOGY ................................................................................................. 164 10.2 METERING ................................................................................................................................. 165 11.0 REGIONAL DEVELOPMENT PLANS ............................................................................ 166 11.1 ENDEAVOUR ENERGY REGIONAL NETWORK MAPS............................................................ 166 12.0 GLOSSARY .................................................................................................................... 173 iv | 2014 Distribution Annual Planning Report | December 2014
1.0
EXECUTIVE SUMMARY
As a state-owned corporation Endeavour Energy is an electricity Distribution Network Service Provider
(DNSP) that develops, owns, operates and maintains electricity distribution assets in NSW.
On 11 October 2012 the Australian Energy Market Commission (AEMC) amended the National
Electricity Rules (NER) to establish a national Distribution Network Planning and Expansion Framework
which is applicable to all DNSPs operating in the national electricity market. Commencing on 1 January
2013, this Rule requires all registered DNSPs to:

Conduct an annual planning review and publish a Distribution Annual Planning Report (DAPR);

Conduct economic assessments of potential project options under a new regulatory investment
test for distribution (RIT-D), and

Implement a Demand Side Engagement Strategy to consult with and engage non-network
providers in the development and evaluation of potential solutions to identified network needs.
It is required that the annual planning review includes the planning for all assets and activities carried out
by Endeavour Energy that would materially affect the performance of its network. This includes planning
activities associated with replacement and refurbishment of assets and negotiated services. The
objective of the annual planning review is to identify possible future issues that could negatively affect
the performance of the distribution network to enable DNSPs to plan for and adequately address such
issues in a sufficient timeframe. The outcome of the annual planning review is the Distribution Annual
Planning Report (DAPR).
Endeavour Energy is required to prepare and publish a DAPR that is compliant with the requirements of
National Electricity Rules Schedule S5.8 Distribution Annual Reporting Requirements to:

Provide transparency to Endeavour Energy’s decision making processes and provide a level
playing field for all stakeholders in the national electricity market in terms of attracting investment
and promoting efficient decisions;

Include information associated with all parts of the planning process including forecasting,
identification of network limitations and the development of credible options to address network
constraints;

To give third parties the opportunity to offer alternative proposals to alleviate constraints. These
proposals may include non-network options such as demand management or embedded
generation solutions.

Set out the results of Endeavour Energy’s annual planning review, including joint planning,
covering a minimum five year forward planning period for distribution assets;

Inform registered participants and interested parties of the annual planning review outcomes
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 Endeavour Energy '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

Assist non-network providers, TNSPs, other DNSPs and connection applicants to make efficient
investment decisions.
The DAPR covers a minimum five year forward planning period for distribution network sub-transmission
assets.
1 | 2014 Distribution Annual Planning Report | December 2014
2.0
INTRODUCTION
This DAPR has been prepared to comply with National Electricity Rules (NER) clause 5.13.2.
With a five year forward planning horizon, the 2014/15 to 2018/19 DAPR is the second DAPR to be
published by Endeavour Energy. It reflects the outcomes of the annual planning review of the Endeavour
Energy network. The aim of the document is to inform network participants and stakeholder groups of
the proposed development of the Endeavour Energy network, including potential opportunities for nonnetwork solutions particularly for large investments where the AER Regulatory Investment Test for
Distribution (RIT-D) applies.
2.1
ABOUT ENDEAVOUR ENERGY
Endeavour Energy is a State Owned Corporation subject to a number of statutory and legislative
requirements corporation serving some of Australia’s largest and fastest growing regional economies.
Our Board has overall responsibility for corporate governance at Endeavour Energy.
Endeavour Energy manages a $5.31 billion electricity distribution network for 922,205 customers, or 2.2
million people, in households and businesses across a network area spanning 24,500 square kilometres
in Sydney’s Greater West, the Illawarra and South Coast, the Blue Mountains, the Southern Highlands
and Shoalhaven. Endeavour Energy is incorporated under the Energy Services Corporations Act 1995
and operates within the terms of the Electricity Supply Act 1995 on behalf of our shareholder, the New
South Wales Government. The focus of our 2,533 people is to deliver a safe, reliable and efficient
electricity supply to our residential and business customers while delivering strong financial results to our
shareholder. We are committed to making a serious and sincere effort to deliver better value for
customers by reducing our operating costs without compromising safety or services
2.1.1
OUR OBJECTIVES
In common with the other NSW electricity distribution companies, Endeavour Energy’s purpose
statement is described within the Networks NSW 2013/14 Group Strategic Plan as:
To be of service to our communities by efficiently distributing electricity
to our customers in a way that is safe, reliable and sustainable.
This statement communicates an internal focus on providing a safe, reliable and affordable electricity
supply to the communities we serve.
The Group Strategic Plan is supported in the achievement of this purpose by seven strategic plans that
outline the desired outcomes in the following key areas of business operations and the key short term
initiatives for Networks NSW that will deliver the desired outcomes in the long term.

Improve safety performance

Deliver the network plan

Improve customer value

Leverage technology

Manage business risk

Deliver performance through people

Achieve the financial plan
Endeavour Energy’s Network Strategy supports the overall Group Strategic Plan and plans that have
been developed to deliver these objectives with a particular focus on four priorities.

Ensuring the safety of employees, contractors and the public

Meeting customers’ reliability needs

Servicing growth in demand

Managing the network efficiently and sustainably
In particular, the Network Strategy describes how the priorities drive the short and long term planning of
network investment to achieve the overall objective of controlling increases in our share of customer bills
to no more than the rate of increase in the Consumer Price Index.
The strategy is effected through the plans and programs developed using Endeavour Energy’s network
planning and management framework. The framework is embedded in a range of internal procedures,
plans, standards and policy documents and managed by the Executive Network Asset Management
Committee (ENAMC) chaired by the General Manager Network Operations. Endorsement of the funding
required to implement agreed plans and programs is provided by the Endeavour Energy Investment
Governance Committee (IGC) followed by technical and financial endorsement by Networks NSW
investment governance committees prior to be submitted for approval.
Significant resources are devoted to ensuring timely, relevant and thorough data and information is
available to support decisions. For example, Endeavour Energy maintains detailed asset age, location
and condition data across the Geographic Information System, Field Inspection System, Asset
Management System and Outage Management System. Endeavour Energy also monitors the
relationship between planned service performance targets and service outcomes.
Endeavour Energy’s Network Planning process is highly consultative and transparent. Formal network
plans are developed annually through an extensive process culminating in the development of the
annual Strategic Asset Management Plan (SAMP) and Endeavour Energy’s Network Management Plan.
2.1.2
OUR VALUES
Endeavour Energy employees are required to understand and support the Company’s corporate values.
These five values and their associated behaviours are the basis for everything the Company does.
Safety Excellence





Put safety as your number one priority
Do not participate in unsafe acts, and challenge unsafe behaviours
Think before you act
Lead by example
Take responsibility for the health and safety of yourself and others
Respect For People



Treat all people with respect, dignity, fairness and equity
Demonstrate co-operation, trust and support in the workplace
Practise open, two-way communication
Customer and Community Focus



Deliver value and reliable service to our customers and communities
Use resources responsibly and efficiently
Be environmentally and socially responsible
Continuous Improvement



Look for safer and better ways to do your job
Improve our financial performance
Support innovation to add value to our business
Act With Integrity



2.1.3
Act honestly and ethically in everything you do
Be accountable and own your actions
Follow the rules and speak up
OUR PRINCIPAL ACTIVITIES
Endeavour Energy’s principal activities include:

The ownership and management of assets which make up the electricity distribution network

Infrastructure related construction and maintenance services

A range of other services including street lighting, customer connections, customer safety checkups and energy reviews and metering
2.1.4
OPERATING ENVIRONMENT
Endeavour Energy is regulated by statutory and legislative requirements including work health & safety
(WH&S), environmental, competition, industrial, consumer protection and information laws, the National
Electricity Rules, the NSW Electricity Supply Act 1995, the Energy Services Corporations Act, and a
NSW Distribution Network Service Provider licence. Endeavour Energy ensures compliance with these
laws and regulations through its internal codes and policies and a common control framework that
comprises plans, policies, procedures, delegations, instruction and training, audits of compliance, and
risk management.
In 2012 the NSW Government announced plans to reform the three NSW electricity network companies
– Endeavour Energy, Ausgrid and Essential Energy – to generate $400 million in efficiencies over four
years to fund its energy rebate scheme for low income households and families.
Endeavour Energy, Ausgrid and Essential Energy continue to operate as separate legal entities but are
managed by a joint Board of Directors and common Chief Executive Officer (CEO). The three network
companies operate under a shared Group management model known as Networks NSW. Each business
remains focused on the objectives of the State Owned Corporations Act, including:

Operating a safe, reliable and sustainable network

Operating at least as efficiently as any comparable privately owned business

Maximising the value of the company to the State

Balancing commercial, social, environmental and customer expectations
Networks NSW consists of a shared Group management structure. The Executive Leadership Group
(ELG) includes the CEO, Group Executive Managers, the Chief Operating Officer from each network
company and the Board Secretary. The CEO reports to the joint Board, which in turn is accountable to
the two voting shareholders, the NSW Treasurer and the NSW Minister for Finance, who each hold one
share in each of the three businesses for and on behalf of the NSW Government. The Portfolio Minister
of each of the network companies is the NSW Minister for Energy.
The joint Board is responsible for setting the overall strategic direction and performance targets, and
monitoring the implementation of the strategy by the three organisations. The CEO leads the ELG in
delivering the approved strategy and achieving the performance targets set by the joint Board.
Endeavour Energy is subject to the National Electricity Law (NEL) and National Electricity Rules (NER)
which regulate the National Electricity Market. As a NSW Statutory State Owned Corporation and NSW
Energy Services Corporation, Endeavour Energy is generally subject to the statutory and other legal
requirements applied to all businesses in NSW. Endeavour Energy operates in the National Electricity
Market (NEM) as a distribution network provider (DNSP). Endeavour Energy is also required to follow
government and regulatory direction. Locally the NSW Government Investment & Industry NSW
department mandates the network Reliability and Performance Licence Conditions. The Independent
Pricing and Regulatory Tribunal (IPART - Electricity) is responsible for administering licensing within the
energy industry and monitoring compliance with licence requirements. The Australian Energy Regulator
(AER) is the economic regulator of the distribution and transmission sectors of the national electricity
market under the National Electricity Laws and National Electricity Rules.
Endeavour Energy’s operations are guided by a number of important policies and codes, including a
Code of Conduct, Safety Policy, Environmental Code of Conduct and Policy and Statement of Business
Ethics.
2.1.5
ENDEAVOUR ENERGY STATISTICS
Presented in Table 1 is a summary of Endeavour Energy’s network and other statistics.
Distribution Customer Numbers (total)
Distribution Customer Numbers Northern Region
Distribution Customer Numbers Central Region
Distribution Customer Numbers Southern Region
Maximum Demand (aggregated system MW)
Feeder Numbers CBD
Feeder Numbers Urban
Feeder Numbers Short Rural
Feeder Numbers Long Rural
Energy Received by Distribution Network to Year End (GWh)
Energy Distributed to Year End (Residential) (GWh)
Energy Distributed to Year End (Non-Residential Including un-metered supplies) (GWh)
Energy Distributed to Year End (GWh)
System Loss Factor (%)
Transmission System (km)
Transmission Substation (Number)
Sub Transmission System (km)
Substation - Zone (Number)
Substation - Distribution (Number)
High Voltage Overhead (km)
High Voltage Underground (km)
Low Voltage Overhead (km)
Low Voltage Underground (km)
Number at end
of 2012/13
907,988
403,709
318,690
185,589
3,708
0
1,139
235
1
16,694
5,367
10,634
16,001
4.15
0
0
3,532
162
30,683
11,326
4,055
8,853
7,262
Number at end
of 2013/14
922,205
410,305
324,245
187,655
3,253
0
1,211
244
1
16,281
5,147
10,490
15,637
3.96
0
0
3,561
170
31,068
11,314
4,264
8,850
7,498
Table 1: Endeavour Energy statistics
2.2
ENDEAVOUR ENERGY NETWORK
Endeavour Energy’s network services more than 2.2 million people with a broad-ranging customer base
covering rural, urban, residential, industrial and commercial customers, including mining, manufacturing
and agricultural industries. Endeavour Energy operates one of the largest electricity networks in
Australia with more than 60 years’ experience in delivering a safe and reliable power supply.
In 2013/14, Endeavour Energy’s network supplied 16,281 GWh of electricity to 922,205 network
customers. It had 2,533 staff members over 19 locations across the franchise area. Endeavour Energy’s
distribution area, shown below, covers an area of 24,500 square kilometres and includes some of the
most densely populated and fastest growing areas of NSW. It also supplies customers in Sydney’s
Greater West, the Illawarra, as far north as the Kandos and as far south as Ulladulla, including the
Southern Highlands and the Blue Mountains.
Figure 1: Endeavour Energy’s network area
2.2.1
NUMBER AND TYPES OF DISTRIBUTION ASSETS
Most of Endeavour Energy’s supply of electricity is taken from the generation source through TransGrid’s
transmission network at 132kV and 66kV. Once the energy is transferred into the Endeavour Energy
network, the voltage is transformed through 22 sub-transmission and 162 zone substations and
distributed to customers through a 22kV/11kV/12.7kV High Voltage network. Distribution substations
further reduce the voltage to supply customers with a 230V nominal low voltage supply to comply with
Australian Standards.
Endeavour Energy’s distribution network includes:

A sub-transmission system of 33kV, 66kV and 132kV assets

A high voltage distribution system of 11kV, 22kV and SWER assets

A low voltage distribution system of 230V and 400V assets

Over 32,028 km of overhead lines and underground cables
The elements that make up the electricity network are highlighted in Figure 2 below. The Transmission
network is between the output of the Power Station and the Bulk Supply Point. The distribution network
generally commences at the output of the Bulk Supply Point and includes the entire network to the
connection point at the customer’s premises.
Figure 2: Network layout diagram
2.3
ANNUAL PLANNING REVIEW
The NER requires that the annual planning review includes the planning for all assets and activities
carried out by Endeavour Energy that would materially affect the performance of its network. This
includes planning activities associated with the replacement and refurbishment of assets and negotiated
services. The objective of the annual planning review is to identify possible future issues that could
negatively affect the performance of the distribution network to enable DNSPs to plan for and adequately
address such issues in an appropriate timeframe. The outcome of the annual planning review is the
Distribution Annual Planning Report (DAPR).
This DAPR provides an insight into the planning process as well as providing information to Registered
Participants and interested parties regarding the nature and location of emerging constraints within
Endeavour Energy’s sub-transmission and 22kV and 11kV distribution network. The timely identification
and publication of emerging network constraints provides an opportunity for the market to identify
potential non-network solutions to those constraints and allows Endeavour Energy to develop and
implement appropriate and timely solutions.
2.3.1
NETWORK PLANNING PROCESS
The network planning and development process for the distribution network is carried out in accordance
with the National Electricity Rules Chapter 5 Part B Network Planning and Expansion.
Endeavour Energy operates in accordance with the legislative and regulatory framework applicable to
electricity Distribution Network Service Providers (DNSPs) in NSW.
Each year, Endeavour Energy prepares and publishes a Network Management Plan (NMP) outlining the
approach to network safety and reliability, including the network planning framework and preparation of
the Strategic Asset Management Plan (SAMP). Endeavour Energy is committed to the principles of the
NSW Government’s Total Asset Management (TAM) System and believes that the Company’s asset
planning procedures are consistent with the TAM guidelines. The consistency of the Company’s asset
planning procedures to the TAM model is demonstrated in the NMP, and is shown diagrammatically
below.
Figure 3: Network planning process
Endeavour Energy carries out network planning at both a strategic and a project level and shares an
investment governance framework with the other NSW DNSPs as part of the group company Networks
NSW. Endeavour Energy’s investment governance process provides continuous review and ongoing
assurance that the Company’s capital investment is both prudent and efficient as well as being
consistent with the longer term strategic planning objectives.
Endeavour Energy’s planning process is designed to identify the most efficient ways of ensuring the
network business meets its network performance obligations. The Company places great emphasis on
the planning and project identification stage, assessing our customer’s short term and longer term supply
needs and then identifying and selecting the optimal solution, to meet those needs. All credible potential
options, including non-network and non-capital alternatives, are considered in determining how best to
meet our network performance obligations and the objectives of the National Electricity Law. There is a
robust selection process that explicitly trades off alternative expenditure options using quantified
estimates of credible option costs and benefits to identify the optimum solution to address network
constraints.
In accordance with NER obligations, network augmentation and non-network (demand management)
options are assessed impartially, using a consistent process for reviewing cost effectiveness. Demand
management options are evaluated for the extent to which they can enable a network augmentation
need to be avoided or deferred. This allows various combinations of demand management and deferred
augmentation options to be assessed.
It is noted that the Director General of Industry and Investments NSW has withdrawn the NSW Demand
Management Code of Practice. The requirement to consider demand management and non-network
option solutions when considering how to address identified network needs are now included in the NER,
Chapter 5 Part B, Network Planning and Expansion.
The first stage of the planning process involves gathering data required to inform the investment
process. This includes: recorded actual electricity demand; the preparation of demand forecasts; the
examination of network capacity limits; the assessment of asset condition; the forecast of new customer
connection requirements and the consideration of applicable statutory and regulatory obligations.
The forecast adequacy of the network is assessed against key criteria which include:

Meeting statutory and regulatory requirements relating to the safe operation of the network and to
environmental impact

Addressing capacity constraints to achieve a level of supply security commensurate with
reasonable customer expectations

Reliability performance against the reliability performance standards set out in the Licence
Conditions

Asset condition

Customer connection requirements
When emerging network limitations are identified, a range of feasible options are developed to address
the network need and to ensure supply security levels that maintain a reliable and sustainable supply.
Options considered include both network and non-network solutions. A review including public
consultation with interested stakeholders then selects the most economic option (or options). Each
major investment is required to be consistent with Endeavour Energy’s longer term network plans and
network standards and the National Electricity Objective.
This document forms part of the public consultation and provides notification of the network limitations. It
also indicates the required timeframe to resolve the limitations to allow for appropriate corrective network
augmentation or non-network alternatives or modifications to connection facilities to be developed and
undertaken.
Endeavour Energy’s network planning approach is outlined in the Network Management Plan and is
consistent with the principles of the NSW Government’s Total Asset Management system. Endeavour
Energy is required to comply with service standards in the Reliability and Performance licence conditions
imposed by the NSW Minister for Energy. The supply security standards set out in Schedule 1 of the
Licence Conditions have been repealed by the Minister for Energy and the changes will take effect on 1
July 2014. Reliability Standards in Schedules 2 and 3 of the Licence Conditions remain in place, as well
as a corporate objective to maintain existing levels of reliability performance. As such, for future network
investment, the level of supply security provided will be subject to the outcomes of a reliability risk and
cost benefit analysis specific to that situation, rather than compliance to mandated minimum supply
security levels.
Capital investment requirements in the distribution network are forecast in line with network needs and
constraints across the network area.
The spatial demand forecast is a critical process which supports the planning and, development of the
capital program. The forecasting process is carried out twice a year and is a critical input into the
planning process to identify and understand the limitations on the network. The summer and winter
loading conditions are analysed as understanding the seasonal variations as these are important in
identifying optimal solutions.
2.4
SIGNIFICANT CHANGES FROM PREVIOUS DAPR
There are no significant changes to the DAPR report.
2.4.1
ANALYSIS AND EXPLANATION OF FORECAST CHANGES
Future DAPRs will discuss any significant changes which have occurred to forecasts contained in this
DAPR.
2.4.2
ANALYSIS AND EXPLANATION OF CHANGES IN PLANNING PROCESS
Future DAPRs will discuss as required any:

Significant changes to proposed solutions (network or non-network) to address system
limitations, project timing, deferral, and cancellation

Significant changes (including timing, deferral and cancellation) to proposed replacement projects
>$5m

Significant changes (including timing, deferral and cancellation) to proposed RIT-Ds
3.0
FORECASTS FOR THE FORWARD PLANNING PERIOD
This section summarises the peak demand conditions experienced during the previous summer and
winter, and provides a detailed breakdown of the peak demand forecast by season for the 2014 – 2018
period. The peak demand forecasts provide Endeavour Energy with the basis for identifying network
limitations and commencing the RIT-D process of identifying and evaluating the credible network and
non-network options to address those limitations. It also feeds into the strategic asset management plan
(SAMP) which documents the capital and operating investment expected to be required for the next
rolling ten year periods.
Endeavour Energy’s Network System demand for the 2013/14 summer peaked at 3,253 megawatts
(MW) at 3:45 pm on Friday 20 December 2013. The maximum temperature at Richmond was recorded
at 39.1ºC.
The peak demand for 2014 summer was a reduction of 454 MW compared to that of 3,708 MW
measured for the previous summer of 2013 with the record breaking maximum temperature of 46.0ºC at
Richmond. This reduction of peak demand in 2014 was largely attributed to decreased usage of air
conditioning loads for the relatively mild 2014 summer.
Figure 4 shows the time series of the daily maximum temperatures at Richmond and the peak demands
on the EE network and NSW during the 2014 summer peak demand period. EE peak demand and
maximum NSW daily peak demand for the 2014 summer occurred on the same day of 20 December
2013.
50
11.9GW
14
12
45
40
10
6
30
4
25
EE
29 Dec
28 Dec
27 Dec
26 Dec
25 Dec
24 Dec
23 Dec
22 Dec
21 Dec
19 Dec
18 Dec
17 Dec
16 Dec
15 Dec
14 Dec
13 Dec
12 Dec
15
11 Dec
0
10 Dec
20
9 Dec
2
NSW
Richmond Max Temperature (°C)
35
3.2GW
8
20 Dec
Peak Demand (GW)
39.1°C
Temperature
Figure 4: Endeavour Energy and NSW peak demand and temperature – 13/14 summer
In general, the EE and NSW peak demands in summer follow the variations of daily maximum
temperature. However, the day of hottest temperature does not always result in maximum demand.
While temperature has a highly significant influence on the peak demand, a number of other factors can
make an impact including: day of the week (weekend/weekday), time of day, public and school holidays,
wind (speed, direction and timing), persistent hot or cold spells, user behaviours and economic
conditions.
3.1
FORECASTING METHODOLOGY
Peak demand forecasts are made for the summer and winter season. Summer is defined as the five
month period between November and March while winter consists of the four month period from May to
August. The forecast method is based on a bottom-up approach and provides maximum MVA, MW and
MVAr loads and the Power Factor expected for the summer and winter peak periods.
The forecasts are prepared for each zone substation and major customer substation, for each
transmission substation, for TransGrid’s Bulk Supply Points (BSPs) that supply Endeavour Energy’s
network and for the Endeavour Energy network as a whole.
The forecasts consider planned load transfers, expected spot loads, land releases and re-development
in the area under consideration. Loads supplied by generation embedded in the network are
incorporated into the calculation of the maximum demand forecasts.
Peak demand forecast accounts for the total growth from the existing customers as well as the new
customers. The forecasting process can be divided into two major steps. The first step is to estimate the
organic growth at the zone substation which specifies the internal growth from its existing customers
likely to be experienced over the forecast period. For summer, it is calculated by the known current and
projected penetration rates of air conditioners and the percentage of residential peak load at the zone
substation. This organic growth at the zone substation is used to establish the base level of the 10-year
forecast. For winter, the organic growth at zone substations is assumed to be flat with zero growth.
Historical (past actual) and forecast peak demands are corrected to reference temperatures to provide
Temperature Corrected Maximum Demand (TCMD) values. TCMD is an estimate of the peak demand
that is expected under the reference conditions. TCMD values are given with a 10% and 50%
Probability of Exceedance (PoE) to reflect the probability that the forecast values will be exceeded due to
higher or lower than reference temperatures and other factors.
The forecasts for transmission substations, bulk supply points and for the Endeavour Energy network as
a whole aggregate the constituent maximum demand figures to provide an undiversified total maximum
demand figure. Diversified values of maximum demand are calculated from the undiversified values by
application of a diversification factor derived from historical data. Historical values of actual diversified
demand are provided where suitable metering is available.
For Endeavour Energy’s forecasting purposes, the most important days are those with the highest
demand. The summer demand is most likely to peak on weekdays correlating with maximum
temperatures, while in winter demand generally peaks on weekdays at 6pm. The temperature at 6pm is
used for the winter reference temperature.
3.1.1
FORECAST INPUT INFORMATION SOURCES
Demand and temperature data is sourced from Endeavour Energy’s Network Load History (NLH)
database. Data from the SCADA system is used as a substitute where gaps existed in the metering data
available from NLH. Where neither metering nor SCADA data is available, current flow is read from the
current transformers on individual circuit breakers.
3.1.2
ASSUMPTIONS APPLIED TO FORECASTS
The following Probability of Exceedence (PoE) parameters are adopted:

1 in 10 year event (corresponds to 10% PoE)

1 in 2 year event (corresponds to 50% PoE)
A 10% PoE figure is estimated to be exceeded only once in every ten seasons on average whilst a 50%
PoE figure is likely to be exceeded once every two years on average.
3.2
DEMAND FORECASTS
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 and, these are marked as limited to N. Generally these
have maximum demands of less than 10MVA.
The substation total capacity is the maximum load able to be carried by the substation with all elements
in service.
The secure capacity of a substation is the capacity with one major element (such as a power
transformer) out of service. This is often referred to as its “Firm” or N-1 rating. Transmission substations
are considered to be constrained when the load exceeds the secure capacity. Suburban zone
substations are considered to be constrained when the demand exceeds the secure capacity by more
than 1% of the year annually (88 hrs) or when the load is greater than 120% of the secure capacity. The
exception are substations whose rating is limited by underground feeders or where exceeding secure
capacity will result in the thermal rating of apparatus being exceeded in its normal configuration. In these
situations, the load may not exceed the secure capacity of the substation.
The voltage levels of Endeavour Energy’s sub-transmission substations (termed “Transmission
substations”) are nominally 132kV on the primary and either 66kV or 33kV on the secondary.
The voltage levels of our Endeavour Energy’s zone substations are nominally 132kV, 66kV or 33kV on
the primary and 11kV, 22kV on the secondary.
The forecast is prepared as soon as possible after the end of each peak season.
The zone substation rating changes have only been included where the associated project which is
influencing the rating has been given approval and are committed at the date of preparation of the
forecast.
The forecast power factor readings correspond to the power factor at time of peak load. A dash in this
field indicates that the particular transformer was either not commissioned at the time of measurement or
is normally unloaded.
Forecast demands for the sub-transmission feeder network are based on its ‘N’ rating, summer or winter,
and the ‘N-1’ loading, that is, the worst condition load that would appear on the feeder with an adjacent
feeder out of service compared to the thermal rating of the smallest conductor or cable on that feeder.
The ‘95% Peak Load Exceeded (hours)’ figure in the Transformer Rating and Substation Details table
represents the number of hours the load is above the 95% level of actual peak demand. It is an
indication of how peaky the load profile is which is important for designing an effective non-network
option.
The ‘Actual (MVA)’ figure that appears in the summer and winter demand forecast tables is not
temperature corrected. It is the actual recorded load. The forecast loads are based on temperature
corrected actuals.
The ‘Embedded Generation’ figure that appears in the Transformer Rating and Substation Details table
in each forecast area provides the estimated aggregate level of embedded generation connection to the
network supplied from that substation. It includes residential and commercial PV and customer
generation. Customer details are not provided due to privacy reasons.
The summer 2014 period means the 2013/14 summer.
The Transmission-distribution connection points are called Bulk Supply Pont (BSP) and are owned by
TransGrid, the NSW transmission company.
Endeavour Energy does not currently produce or report on sub-transmission feeder forecasts.
Endeavour Energy evaluates the capability of its sub-transmission network on the basis of load flows
modelling different contingencies and network operating configurations. The sub-transmission forecast
tables in this document are desktop estimates derived from zone substation loading data and are based
on an assumed operating configuration based on the present day network. The loads presented are
indicative of the load on the stated feeder in the event of the most likely contingency. Hence, the subtransmission forecast tables should therefore be treated as indicative loading data in the event of a
probable contingency event.
Actual sub-transmission feeder constraints are identified from detailed load flow studies modelling
several different contingency events and operating configurations. At the time of publication of this
document it has not been possible to outline the load flow results in a meaningful way in the format
required of the Distribution Annual Planning Report.
3.2.1
BAULKHAM HILLS TRANSMISSION SUBSTATION
3.2.1.1
BAULKHAM HILLS TS CONNECTION POINTS
Baulkham Hills TS is supplied by Sydney West BSP via Blacktown TS on feeders 9J3 and 9J4. This
system has a firm rating for one circuit outage of 512 / 618MVA summer / winter based on the line
ratings. The 2400A switchgear at Baulkham Hills TS limits the winter rating to 548 MVA. The Baulkham
Hills 132kV busbar supplies the Baulkham Hills 132/11kV supply point and Carlingford TS. Baulkham
Hills TS has four 60 MVA 132/33kV transformers, providing a firm capacity of 180MVA.
Substation
Jasper Rd ZS
North Rocks ZS
Northmead ZS
Seven Hills ZS
Westmead ZS
Baulkham Hills TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
3 x 25
2 x 25
2 x 15 + 1 x 25
3 x 25
2 x 25
4 x 60
Installed
Capacity
Total ‘N’
(MVA)
75
50
55
75
50
240
Firm Rating
Secure ‘N-1’
(MVA)
50
25
30
50
25
180
95% Peak
Load
Exceeded
(hours)
107.00
4.00
2.75
5.50
25.25
12.00
Embedded
Generation
(MW)
2.50
1.15
0.98
0.84
2.18
-
Table 2: Baulkham Hills TS – transformer rating and substation details
Substation Name
Jasper Road ZS
North Rocks ZS
Northmead ZS
Seven Hills ZS
Westmead ZS
Baulkham Hills TS
Forecast
PF
0.960
0.993
0.987
0.984
0.994
0.995
Actual (MVA)
2013
2014
0.960
36.5
0.993
19.4
0.987
23.5
0.984
31.3
0.994
23.7
0.995
141.8
2015
31.1
17.3
21.1
27.1
22.4
112.1
2016
32.7
18.4
23.8
27.4
22.8
110.7
Forecast (MVA)
2017
32.8
18.4
24.5
27.4
23.2
111.8
2018
32.9
18.5
25.0
27.4
23.3
112.5
2019
32.9
18.5
25.4
27.4
23.4
112.9
2014
26.3
15.6
19.3
28.2
21.0
118.1
2015
26.7
15.6
20.8
28.2
21.2
120.4
Forecast (MVA)
2016
26.7
15.6
21.2
28.2
21.3
120.9
2017
26.7
15.6
21.6
28.2
21.3
121.3
2018
26.7
15.6
21.8
28.2
21.3
121.6
Table 3: Baulkham Hills TS – summer demand forecast
Substation Name
Jasper Road ZS
North Rocks ZS
Northmead ZS
Seven Hills ZS
Westmead ZS
Baulkham Hills TS
Forecast
PF
0.986
0.999
0.993
0.993
0.989
0.987
Actual (MVA)
2012
2013
28.5
25.4
16.1
14.8
21.2
17.5
27.7
28.2
17.9
18.6
152.1
115.3
Table 4: Baulkham Hills TS – winter demand forecast
3.2.1.2
BAULKHAM HILLS TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Baulkham Hills TS is at 33kV.
Baulkham Hills TS is supplied by Sydney West Bulk Supply Point via 132kV feeders 9J3 and 9J4, Refer
Sydney West BSP.
Capacity
(MVA)
Feeder Name
470 Seven Hills – Marayong
473 TS – Tee
473 Tee – Kellyville
473 Tee – Marayong
469 TS – Jasper Rd
472 TS – North Rocks
480 TS – Tee
480A Northmead – North Rocks
480B Northmead – North Rocks
478 TS – Northmead
466 Northmead – Westmead
477 TS – Westmead
475 TS – Seven Hills
479 TS – Seven Hills
474 TS – Holroyd
34.0
32.0
21.0
21.0
21.0
36.2
42.0
42.0
42.0
42.0
42.0
42.0
46.0
46.0
44.0
46.0
46.0
Actual
(MVA)
2014
20.0
17.9
9.7
17.9
9.2
31.1
31.1
17.3
33.3
17.3
32.4
32.4
22.4
22.4
27.1
27.1
29.2
Forecast (MVA)
2015
20.2
18.0
10.7
18.0
10.1
32.7
32.7
18.4
35.6
18.4
35.2
35.2
22.8
22.8
27.4
27.4
31.1
2016
20.2
18.0
10.7
18.0
10.2
32.8
32.8
18.4
36.1
18.4
36.1
36.1
23.2
23.2
27.4
27.4
31.2
2017
20.2
18.0
10.8
18.0
10.2
32.9
32.9
18.5
36.5
18.5
36.7
36.7
23.3
23.3
27.4
27.4
31.3
2018
20.2
18.0
10.8
18.0
10.2
32.9
32.9
18.5
36.8
18.5
37.1
37.1
23.4
23.4
27.4
27.4
31.4
2019
20.2
18.0
10.8
18.0
10.2
32.9
32.9
18.5
36.9
18.5
37.3
37.3
23.5
23.5
27.4
27.4
31.5
Table 5: Baulkham Hills TS – summer
Network Constraint
Nil
Year
Investigation
Table 6: Baulkham Hills TS – identified limitations
Solution
3.2.1.3
BAULKHAM HILLS TS NETWORK MAP
3.2.2
BELLAMBI TRANSMISSION SUBSTATION
3.2.2.1
BELLAMBI TS CONNECTION POINTS
Bellambi Transmission Substation has three 60MVA 132/33kV transformers providing a firm capacity of
120 MVA. Bellambi Transmission Substation is supplied from TransGrid’s Dapto BSP via two 132kV
feeders 980 & 981, which each have a rating of 163 / 176MVA summer / winter.
Substation
Bulli ZS
Corrimal ZS
Darkes Forest ZS
Helensburgh ZS
Mt Ousley ZS
Russell Vale ZS
Wombarra ZS
Bellambi TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 10
2 x 19
2x5
2 x 12.5
2 x 35
2 x 10 + 1 x 25
2x5
3 x 60
Installed
Capacity
Total ‘N’
(MVA)
20
38
10
25
70
45
10
180
Firm Rating
Secure ‘N-1’
(MVA)
10
19
5
12.5
35
20
5
120
95% Peak
Load
Exceeded
(hours)
2.75
2.00
1.75
10.00
7.50
3.00
4.00
2.50
Embedded
Generation
(MW)
1.37
1.55
0.00
0.60
1.02
1.42
0.66
-
Table 7: Bellambi TS – transformer rating and substation details
Substation Name
Bulli ZS
Corrimal ZS
Darkes Forest ZS
Helensburgh ZS
Mount Ousley ZS
Russell Vale ZS
Wombarra ZS
Bellambi TS
Forecast
PF
0.960
0.998
0.874
0.998
0.970
0.962
0.967
0.997
Actual (MVA)
2013
2014
10.6
8.3
17.8
14.6
1.0
0.8
11.4
9.3
18.8
16.8
16.2
11.2
4.4
4.5
75.8
63.5
2015
8.3
14.6
0.9
7.3
16.6
11.6
4.6
77.0
2016
8.4
14.9
0.9
7.3
17.2
12.3
4.9
78.9
Forecast (MVA)
2017
8.6
15.1
0.9
7.3
17.3
12.3
4.9
79.3
2018
8.7
15.4
0.9
7.3
17.5
12.3
4.9
79.9
2019
8.9
15.7
0.9
7.3
17.7
12.3
4.9
80.4
2014
10.5
16.9
0.9
10.1
17.9
15.1
5.7
85.2
2015
10.5
17.2
0.9
10.1
18.5
15.6
5.7
86.5
Forecast (MVA)
2016
10.5
17.2
0.9
10.1
18.5
15.6
5.7
86.5
2017
10.5
17.2
0.9
10.1
18.5
15.6
5.7
86.5
2018
10.5
17.2
0.9
10.1
18.5
15.6
5.7
86.5
Table 8: Bellambi TS – summer demand forecast
Substation Name
Bulli ZS
Corrimal ZS
Darkes Forest ZS
Helensburgh ZS
Mount Ousley ZS
Russell Vale ZS
Wombarra ZS
Bellambi TS
Forecast
PF
0.990
0.998
0.941
0.998
0.900
0.982
0.980
0.991
Actual (MVA)
2012
2013
10.8
10.5
16.1
16.9
1.6
0.9
14.2
12.1
19.0
17.2
12.7
15.0
6.5
5.4
80.7
85.4
Table 9: Bellambi TS – winter demand forecast
3.2.2.2
BELLAMBI TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Bellambi TS is at 33kV.
Capacity
(MVA)
Feeder Name
7028 TS – Helensburgh
7253 Helensburgh – Darkes Forest
7252 Darkes Forest – Tee
7022 TS – Darkes Forest
7025 TS – Wombarra
7026 TS – Bulli
7027 TS – Russel Vale
7293 Bulli – Russel Vale
7029 TS – South Bulli SS
7291 South Bulli SS – Russel Vale
7292 Russel Vale – Corrimal
7030 TS – Corrimal
7112 North Wollongong – Corrimal
7121 North Wollongong – Mt Ousley
7021 TS – Mt Ousley
44.4
21.2
21.7
44.2
44.2
19.7
32.0
13.4
32.1
32.0
32.0
55.7
47.7
35.4
35.4
Actual
(MVA)
2014
4.6
4.6
4.6
8.3
8.0
7.7
11.8
8.3
13.9
9.0
14.6
14.6
0.0
0.0
16.8
Forecast (MVA)
2015
3.7
3.7
3.7
7.3
7.0
10.8
16.7
8.3
17.1
9.3
14.6
14.6
5.5
5.5
16.6
2016
3.7
3.7
3.7
7.5
7.2
11.1
17.2
8.4
17.6
9.9
14.9
14.9
5.5
5.5
17.2
2017
3.7
3.7
3.7
7.5
7.2
11.2
17.3
8.6
17.7
9.9
15.1
15.1
5.5
5.5
17.3
2018
3.7
3.7
3.7
7.5
7.2
11.2
17.3
8.7
17.9
9.9
15.4
15.4
5.5
5.5
17.5
2019
3.7
3.7
3.7
7.5
7.2
11.3
17.4
8.9
18.1
9.9
15.7
15.7
5.5
5.5
17.7
Table 10: Bellambi TS – summer
Network Constraint
Nil
Year
Investigation
Table 11: Bellambi TS – identified limitations
Solution
3.2.2.3
BELLAMBI TS NETWORK MAP
3.2.3
BLACKTOWN TRANSMISSION SUBSTATION
3.2.3.1
BLACKTOWN TS CONNECTION POINTS
Blacktown TS has four 120 MVA 132/33kV transformers providing a firm capacity of 360MVA and is
supplied from Sydney West BSP via two dual circuit steel towers lines forming 132kV feeders 93Z/93A
and 9J1/9J2. The current temperature corrected demand on the Blacktown 33kV busbar is 256MVA but
dropping to 220MVA in 2014/15 then rising to 226MVA by the end of the forecast period. This significant
reduction in demand in 2014/15 is due to the transfer of Doonside ZS to the Sydney West 132kV
network and Bossley Park ZS to the West Wetherill Park network.
Substation
Voltage
Levels
Bossley Park ZS
Doonside ZS
Greystanes ZS
Holroyd ZS
33/11kV
33/11kV
33/11kV
33/11kV
Leabons Lane ZS
Marayong ZS
Newton ZS
Prospect ZS
Prospect East ZS
Prospect South ZS
Quarries ZS
Blacktown TS
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
Transformer
Description
(MVA)
2 x 35
2 x 15 + 1 x 20
2 x 25
1 x 17.25 + 2 x
25
2 x 25
3 x 25
3 x 25
3 x 15
2 x 25
2 x 25
2 x 35
4 x 120
Installed
Capacity
Total ‘N’
(MVA)
70
50
50
67.25
50
75
75
45
50
50
70
480
Embedded
Generation
(MW)
35
30
25
42.25
95% Peak
Load
Exceeded
(hours)
2.75
5.75
6.50
6.25
25
50
50
30
25
25
35
360
9.50
5.00
11.75
3.00
5.00
75.50
6.50
3.75
1.59
1.49
0.78
1.81
0.67
-
Firm Rating
Secure ‘N-1’
(MVA)
2.22
5.75
1.52
1.73
Table 12: Blacktown TS – transformer rating and substation details
Substation Name
Bossley Park ZS
Doonside ZS
Greystanes ZS
Holroyd ZS
Leabons Lane ZS
Marayong ZS
Newton ZS
Prospect ZS
Prospect East ZS
Prospect South ZS
Quarries ZS
Blacktown TS
Forecast
PF
0.997
0.939
0.989
0.984
0.950
0.991
0.932
0.908
0.948
0.982
Actual (MVA)
2013
2014
30.0
28.8
28.2
22.7
23.1
20.0
33.2
29.2
20.1
19.4
38.1
38.0
36.4
32.7
30.0
25.3
10.4
10.8
2.3
3.1
18.9
21.3
269.4
244.0
2015
21.1
31.1
21.5
38.3
33.6
26.9
10.8
3.0
24.6
219.8
2016
21.2
31.2
21.5
38.3
34.9
26.9
10.8
3.0
26.4
222.9
Forecast (MVA)
2017
21.3
31.3
21.5
38.3
36.2
26.9
10.8
3.0
27.2
224.9
2018
21.3
31.4
21.5
38.3
36.6
26.9
10.8
3.0
27.2
225.5
2019
21.4
31.5
21.5
38.3
36.6
26.9
10.8
3.0
27.3
225.7
2014
15.9
23.9
13.3
35.9
24.6
22.4
9.3
2.2
16.6
160.3
2015
15.9
23.9
13.3
35.9
26.2
22.4
9.3
2.2
19.0
163.7
Forecast (MVA)
2016
15.9
23.9
13.3
35.9
27.2
22.4
9.3
2.2
13.0
164.2
2017
15.9
23.9
13.3
35.9
27.5
22.4
9.3
2.2
13.0
164.5
2018
15.9
23.9
13.3
35.9
27.5
22.4
9.3
2.2
13.0
164.5
Table 13: Blacktown TS – summer demand forecast
Substation Name
Bossley Park ZS
Doonside ZS
Greystanes ZS
Holroyd ZS
Leabons Lane ZS
Marayong ZS
Newton ZS
Prospect ZS
Prospect East ZS
Prospect South ZS
Quarries ZS
Blacktown TS
Forecast
PF
0.997
0.971
0.995
0.996
0.950
0.985
0.934
0.914
0.968
0.994
Actual (MVA)
2012
2013
20.0
17.6
20.0
20.6
16.9
16.0
31.9
22.9
16.5
13.4
35.9
35.8
24.4
25.7
21.5
22.0
9.4
9.3
2.2
2.1
11.1
13.4
186.3
191.2
Table 14: Blacktown TS – winter demand forecast
3.2.3.2
BLACKTOWN TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Blacktown TS is at 33kV.
Capacity
(MVA)
Feeder Name
428 TS – Prospect
433 TS – Prospect
463 TS – Prospect
432 TS – Holroyd
426 TS – Greystanes
430 Blacktown TS – Tee
435 TS – Bossley Park
434 TS – Quarries
440 TS – Tee
440 Tee – Quarries
440 Tee – East Prospect
431 East Prospect – South Prospect
427 TS – South Prospect
455 TS – Doonside
450 TS – Tee
450 Tee – Newton
450 Tee – Doonside Tee
450 Doonside Tee – Doonside ZS
450 Doonside Tee – Quakers Hill ZS
481 Newton – Leabons Lane
467 OB – Leabons Lane
429 TS – Leabons Lane
445 TS – Marayong
17.0
17.0
17.0
42.0
42.0
42.0
42.0
42.0
42.0
42.0
42.0
30.0
50.0
27.0
42.0
42.0
42.0
42.0
42.0
50.0
42.0
42.0
45.0
Actual
(MVA)
2014
12.7
12.7
12.7
29.2
20.0
20.0
28.8
16.4
22.2
10.7
7.5
4.4
7.5
22.7
34.6
21.6
41.4
22.7
35.4
49.0
32.7
32.7
38.0
Forecast (MVA)
2015
13.5
13.5
13.5
31.1
21.1
21.1
32.0
26.9
36.4
12.3
22.6
19.6
22.6
27.0
37.9
29.4
46.4
27.0
38.1
53.3
34.5
34.5
38.3
2016
13.5
13.5
13.5
31.2
21.2
21.2
30.0
28.0
37.8
13.2
22.6
19.6
22.6
27.1
38.7
29.7
46.9
27.1
38.9
54.5
35.4
35.4
38.3
2017
13.5
13.5
13.5
31.3
21.3
21.3
30.1
28.4
38.4
13.6
22.6
19.6
22.6
27.1
39.5
29.7
47.0
27.1
39.0
55.2
36.2
36.2
38.3
2018
13.5
13.5
13.5
31.4
21.3
21.3
30.2
28.4
38.4
13.6
22.6
19.6
22.6
27.1
39.8
29.7
47.0
27.1
39.0
55.4
36.4
36.4
38.3
2019
13.5
13.5
13.5
31.5
21.4
21.4
30.2
28.4
38.4
13.6
22.6
19.6
22.6
27.1
39.8
29.7
47.0
27.1
39.0
55.4
36.4
36.4
38.3
Table 15: Blacktown TS – summer
Network Constraint
Nil
Year
Investigation
Table 16: Blacktown TS – identified limitations
Solution
3.2.3.3
BLACKTOWN TS NETWORK MAP
3.2.4
CAMELLIA TRANSMISSION SUBSTATION
3.2.4.1
CAMELLIA TS CONNECTION POINTS
Camellia Transmission Substation is supplied at 132kV from the new Holroyd Bulk Supply Point via
Endeavour Energy’s Guildford Transmission Substation. Camellia TS now has a recently commissioned
132kV busbar which has removed the tail-ended operation of the 3 x 120 MVA 132/33kV transformers.
Each transformer and feeder is now controlled by a local circuit breaker which provides greater
operational flexibility of the Camellia 132kV busbar for the West Parramatta Zone Substation and East
Parramatta Switching Station.
Substation
Granville ZS
Lennox ZS
Parramatta ZS
Rosehill ZS
Camellia TS
Voltage
Levels
33/11kV
33/11kV
33/11kV
33/11kV
132/33 kV
Transformer
Description
(MVA)
1 x 16.5 + 1 x
20
3 x 25
3 x 25
2 x 25
3 x 120
Installed
Capacity
Total ‘N’
(MVA)
36.5
Embedded
Generation
(MW)
16.5
95% Peak
Load
Exceeded
(hours)
3.25
50
50
25
240
2.50
19.50
3.50
17.50
0.19
0.00
2.65
18.55
Firm Rating
Secure ‘N-1’
(MVA)
75
75
50
360
0.79
Table 17: Camellia TS – transformer rating and substation details
Substation Name
Granville ZS
Lennox ZS
Parramatta ZS
Rosehill ZS
Camellia TS
Forecast
PF
0.958
0.967
0.938
Actual (MVA)
2013
2014
31.8
31.8
36.9
26.6
28.9
122.3
95.5
2015
21.4
25.9
49.4
2016
24.0
25.9
51.8
Forecast (MVA)
2017
24.0
25.9
51.8
2018
24.0
25.9
51.8
2019
24.0
25.9
51.8
2014
16.9
19.4
51.4
2015
16.9
19.4
51.4
Forecast (MVA)
2016
16.9
19.4
51.4
2017
16.9
19.4
51.4
2018
16.9
19.4
51.4
Table 18: Camellia TS – summer demand forecast
Substation Name
Granville ZS
Lennox ZS
Parramatta ZS
Rosehill ZS
Camellia TS
Forecast
PF
0.996
0.976
0.959
Actual (MVA)
2012
2013
16.8
26.8
24.2
28.6
27.3
21.2
20.4
167.0
80.3
Table 19: Camellia TS – winter demand forecast
3.2.4.2
CAMELLIA TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Camellia TS is at 33kV.
Capacity
(MVA)
Feeder Name
403 TS – HVC
404 TS – HVC
405 TS – HVC
409 TS – HVC
410 TS – HVC
411 TS – Rosehill
413 TS – Rosehill
417 TS – Lennox
418 TS – Lennox
421 TS – Parramatta
50.0
50.0
36.0
17.0
17.0
50.0
50.0
50.0
43.0
27.0
27.0
26.0
Actual
(MVA)
2014
8.5
8.5
7.9
1.3
1.3
28.9
28.9
31.8
31.8
21.1
21.1
21.1
Forecast (MVA)
2015
2.1
2.1
1.9
1.3
1.3
25.9
25.9
21.4
21.4
22.4
22.4
22.4
2016
2.1
2.1
1.9
1.3
1.3
25.9
25.9
24.0
24.0
22.4
22.4
22.4
2017
2.1
2.1
1.9
1.3
1.3
25.9
25.9
24.0
24.0
22.4
22.4
22.4
2018
2.1
2.1
1.9
1.3
1.3
25.9
25.9
24.0
24.0
22.4
22.4
22.4
2019
2.1
2.1
1.9
1.3
1.3
25.9
25.9
24.0
24.0
22.4
22.4
22.4
Table 20: Camellia TS – summer
Network Constraint
Nil
Year
Investigation
Table 21: Camellia TS – identified limitations
Solution
3.2.4.3
CAMELLIA TS NETWORK MAP
3.2.5
CARLINGFORD TRANSMISSION SUBSTATION
3.2.5.1
CARLINGFORD TS CONNECTION POINTS
Carlingford Transmission Substation has three 120 MVA 132/66kV double-wound transformers and one
120 MVA 132/66kV auto transformer. The auto transformer was the former system spare and was
installed at Carlingford following the failure of one of the original units. This unit has a relatively lower
impedance than the other units such that they do not share load equally when operated in the usual
manner of three on and one on auto standby. This formerly created a capacity constraint whenever the
unit was in service, but this is no longer the case based on the reduced demand at Carlingford. This
inherent constraint will need to be considered as part of the renewal strategy for the remaining
transformers, all of which are nearing the end of their expected service life.
Substation
Castle Hill ZS
Dundas ZS
Rydalmere ZS
West Pennant Hills ZS
Carlingford TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
66/11kV
66/11kV
132/66kV
3 x 25
3 x 35
2 x 33 + 1 x 25
2 x 35
4 x 120
Installed
Capacity
Total ‘N’
(MVA)
75
105
91
70
480
Firm Rating
Secure ‘N-1’
(MVA)
50
52.5
58
35
360
95% Peak
Load
Exceeded
(hours)
6.50
7.25
10.25
9.25
2.25
Embedded
Generation
(MW)
0.39
2.82
0.94
1.73
-
Table 22: Carlingford TS – transformer rating and substation details
Substation Name
Carlingford (Ausgrid)
Castle Hill ZS
Dundas ZS
Rydalmere ZS
Carlingford TS
Forecast
PF
0.886
0.968
0.983
0.983
0.975
0.980
Actual (MVA)
2013
2014
109.6
99.1
21.6
20.1
41.1
36.6
38.5
34.2
25.4
22.9
220.5
195.8
2015
119.7
20.4
36.7
37.0
32.5
230.3
2016
119.1
20.5
38.2
37.0
32.6
231.4
Forecast (MVA)
2017
121.9
20.5
39.4
37.1
35.8
238.3
2018
125.2
20.5
40.2
37.1
24.6
231.1
2019
128.1
20.5
40.7
37.2
24.6
234.2
2014
96.8
13.3
36.4
29.5
19.7
173.9
2015
94.0
13.3
37.8
30.3
27.3
180.7
Forecast (MVA)
2016
94.8
13.3
38.9
30.3
29.8
184.8
2017
95.6
13.3
39.8
30.3
21.0
178.1
2018
96.6
13.3
40.4
30.3
21.0
179.5
Table 23: Carlingford TS – summer demand forecast
Substation Name
Carlingford (Ausgrid)
Castle Hill ZS
Dundas ZS
Rydalmere ZS
Carlingford TS
Forecast
PF
0.878
0.982
0.988
0.976
0.976
0.968
Actual (MVA)
2012
2013
97.0
103.9
20.0
13.8
42.4
32.9
29.3
29.6
18.9
17.3
186.3
187.4
Table 24: Carlingford TS – winter demand forecast
3.2.5.2
CARLINGFORD TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Carlingford TS is at 66kV.
Capacity
(MVA)
Feeder Name
D1 TS – Dundas
D2 TS – Dundas
D3 TS – Dundas
814 TS – Rydalmere
816 TS – Rydalmere
815 TS – Castle Hill
818 TS – West Pennant Hills
825 TS – Tee
825/1 Tee – West Pennant Hills
825/2 Tee – Castle Hill
830 Castle Hill – Kenthurst
96.0
96.0
96.0
72.2
58.0
40.5
43.7
40.5
86.0
40.5
35.8
Actual
(MVA)
2014
22.8
22.8
13.8
34.2
34.2
20.1
28.7
26.9
22.9
20.1
21.4
Forecast (MVA)
2015
22.9
22.9
13.8
37.0
37.0
20.4
38.4
36.6
32.5
20.4
17.6
2016
23.8
23.8
14.4
37.0
37.0
20.5
38.5
36.7
32.6
20.5
17.6
2017
24.6
24.6
14.8
37.1
37.1
20.5
41.8
39.9
35.8
20.5
17.6
2018
25.0
25.0
15.1
37.1
37.1
20.5
30.6
28.7
24.6
20.5
17.6
2019
25.3
25.3
15.3
37.2
37.2
20.5
30.6
28.7
24.6
20.5
17.6
Table 25: Carlingford TS – summer
Network Constraint
Year
Feeder 825 exceeds its emergency rating
of 40MVA under N-1 conditions.
2016/17
Investigation
This limitation is not expected to eventuate as Feeder
825 is to be re-tensioned and augmented to a 50 MVA
summer rating in 2014/15. The removal of the
temporary customer load is planned prior to 2017/18
summer.
Table 26: Carlingford TS – identified limitations
Solution
Continue to
Monitor
3.2.5.3
CARLINGFORD TS NETWORK MAP
3.2.6
DAPTO BULK SUPPLY POINT
3.2.6.1
DAPTO BSP CONNECTION POINTS
Dapto Bulk Supply Point is owned by TransGrid and has three 375 MVA 330/132kV transformers.
Endeavour Energy is supplied at 132kV from Dapto BSP. Dapto BSP supplies 132kV north to Bellambi,
Springhill and Outer Harbour TS’s; south to Mt Terry TS, Shoalhaven TS and West Tomerong TS (partly
commissioned, March 2014) as well as Ulladulla ZS; and west to Burrawang Pumping Station then
further west providing backup to Fairfax Lane TS. Dapto BSP also supplies 132kV to the Essential
Energy network at Bateman’s Bay ZS and Moruya North TS. The Essential Energy substations are
supplied through the rebuilt Evans Lane Switching Station which is also the connection point for Ulladulla
ZS. Tallawarra SS, which is connected to Springhill TS and to Dapto BSP, connects TRUenergy’s
400MW generator to the 132kV network.
Substation
Batemans Bay ZS (Essential
Energy)
Ulladulla ZS
Yatte Yattah ZS
Bellambi TS
Moruya North TS (Essential
Energy)
Mount Terry TS
Outer Harbour TS
Shoalhaven TS
Springhill TS
West Tomerong TS
Voltage
Levels
Transformer
Description
(MVA)
132/33kV
2 x 23
Installed
Capacity
Total ‘N’
(MVA)
46
Embedded
Generation
(MW)
23
95% Peak
Load
Exceeded
(hours)
1.25
132/33kV
132/33kV
132/33kV
132/33kV
2 x 30
1x5
3 x 60
2 x 30
60
5
180
60
30
5
120
30
5.50
0.50
2.50
3.25
2.80
0.47
-
132/33kV
132/33kV
132/33kV
132/33kV
132/33kV
2 x 120
2 x 60
3 x 60
3 x 120
2 x 60
240
120
180
360
120
120
60
120
240
60
4.25
2.25
10.25
6.25
2.75
-
Firm Rating
Secure ‘N-1’
(MVA)
-
Table 27: Dapto BSP – transformer rating and substation details
Substation Name
Batemans Bay/Moruya Nth
Ulladulla ZS
Yatte Yattah ZS
Bellambi TS
Mount Terry TS
Outer Harbour TS
Shoalhaven TS
Springhill TS
West Tomerong TS
Dapto BSP
Forecast
PF
1.000
0.938
0.997
0.948
0.952
0.966
0.972
0.933
0.996
Actual (MVA)
2013
2014
46.5
33.7
26.6
19.6
4.0
4.3
75.8
63.5
124.9
78.1
29.4
23.7
136.7
109.2
166.5
153.5
650.0
549.5
2015
33.7
16.2
77.0
76.5
37.6
78.2
163.9
44.8
587.6
2016
33.7
16.7
78.9
79.9
37.6
81.9
167.6
41.8
596.5
Forecast (MVA)
2017
33.7
16.8
79.3
80.6
37.6
82.1
180.9
45.5
612.4
2018
33.7
16.9
79.9
83.0
37.6
82.4
180.8
45.6
615.2
2019
33.7
17.0
80.4
83.3
37.6
82.9
182.8
45.7
618.3
2014
44.9
20.8
85.2
89.2
40.0
74.4
158.9
50.2
656.1
2015
44.9
21.1
86.5
90.2
40.0
74.5
162.1
51.7
662.9
Forecast (MVA)
2016
44.9
21.3
86.5
92.0
40.0
78.3
168.6
49.9
672.4
2017
44.9
21.4
86.5
94.1
40.0
78.3
172.9
50.7
679.0
2018
44.9
21.4
86.5
94.2
40.0
78.3
173.5
50.8
679.8
Table 28: Dapto BSP – summer demand forecast
Substation Name
Batemans Bay/Moruya Nth
Ulladulla ZS
Yatte Yattah ZS
Bellambi TS
Mount Terry TS
Outer Harbour TS
Shoalhaven TS
Springhill TS
West Tomerong TS
Dapto BSP
Forecast
PF
1.000
0.938
0.991
0.948
0.954
0.981
0.974
0.949
0.995
Actual (MVA)
2012
2013
45.5
42.1
26.7
23.0
4.4
3.4
80.7
85.4
97.3
96.3
35.7
29.6
118.7
118.4
154.7
149.8
674.0
622.6
Table 29: Dapto BSP – winter demand forecast
3.2.6.2
DAPTO BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Dapto BSP is at 132kV.
Capacity
(MVA)
Feeder Name
980 BSP – Bellambi TS
981 BSP – Bellambi TS
98Y BSP – Springhill TS
982 BSP – Springhill TS
983 BSP – Tallawarra SS
984 – BSP – Tallawarra SS
98X Tallawarra SS – Springhill TS
98G Tallawarra SS – Springhill TS
98B Springhill TS – HVC
986 – Springhill TS – HVC
989 Springhill TS – Outer Harbour
985 Springhill TS – Outer Harbour TS
988 BSP – Fairfax Lane TS
98W BSP – Mt Terry
98F BSP – Mt Terry
98L Mt Terry – Shoalhaven
98U Mt Terry – Shoalhaven
98H Evans Lane SS – Essential Energy
98M – Evans Lane SS – Essential Energy
28C Evans Lane SS – Ulladulla
28F Evans Lane SS – Ulladulla
98P Evans Lane SS – Shoalhaven
98J Evans Lane SS – Shoalhaven
98T – Essential Energy – Essential Energy
163.0
163.0
256.0
256.0
256.0
256.0
344.0
343.0
69.0
69.0
176.0
176.0
133.0
344.0
343.0
261.0
261.0
182.0
85.0
96.0
96.0
214.0
214.0
72.0
Actual
(MVA)
2014
63.5
63.5
71.7
71.7
71.7
71.7
71.7
71.7
24.9
24.9
23.7
23.7
7.3
240.6
240.6
162.5
162.5
61.3
61.3
19.6
19.6
53.3
53.3
33.7
Forecast (MVA)
2015
77.0
77.0
128.8
128.8
128.8
128.8
128.8
128.8
25.0
25.0
37.6
37.6
7.3
204.6
204.6
128.1
128.1
57.4
57.4
16.2
16.2
49.9
49.9
33.7
2016
78.9
78.9
130.1
130.1
130.1
130.1
130.1
130.1
25.0
25.0
37.6
37.6
7.3
212.2
212.2
132.3
132.3
57.9
57.9
16.7
16.7
50.4
50.4
33.7
2017
79.3
79.3
134.8
134.8
134.8
134.8
134.8
134.8
25.0
25.0
37.6
37.6
7.3
213.2
213.2
132.6
132.6
58.1
58.1
16.8
16.8
50.5
50.5
33.7
2018
79.9
79.9
134.7
134.7
134.7
134.7
134.7
134.7
25.0
25.0
37.6
37.6
7.3
216.0
216.0
133.0
133.0
58.2
58.2
16.9
16.9
50.6
50.6
33.7
2019
80.4
80.4
135.5
135.5
135.5
135.5
135.5
135.5
25.0
25.0
37.6
37.6
7.3
216.8
216.8
133.5
133.5
58.2
58.2
17.0
17.0
50.7
50.7
33.7
Table 30: Dapto BSP – summer
Network Constraint
Nil
Year
Investigation
Table 31: Dapto BSP – identified limitations
Solution
3.2.6.3
DAPTO BSP NETWORK MAP
3.2.7
FAIRFAX LANE TRANSMISSION SUBSTATION
3.2.7.1
FAIRFAX LANE TS CONNECTION POINTS
Fairfax Lane Transmission Substation is owned by Endeavour Energy and has three 60MVA 132/33kV
transformers providing a firm capacity of 120MVA. The substation is supplied via 132kV feeder 98C from
Marulan BSP with an alternative supply from feeder 988 Dapto BSP. Feeder 98C is rated at 168/190
MVA summer/winter with 988 rated at 133/146 MVA summer/winter. The capacity of each of these
132kV feeders is adequate to meet the medium-term needs of the area.
Substation
Voltage
Levels
Berrima Junction ZS
Bowral ZS
33/11kV
33/11kV
Mittagong ZS
33/11kV
Moss Vale ZS
Ringwood ZS
Robertson ZS
Fairfax Lane TS
33/11kV
33/11kV
33/11kV
132/33kV
Transformer
Description
(MVA)
1 x 20
2 x 10 + 1 x
12.5
2 x 12.5 + 1 x
15
2 x 25
2 x 12.5
2 x 3.5
3 x 60
Installed
Capacity
Total ‘N’
(MVA)
20
32.5
Embedded
Generation
(MW)
NA
20
95% Peak
Load
Exceeded
(hours)
0.25
1.50
40
25
9.25
1.57
50
25
7.0
180
25
12.5
3.5
120
8.50
0.25
5.25
8.50
1.02
0.82
0.44
-
Firm Rating
Secure ‘N-1’
(MVA)
0.00
1.18
Table 32: Fairfax Lane TS – transformer rating and substation details
Substation Name
Berrima Junction ZS
Bowral ZS
Mittagong ZS
Moss Vale ZS
Ringwood ZS
Robertson ZS
Fairfax Lane TS
Forecast
PF
0.900
0.955
0.945
0.920
0.944
0.925
0.945
Actual (MVA)
2013
2014
1.7
1.8
18.5
15.3
13.8
12.8
17.4
16.0
5.4
5.6
3.5
3.6
78.8
74.1
2015
1.9
16.4
14.1
16.2
5.8
3.7
74.2
2016
1.9
16.5
14.5
16.4
5.8
3.7
74.9
Forecast (MVA)
2017
2.2
16.5
14.8
16.8
5.8
3.7
75.7
2018
2.6
16.6
15.1
17.1
5.8
3.7
76.6
2019
2.8
16.7
15.3
17.5
5.9
3.7
77.4
2014
1.6
17.5
15.0
17.2
5.6
4.6
83.9
2015
1.8
17.5
15.3
17.3
5.6
4.6
84.5
Forecast (MVA)
2016
2.1
17.5
15.5
17.5
5.6
4.6
85.0
2017
2.3
17.5
15.7
17.7
5.6
4.6
85.5
2018
2.4
17.5
15.8
17.9
5.6
4.6
85.9
Table 33: Fairfax Lane TS – summer demand forecast
Substation Name
Berrima Junction ZS
Bowral ZS
Mittagong ZS
Moss Vale ZS
Ringwood ZS
Robertson ZS
Fairfax Lane TS
Forecast
PF
0.900
0.999
0.994
0.953
0.975
0.917
0.988
Actual (MVA)
2012
2013
0.7
1.5
19.2
17.0
16.1
14.8
18.3
17.7
6.0
6.1
4.8
4.4
82.6
84.2
Table 34: Fairfax Lane TS – winter demand forecast
3.2.7.2
FAIRFAX LANE TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Fairfax Lane TS is at 33kV.
Capacity
(MVA)
Feeder Name
7905 – TS – HVC
7903 TS – Moss Vale
7904 TS – Moss Vale
7917 TS – Ringwood
7908 HVC – Moss Vale
7906 Ringwood – Moss Vale
7907 TS – Robertson
7901 TS – Bowral
7902 TS – Bowral
7918 Bowral – Mittagong
7909 Bowral – Mittagong
7910 Mittagong – HVC
34.3
35.2
32.5
17.7
28.6
8.0
11.4
42.4
42.4
43.0
29.2
32.5
Actual
(MVA)
2014
23.9
9.6
9.6
5.6
23.9
5.6
3.6
30.2
30.2
14.9
14.9
4.3
Forecast (MVA)
2015
24.0
25.8
25.8
5.8
24.0
5.8
3.7
34.6
34.6
18.2
18.2
6.3
2016
24.0
26.0
26.0
5.8
24.0
5.8
3.7
35.1
35.1
18.7
18.7
6.3
2017
24.0
26.4
26.4
5.8
24.0
5.8
3.7
35.5
35.5
18.9
18.9
6.3
2018
24.0
26.7
26.7
5.8
24.0
5.8
3.7
35.8
35.8
19.2
19.2
6.3
2019
24.0
27.1
27.1
5.9
24.0
5.9
3.7
36.1
36.1
19.4
19.4
6.3
Table 35: Fairfax Lane TS – summer
Network Constraint
Robertson ZS firm rating exceeded. The
load is 26% above the firm rating for a
single transformer
Year
Investigation
Solution
W2015
The situation will continue to be monitored and further
options to be investigated in the future.
Continue to
Monitor
Table 36: Fairfax Lane TS – identified limitations
3.2.7.3
FAIRFAX LANE TS NETWORK MAP
3.2.8
GUILDFORD TRANSMISSION SUBSTATION
3.2.8.1
GUILDFORD TS CONNECTION POINTS
Guildford Transmission Substation is supplied at 132kV from Holroyd Bulk Supply Point by feeders 93F
and 93L and also from Sydney West BSP by feeders 93M (via West Wetherill Park) and 93J (via
Granville and Camellia) with two N/O bus-sections between the two supply sources. Guildford TS rebuild
project TS-125 established new indoor 132kV GIS, 33kV indoor switchboard and three 120MVA power
transformers. Guildford TS caters for the existing customer base as well as for the 132kV Parramatta
CBD network. Guildford TS has three 120MVA transformers providing a firm capacity of 240MVA.
Marubeni generating station supplies 160MW and 60MVAr onto the Guildford 33kV busbar.
Substation
Cabramatta ZS
Carramar ZS
Fairfield ZS
Sherwood ZS
Smithfield ZS
South Granville ZS
Woodpark ZS
Yennora ZS
Guildford TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 25
2 x 25
3 x 25
3 x 25
3 x 25
2 x 25
2 x 25
2 x 25
4 x 60
Installed
Capacity
Total ‘N’
(MVA)
50
50
75
75
75
50
50
50
240
Firm Rating
Secure ‘N-1’
(MVA)
25
25
50
50
50
25
25
25
180
95% Peak
Load
Exceeded
(hours)
3.25
3.25
3.00
7.25
6.25
12.50
61.00
5.00
15.50
Embedded
Generation
(MW)
1.10
0.91
0.87
1.27
2.98
0.79
0.08
0.93
213.7
Table 37: Guildford TS – transformer rating and substation details
Substation Name
Cabramatta ZS
Carramar ZS
Fairfield ZS
Guildford (Ausgrid)
Sherwood ZS
Smithfield ZS
South Granville ZS
Woodpark ZS
Yennora ZS
Guildford TS
Forecast
PF
0.969
0.991
0.972
0.891
0.999
0.996
0.937
0.970
0.957
0.961
Actual (MVA)
2013
2014
22.3
24.3
17.0
16.8
27.5
23.1
23.6
21.8
27.2
26.0
35.6
28.8
18.9
15.6
24.7
22.3
17.9
16.4
231.3
207.3
2015
16.2
19.0
25.3
22.9
27.7
32.4
17.7
22.9
18.1
229.6
2016
16.3
19.0
25.3
22.7
27.8
32.6
17.8
22.9
18.4
210.2
Forecast (MVA)
2017
16.3
19.1
25.3
22.5
28.0
32.7
17.8
22.9
18.4
210.4
2018
16.4
19.1
25.3
22.4
28.1
32.8
17.9
22.9
18.5
210.7
2019
16.4
19.1
25.3
22.3
28.1
32.9
17.9
22.9
18.5
210.8
2014
10.3
14.3
21.4
19.8
20.9
23.4
12.9
21.3
15.1
174.2
2015
10.3
14.6
22.6
19.2
21.4
23.9
12.9
21.6
15.1
176.2
Forecast (MVA)
2016
10.3
14.6
22.6
19.2
21.4
23.9
12.9
21.6
15.1
176.2
2017
10.3
14.6
22.6
19.3
21.4
23.9
12.9
21.6
15.1
176.3
2018
10.3
14.6
22.6
19.5
21.4
23.9
12.9
21.6
15.1
176.5
Table 38: Guildford TS – summer demand forecast
Substation Name
Cabramatta ZS
Carramar ZS
Fairfield ZS
Guildford (Ausgrid)
Sherwood ZS
Smithfield ZS
South Granville ZS
Woodpark ZS
Yennora ZS
Guildford TS
Forecast
PF
0.986
0.996
0.996
0.930
0.998
0.997
0.965
0.983
0.980
0.973
Actual (MVA)
2012
2013
20.6
17.4
13.6
15.0
24.3
21.2
20.3
19.8
23.3
20.3
23.8
23.4
13.0
12.8
22.3
21.3
17.4
15.0
184.3
181.1
Table 39: Guildford TS – winter demand forecast
3.2.8.2
GUILDFORD TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Guildford TS is at 33kV.
Capacity
(MVA)
Feeder Name
744 TS – Horsley Park
757 TS – Cabramatta
779 TS – Woodpark
671 TS – Fairfield
674 TS – Fairfield
755 TS – Sherwood
777 TS – Sherwood
756 TS – Tee
756 Tee – Yennora
756 Tee – HVC
759 TS – Yennora
758 TS – Tee
758/1 Tee – Sth Granville
758 Tee – HVC
780 TS – Sth Granville
763 TS – Tee
763/2 Tee – Smithfield
763/1 Tee – HVC
774 TS – Smithfield
673 TS – Carramar
672 Fairfield – Carramar
45.0
23.3
42.0
45.0
65.0
55.0
42.0
32.0
42.0
24.0
19.0
24.0
42.0
24.0
19.0
24.0
42.0
42.0
23.0
34.0
28.0
28.0
Actual
(MVA)
2014
28.8
11.2
24.3
22.3
40.0
40.0
26.0
26.0
26.9
16.4
21.1
16.4
10.5
0.0
21.1
0.0
29.0
14.4
19.5
28.8
16.8
16.8
Forecast (MVA)
2015
32.0
11.2
16.2
22.9
44.3
44.3
27.7
27.7
29.0
18.1
21.8
18.1
28.6
17.7
21.8
17.7
31.2
16.2
19.6
32.2
19.0
19.0
2016
30.0
9.0
16.3
22.9
44.3
44.3
27.8
27.8
18.4
18.4
0.0
18.4
17.8
17.8
0.0
17.8
31.3
16.3
19.6
31.3
19.0
19.0
2017
30.1
9.1
16.3
22.9
44.4
44.4
28.0
28.0
18.4
18.4
0.0
18.4
17.8
17.8
0.0
17.8
31.4
16.3
19.6
31.4
19.1
19.1
2018
30.2
9.1
16.4
22.9
44.4
44.4
28.1
28.1
18.5
18.5
0.0
18.5
17.9
17.9
0.0
17.9
31.5
16.4
19.6
31.5
19.1
19.1
2019
30.2
9.1
16.4
22.9
44.4
44.4
28.1
28.1
18.5
18.5
0.0
18.5
17.9
17.9
0.0
17.9
31.5
16.4
19.6
31.5
19.1
19.1
Table 40: Guildford TS – summer
Network Constraint
Nil
Year
Investigation
Table 41: Guildford TS – identified limitations
Solution
3.2.8.3
GUILDFORD TS NETWORK MAP
3.2.9
HAWKESBURY TRANSMISSION SUBSTATION
3.2.9.1
HAWKESBURY TS CONNECTION POINTS
Hawkesbury transmission substation is supplied at 132kV from Vineyard Bulk Supply Point by feeders
227 and 234. Hawkesbury TS has three 120 MVA 132 / 33kV transformers.
Substation
Cattai ZS
East Richmond
Glossodia ZS
Glenorie ZS
Kurrajong ZS
North Richmond ZS
Richmond ZS
Riverstone ZS
South Windsor ZS
Windsor ZS
Wisemans ZS
Hawkesbury TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
1 x 15 + 1 x 25
2 x 35
2 x 25
1 x 15
2 x 15
2 x 25
2 x 25
2 x 25
3 x 25
2 x 35
1 x 12.5
3 x 120
Installed
Capacity
Total ‘N’
(MVA)
40
70
50
15
30
50
50
50
75
70
12.5
360
Firm Rating
Secure ‘N-1’
(MVA)
15
35
25
15
15
25
25
25
50
35
NA
240
95% Peak
Load
Exceeded
(hours)
0.25
1.25
6.25
3.00
5.50
4.00
13.25
3.75
2.50
11.00
Embedded
Generation
(MW)
0.53
0.98
0.27
1.02
0.93
0.41
0.54
1.47
0.63
0.16
-
Table 42: Hawkesbury TS – transformer rating and substation details
Substation Name
Cattai ZS
East Richmond ZS
Glenorie ZS
Glossodia ZS
Kurrajong ZS
North Richmond ZS
Richmond ZS
Riverstone ZS
South Windsor ZS
Windsor ZS
Forecast
PF
0.920
0.990
0.950
0.929
0.931
0.966
0.998
0.969
0.926
Actual (MVA)
2013
2014
11.7
10.9
17.3
17.8
13.2
11.4
19.8
18.5
19.3
19.1
13.8
13.9
37.3
31.6
19.0
19.3
2015
13.0
20.6
4.3
19.7
11.8
20.6
13.7
38.4
21.3
2016
13.0
20.6
4.3
19.7
11.8
20.6
11.3
38.4
21.3
Forecast (MVA)
2017
13.1
20.6
4.3
19.7
11.8
20.7
13.5
38.4
21.3
2018
13.1
20.6
4.3
19.7
11.8
20.9
14.5
38.4
21.3
2019
13.1
20.6
4.3
19.7
11.8
21.0
15.8
38.4
21.3
2014
7.7
16.0
4.3
11.7
9.5
13.8
12.8
26.2
11.1
2015
7.8
16.3
4.3
11.7
9.5
13.8
11.6
26.9
11.1
Forecast (MVA)
2016
7.8
16.3
4.3
11.7
9.5
13.9
12.2
26.9
11.1
2017
7.8
16.3
4.3
11.7
9.5
14.2
12.7
26.9
11.1
2018
7.8
16.3
4.3
11.7
9.5
14.4
13.0
26.9
11.1
Table 43: Hawkesbury TS – summer demand forecast
Substation Name
Cattai ZS
East Richmond ZS
Glenorie ZS
Glossodia ZS
Kurrajong ZS
North Richmond ZS
Richmond ZS
Riverstone ZS
South Windsor ZS
Windsor ZS
Forecast
PF
0.960
0.996
0.950
0.970
0.969
0.986
0.996
0.993
0.962
Actual (MVA)
2012
2013
7.5
7.7
10.9
10.7
9.5
9.4
15.3
14.6
15.1
14.4
18.2
13.1
26.5
24.7
17.4
13.3
Table 44: Hawkesbury TS – winter demand forecast
3.2.9.2
HAWKESBURY TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Hawkesbury TS is at 33kV.
Capacity
(MVA)
Feeder Name
444 TS – Riverstone
458 TS – Tee
458 Tee – Riverstone
458 Tee – Cattai (New)
446 TS – Windsor
447 TS – Windsor
443 Windsor – Cattai (New)
437 Cattai – Wisemans
436 TS – South Windsor
439 TS – Glossodia
438 TS – Richmond
452 TS – North Richmond
453 TS – Tee
453 Tee – Kurrajong
453 Tee – Nth Richmond
424 North Richmond – Tee
424 Tee Kurrajong
424 Tee Glossodia
42.0
46.0
19.0
36.0
42.0
42.0
34.0
19.0
31.0
31.0
31.0
26.0
45.0
45.0
45.0
45.0
42.0
42.0
21.0
25.0
Actual
(MVA)
2014
13.9
20.3
16.0
13.9
27.3
27.3
16.0
5.1
15.8
15.8
15.8
19.6
19.1
24.0
22.3
11.4
12.3
17.8
11.4
17.8
Forecast (MVA)
2015
13.7
20.9
18.1
13.7
30.3
30.3
18.1
5.1
19.2
19.2
19.2
21.7
20.6
26.6
24.4
11.8
13.7
19.7
11.8
19.7
2016
11.3
18.5
18.2
11.3
30.4
30.4
18.2
5.1
19.2
19.2
19.2
21.7
20.6
26.6
24.4
11.8
13.7
19.7
11.8
19.7
2017
13.5
20.8
18.2
13.5
30.4
30.4
18.2
5.1
19.2
19.2
19.2
21.7
20.6
26.7
24.4
11.8
13.7
19.7
11.8
19.7
2018
14.5
21.8
18.2
14.5
30.4
30.4
18.2
5.1
19.2
19.2
19.2
21.7
20.6
26.8
24.5
11.8
13.8
19.7
11.8
19.7
2019
15.8
23.1
18.2
15.8
30.4
30.4
18.2
5.1
19.2
19.2
19.2
21.8
20.6
26.8
24.6
11.8
13.8
19.7
11.8
19.7
Table 45: Hawkesbury TS – summer
Network Constraint
The firm rating of Riverstone ZS will be
exceeded by S2024.
Year
S2024
Outage of feeder 439 results in overloading
of feeder 453 at 106.7%
S2015
Investigation
Continue to monitor lot releases uptake and load
growth. Future non-network option investigation to be
conducted.
Continue to monitor and investigate the contingency
rating.
Table 46: Hawkesbury TS – identified limitations
Solution
Continue to
Monitor
Continue to
Monitor
3.2.9.3
HAWKESBURY TS NETWORK MAP
3.2.10
HOLROYD BULK SUPPLY POINT
3.2.10.1 HOLROYD BSP CONNECTION POINTS
Holroyd Bulk Supply Point is owned by TransGrid and has two 375 MVA 330/132kV transformers,
providing a firm capacity of 375MVA. Feeders 93F and 93L operate at 132kV between Holroyd and
Guildford. These feeders are tail-ended on the transformers at Holroyd and connected to Guildford
132kV indoor GIS busbar to avoid a busbar duplication over a short distance between Holroyd and
Guildford.
Substation
Granville ZS
North Parramatta ZS
West Parramatta ZS
Camellia TS
Guildford TS
Voltage
Levels
Transformer
Description
(MVA)
132/11kV
132/11kV
132/11kV
132/33kV
132/33kV
2 x 45
2 x 55
3 x 45
3 x 120
4 x 60
Installed
Capacity
Total ‘N’
(MVA)
90
110
135
360
240
Firm Rating
Secure ‘N-1’
(MVA)
45
55
90
240
180
95% Peak
Load
Exceeded
(hours)
3.25
4.50
4.00
17.50
14.50
Embedded
Generation
(MW)
0.79
0.57
0.00
-
Table 47: Holroyd BSP – transformer rating and substation details
Substation Name
Granville ZS
North Parramatta ZS
West Parramatta ZS
Camellia TS
Guildford TS
Holroyd BSP
Forecast
PF
0.950
0.999
0.994
0.938
0.961
0.965
Actual (MVA)
2013
2014
-
2015
24.8
28.9
58.0
49.4
229.6
390.6
2016
25.5
31.3
58.0
51.8
210.2
376.8
Forecast (MVA)
2017
25.6
33.3
62.2
51.8
210.4
383.3
2018
25.6
33.4
62.2
51.8
210.7
383.8
2019
25.7
33.5
62.2
51.8
210.8
384.0
2014
19.5
21.0
43.3
51.4
174.2
309.5
2015
19.5
24.4
43.3
51.4
176.2
314.9
Forecast (MVA)
2016
19.5
24.4
45.6
51.4
176.2
317.1
2017
19.5
24.4
46.7
51.4
176.3
318.3
2018
19.5
24.4
46.7
51.4
176.5
318.5
Table 48: Holroyd BSP – summer demand forecast
Substation Name
Granville ZS
North Parramatta ZS
West Parramatta ZS
Camellia TS
Guildford TS
Holroyd BSP
Forecast
PF
0.950
0.999
0.949
0.959
0.973
0.968
Actual (MVA)
2012
2013
-
Table 49: Holroyd BSP – winter demand forecast
3.2.10.2 HOLROYD BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Holroyd BSP is at 132kV.
Capacity
(MVA)
Feeder Name
Actual
(MVA)
2014
Forecast (MVA)
2015
2016
2017
2018
2019
Nil
Table 50: Holroyd BSP – summer
Network Constraint
Nil
Year
Investigation
Table 51: Holroyd BSP – identified limitations
Solution
3.2.10.3 HOLROYD BSP NETWORK MAP
3.2.11
ILFORD TRANSMISSION SUBSTATION
3.2.11.1 ILFORD TS CONNECTION POINTS
Ilford Transmission Substation (TS) is supplied at 132kV from Mt Piper TS by a single feeder 94M and a
single 60MVA 132/66kV transformer. The backup supply is provided through the 66kV network from Mt
Piper TS.
Substation
Bylong ZS
Ilford Hall ZS
Kandos ZS
Ilford TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
66/11kV
132/66kV
2 x 1.5
1 x 2.5
2x5
1 x 30 + 1 x 60
Installed
Capacity
Total ‘N’
(MVA)
3
2.5
10
90
Firm Rating
Secure ‘N-1’
(MVA)
1.5
NA
5
30
95% Peak
Load
Exceeded
(hours)
5.25
0.00
2.50
4.00
Embedded
Generation
(MW)
0.00
0.04
0.31
-
Table 52: Ilford TS – transformer rating and substation details
Substation Name
Bylong ZS
Ilford Hall ZS
Kandos ZS
Ilford TS
Forecast
PF
0.962
0.902
0.920
0.970
Actual (MVA)
2013
2014
0.4
0.4
0.4
0.4
4.3
4.4
5.4
6.0
2015
0.4
0.4
4.9
5.2
2016
0.4
0.4
4.9
5.3
Forecast (MVA)
2017
2018
0.4
0.4
0.4
0.4
5.1
5.2
5.4
16.5
2019
0.4
0.4
5.2
16.6
2014
0.3
0.4
4.7
5.3
2015
0.3
0.4
4.8
5.4
Forecast (MVA)
2016
2017
0.3
0.3
0.4
0.4
4.9
5.0
5.5
14.4
2018
0.3
0.4
5.1
18.2
Table 53: Ilford TS – summer demand forecast
Substation Name
Bylong ZS
Ilford Hall ZS
Kandos ZS
Ilford TS
Forecast
PF
0.983
0.938
0.960
0.970
Actual (MVA)
2012
2013
0.3
0.3
0.5
0.4
4.4
4.7
6.8
7.7
Table 54: Ilford TS – winter demand forecast
3.2.11.2 ILFORD TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Ilford TS is at 66kV.
Capacity
(MVA)
Feeder Name
841 TS – Kandos
828 Mt Piper – Tee
828 Mt Piper – Portland Tee
828/1 Portland Tee – Airly Colliery Tee
828/4 Kandos ZS – Charbon Tee
828/2 and 828/3 Hyrock Tee – Charbon
839 Kandos – Bylong
20.0
45.0
32.0
20.0
60.0
20.0
20.0
Actual
(MVA)
2014
4.8
12.8
12.8
12.8
0.0
12.8
0.4
Forecast (MVA)
2015
6.2
14.2
14.2
14.2
1.0
13.2
0.4
2016
5.3
13.3
13.3
13.3
0.0
13.3
0.4
2017
5.5
13.5
13.5
13.5
0.0
13.5
0.4
2018
5.6
13.6
13.6
13.6
0.0
13.6
0.4
2019
5.6
13.6
13.6
13.6
0.0
13.6
0.4
Table 55: Ilford TS – summer
Network Constraint
Nil
Year
Investigation
Table 56: Ilford TS – identified limitations
Solution
3.2.11.3 ILFORD TS NETWORK MAP
3.2.12
INGLEBURN BULK SUPPLY POINT
3.2.12.1 INGLEBURN BSP CONNECTION POINTS
Ingleburn BSP is owned by TransGrid and has two, 250 MVA 330/66kV transformers. There is sufficient
capacity at this substation to supply its existing catchment for the foreseeable future.
Substation
Bow Bowing ZS
Macquarie Fields ZS
Minto ZS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
66/11kV
3 x 35
2 x 33
2 x 33 +1 x 35
Installed
Capacity
Total ‘N’
(MVA)
105
66
101
Firm Rating
Secure ‘N-1’
(MVA)
70
33
66
95% Peak
Load
Exceeded
(hours)
7.50
4.75
6.75
Embedded
Generation
(MW)
1.56
2.50
4.60
Table 57: Ingleburn BSP – transformer rating and substation details
Substation Name
Bow Bowing ZS
Macquarie Fields ZS
Minto ZS
Ingleburn BSP
Forecast
PF
0.986
0.981
0.970
0.976
Actual (MVA)
2013
2014
47.4
43.7
29.2
25.4
60.8
53.5
137.7
118.0
2015
43.0
26.1
50.8
118.7
2016
45.1
26.2
55.9
125.9
Forecast (MVA)
2017
45.1
26.3
56.6
126.8
2018
45.1
26.3
57.6
127.7
2019
45.1
26.4
58.5
128.7
2014
42.9
22.0
49.4
114.1
2015
42.2
22.0
49.6
113.6
Forecast (MVA)
2016
42.2
22.0
50.0
114.0
2017
42.2
22.0
50.5
114.5
2018
42.2
22.0
51.1
115.1
Table 58: Ingleburn BSP – summer demand forecast
Substation Name
Bow Bowing ZS
Macquarie Fields ZS
Minto ZS
Ingleburn BSP
Forecast
PF
0.992
0.989
0.986
0.990
Actual (MVA)
2012
2013
42.1
43.0
24.7
23.7
50.1
49.6
132.2
158.3
Table 59: Ingleburn BSP – winter demand forecast
3.2.12.2 INGLEBURN BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Ingleburn BSP is at 66kV.
Capacity
(MVA)
Feeder Name
860 BSP – Tee
860 Tee – Bow Bowing
860 Tee – Macquarie Fields
862 TS – Minto
863 TS – Minto
866 TS – Bow Bowing
861 Tee – Narellan
864 TS – Macquarie Fields
64.0
64.0
64.0
64.0
64.0
64.0
50.0
64.0
Actual
(MVA)
2014
50.7
43.7
25.4
78.2
78.2
43.7
15.6
25.4
Forecast (MVA)
2015
50.2
43.0
26.1
74.6
74.6
43.0
17.5
26.1
2016
52.4
45.1
26.2
79.7
79.7
45.1
20.3
26.2
2017
52.4
45.1
26.3
80.5
80.5
45.1
20.6
26.3
2018
52.4
45.1
26.3
81.5
81.5
45.1
20.8
26.3
2019
52.4
45.1
26.4
82.5
82.5
45.1
21.0
26.4
Table 60: Ingleburn BSP – summer
Network Constraint
Outage 866 BSP-to Bow Bowing will cause
feeder 860 to exceed its line rating.
Minto ZS distribution system has a number
of feeders that have exceeded their
network ratings.
Outage of either 862 or 863 BSP-Minto,
results in load at risk on the alternate
feeder.
Year
Existing
Investigation
Network switching will maintain network within capacity.
Existing
A demand management program is currently in
operating to manage the peak summer demand and
defer the construction of Eschol Park ZS.
A demand management program is currently in
operating to manage the peak summer demand and
defer the augmentation of feeders 862 and 863.
S2015
Table 61: Ingleburn BSP – identified limitations
Solution
Transfer
Capacity
DM
Program in
operation
DM
Program in
operation
3.2.12.3 INGLEBURN BSP NETWORK MAP
3.2.13
KATOOMBA NORTH TRANSMISSION SUBSTATION
3.2.13.1 KATOOMBA NORTH TS CONNECTION POINTS
Katoomba North transmission substation is supplied at 132kV from Wallerawang bulk supply point by
feeders 940 and 941. Both feeders are teed off and tail ended to two 60MVA 132/66kV transformers.
Substation
Blackheath ZS
Katoomba ZS
Wentworth Falls ZS
Katoomba North TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
66/11kV
132/66kV
2x7
2 x 25
1 x 10
2 x 60
Installed
Capacity
Total ‘N’
(MVA)
14
50
10
120
Firm Rating
Secure ‘N-1’
(MVA)
7
25
NA
60
95% Peak
Load
Exceeded
(hours)
1.25
22.00
0.50
1.50
Embedded
Generation
(MW)
0.86
1.44
0.91
-
Table 62: Katoomba North TS – transformer rating and substation details
Substation Name
Blackheath ZS
Katoomba ZS
Wentworth Falls ZS
Katoomba North TS
Forecast
PF
0.977
0.969
0.993
0.969
Actual (MVA)
2013
2014
5.0
4.4
14.2
14.5
5.6
6.4
23.3
21.4
2015
4.6
15.2
6.4
24.4
2016
4.6
15.2
6.4
24.4
Forecast (MVA)
2017
2018
4.6
4.6
15.2
15.2
6.4
6.4
24.4
24.4
2019
4.6
15.2
6.4
24.4
2014
6.7
17.8
6.2
29.9
2015
6.7
17.8
6.2
29.9
Forecast (MVA)
2016
2017
6.7
6.7
17.8
17.8
6.2
6.2
29.9
29.9
2018
6.7
17.8
6.2
29.9
Table 63: Katoomba North TS – summer demand forecast
Substation Name
Blackheath ZS
Katoomba ZS
Wentworth Falls ZS
Katoomba North TS
Forecast
PF
0.981
0.974
0.992
0.961
Actual (MVA)
2012
2013
6.9
6.6
17.7
17.2
7.1
6.2
38.0
30.4
Table 64: Katoomba North TS – winter demand forecast
3.2.13.2 KATOOMBA NORTH TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Katoomba North TS is at 66kV.
109.0
36.0
36.0
Actual
(MVA)
2014
14.5
14.5
0.0
2015
21.5
15.2
6.4
2016
21.5
15.2
6.4
2017
21.5
15.2
6.4
2018
21.5
15.2
6.4
2019
21.5
15.2
6.4
82.0
36.0
109.0
36.0
36.0
0.0
0.0
11.6
14.5
4.4
6.4
6.4
12.2
15.2
4.6
6.4
6.4
12.2
15.2
4.6
6.4
6.4
12.2
15.2
4.6
6.4
6.4
12.2
15.2
4.6
6.4
6.4
12.2
15.2
4.6
Capacity
(MVA)
Feeder Name
804 TS – Tee
804 Tee – Katoomba ZS
804 Katoomba North TS Tee – Wentworth Falls ZS
Tee
804 Tee – Wentworth Falls ZS
804 Wentworth Falls Tee – Lawson TS
805 TS – Tee
805 Tee – Katoomba ZS
805 Katoomba North TS Tee – Blackheath ZS
Forecast (MVA)
Table 65: Katoomba North TS – summer
Network Constraint
Nil
Year
Investigation
Table 66: Katoomba North TS – identified limitations
Solution
3.2.13.3 KATOOMBA NORTH TS NETWORK MAP
3.2.14
LAWSON TRANSMISSION SUBSTATION
3.2.14.1 LAWSON TS CONNECTION POINTS
Lawson Transmission Substation is supplied at 132kV on feeder 941 Wallerawang with the alternate
supply being feeder 942 from Penrith. Lawson TS provides limited backup supply to Katoomba North TS
at 66kV.
Substation
Hazelbrook ZS
Lawson TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
132/66kV
2 x 25
2 x 52
Installed
Capacity
Total ‘N’
(MVA)
50
104
Firm Rating
Secure ‘N-1’
(MVA)
25
52
95% Peak
Load
Exceeded
(hours)
0.75
0.75
Embedded
Generation
(MW)
1.64
-
Table 67: Lawson TS – transformer rating and substation details
Substation Name
Hazelbrook ZS
Lawson TS
Forecast
PF
0.984
0.985
Actual (MVA)
2013
2014
7.9
10.0
23.7
26.5
2015
10.3
22.7
2016
10.3
22.7
Forecast (MVA)
2017
2018
10.3
10.3
22.7
22.7
2019
10.3
22.7
2014
11.2
22.2
2015
11.3
22.3
Forecast (MVA)
2016
2017
11.3
11.3
22.3
22.3
2018
11.3
22.3
Table 68: Lawson TS – summer demand forecast
Substation Name
Hazelbrook ZS
Lawson TS
Forecast
PF
0.984
0.985
Actual (MVA)
2012
2013
10.0
11.1
19.4
22.8
Table 69: Lawson TS – winter demand forecast
3.2.14.2 LAWSON TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Lawson TS is at 66kV.
Capacity
(MVA)
Feeder Name
826 TS – Hazelbrook
808 Hazelbrook – Springwood
824 TS – Springwood
804/1 Wallerawang – Katoomba North
50.0
22.0
45.0
22.0
Actual
(MVA)
2014
32.5
10.0
32.5
0.0
Forecast (MVA)
2015
33.7
10.3
33.7
6.4
2016
33.8
10.3
33.8
6.4
2017
34.0
10.3
34.0
6.4
2018
34.1
10.3
34.1
6.4
2019
34.2
10.3
34.2
6.4
Table 70: Lawson TS – summer
Network Constraint
Thermal capacity of standby feeder 808 is
exceeded by 12.3% when it supplies
Springwood ZS during outage of Feeder
824.
Year
S2015
Investigation
Load transfer at 11kV from Springwood ZS to Blaxland
ZS and Hazelbrook ZS (2MVA) deferring the constraint
until S2021.
Screening test to be conducted to investigate nonnetwork options.
Table 71: Lawson TS – identified limitations
Solution
Transfer
capacity
Investigate
options
3.2.14.3 LAWSON TS NETWORK MAP
3.2.15
LIVERPOOL TRANSMISSION SUBSTATION
3.2.15.1 LIVERPOOL TS CONNECTION POINTS
Liverpool TS has two 120MVA 132/33kV transformers providing a firm capacity of 120MVA, but will have
three transformers by summer 2014/15, providing a firm capacity of 240MVA. Liverpool TS is supplied by
two 132kV feeders, 23L and 93G from the West Liverpool TS busbar. A project has been approved to
augment Liverpool ZS and Homepride ZS and to upgrade the Liverpool CBD 11kV distribution network
thus allowing full capacity utilisation at Liverpool ZS and Homepride ZS.
Substation
Anzac Village ZS
Casula ZS
Chipping Norton ZS
Liverpool ZS
Moorebank ZS
Liverpool TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33 kV
3 x 25
2 x 35
2 x 35
3 x 35
3 x 35
2 x 120
Installed
Capacity
Total ‘N’
(MVA)
75
70
70
105
105
240
Firm Rating
Secure ‘N-1’
(MVA)
50
35
35
70
70
120
95% Peak
Load
Exceeded
(hours)
12.00
6.75
0.75
7.50
5.00
5.75
Embedded
Generation
(MW)
1.97
2.35
1.14
2.65
0.76
-
Table 72: Liverpool TS – transformer rating and substation details
Substation Name
Anzac Village ZS
Casula ZS
Chipping Norton ZS
Liverpool ZS
Moorebank ZS
Liverpool TS
Forecast
PF
0.954
0.958
0.969
0.972
0.956
0.966
Actual (MVA)
2013
2014
24.1
18.9
6.5
50.9
34.5
39.1
34.4
86.4
107.7
2015
20.9
28.8
21.3
33.4
26.2
125.2
2016
22.5
30.3
21.3
32.7
26.2
127.9
Forecast (MVA)
2017
23.4
32.2
22.9
33.3
26.2
133.1
2018
24.8
33.3
22.9
33.9
26.2
137.0
2019
26.4
33.6
22.9
34.6
26.2
140.8
2014
20.4
8.8
14.8
32.5
26.2
101.4
2015
17.8
9.3
16.0
31.5
26.2
99.7
Forecast (MVA)
2016
18.0
10.3
16.0
31.9
26.2
101.5
2017
18.7
11.7
16.0
32.3
26.2
104.2
2018
19.7
12.5
16.0
32.7
26.2
107.2
Table 73: Liverpool TS – summer demand forecast
Substation Name
Anzac Village ZS
Casula ZS
Chipping Norton ZS
Liverpool ZS
Moorebank ZS
Liverpool TS
Forecast
PF
0.985
0.900
0.900
0.996
0.979
0.991
Actual (MVA)
2012
2013
37.9
35.8
33.3
33.3
69.7
66.6
Table 74: Liverpool TS – winter demand forecast
3.2.15.2 LIVERPOOL TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Liverpool TS is at 33kV.
Capacity
(MVA)
Feeder Name
23L West Liverpool – Liverpool TS
93G West Liverpool – Liverpool TS
230*
250.0
Actual
(MVA)
2014
107.7
107.7
Forecast (MVA)
2015
125.2
125.2
2016
127.9
127.9
2017
133.1
133.1
2018
137.0
137.0
2019
140.8
140.8
Table 75: Liverpool TS – summer *Contingency rating
Network Constraint
Anzac Village ZS Feeder 500 or 528
overloads for an outage on the alternate
feeder.
Year
S2022/23
Investigation
Defence 33kV HVC has agreed to an Overload Load
Shedding Agreement. Longer term Endeavour Energy
solution is to establish Holsworthy ZS subject to the
rate of developer activity on surplus Commonwealth
land adjacent to Anzac Village ZS..
Table 76: Liverpool TS – identified limitations
Solution
Continue to
monitor
3.2.15.3 LIVERPOOL TS NETWORK MAP
3.2.16
LIVERPOOL BULK SUPPLY POINT
3.2.16.1 LIVERPOOL BSP CONNECTION POINTS
Liverpool Bulk Supply Point is owned by TransGrid and has three tail ended 375 MVA 330/132kV
transformers providing a firm capacity of 750 MVA. Endeavour Energy is supplied at 132kV from
Liverpool BSP to both the West Liverpool TS (located adjacent to Liverpool BSP) and the Liverpool TS
(located near Liverpool CBD) via the West Liverpool TS 132kV busbar.
Substation
Abbotsbury ZS
Denham Court ZS
Liverpool TS
West Liverpool TS
Voltage
Levels
Transformer
Description
(MVA)
132/11kV
132/11kV
132/33kV
132/33kV
2 x 45
1 x 60
3 x 120
3 x 120
Installed
Capacity
Total ‘N’
(MVA)
90
60
360
360
Firm Rating
Secure ‘N-1’
(MVA)
45
NA
240
240
95% Peak
Load
Exceeded
(hours)
5.75
7.50
Embedded
Generation
(MW)
-
Table 77: Liverpool BSP – transformer rating and substation details
Substation Name
Abbotsbury ZS
Denham Court ZS
Liverpool TS
West Liverpool TS
West Liverpool BSP
Forecast
PF
0.900
0.966
0.989
0.978
Actual (MVA)
2013
2014
86.4
107.7
251.5
198.9
463.6
422.0
2015
20.0
125.2
195.6
331.8
2016
30.4
20.0
127.9
180.3
346.6
Forecast (MVA)
2017
30.4
20.0
133.1
187.4
358.7
2018
30.4
20.0
137.0
191.4
366.4
2019
30.4
20.0
140.8
194.4
373.0
2014
30.4
15.8
101.4
134.3
261.7
2015
30.4
15.8
99.7
137.1
262.8
Forecast (MVA)
2016
30.4
15.8
101.5
141.6
268.7
2017
30.4
15.8
104.2
144.5
274.1
2018
30.4
15.8
107.2
147.0
279.2
Table 78: Liverpool BSP – summer demand forecast
Substation Name
Abbotsbury ZS
Denham Court ZS
Liverpool TS
West Liverpool TS
West Liverpool BSP
Forecast
PF
0.900
0.900
0.991
0.992
0.996
Actual (MVA)
2012
2013
69.7
66.6
184.9
179.5
386.4
322.1
Table 79: Liverpool BSP – winter demand forecast
3.2.16.2 LIVERPOOL BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Liverpool BSP is at 132kV.
Capacity
(MVA)
Feeder Name
93B Liverpool TG – West Liverpool
93N Liverpool TG – West Liverpool
93R Liverpool TG – West Liverpool
512.0
512.0
512.0
Actual
(MVA)
2014
153.3
153.3
153.3
Forecast (MVA)
2015
160.4
160.4
160.4
2016
154.1
154.1
154.1
2017
160.2
160.2
160.2
2018
164.2
164.2
164.2
2019
167.6
167.6
167.6
Table 80: Liverpool BSP – summer
Network Constraint
Nil
Year
Investigation
Table 81: Liverpool BSP – identified limitations
Solution
3.2.16.3 LIVERPOOL BSP NETWORK MAP
3.2.17
MACARTHUR BULK SUPPLY POINT
3.2.17.1 MACARTHUR BSP CONNECTION POINTS
Macarthur BSP has been established to the south of the Mt Annan Botanic Garden, by TransGrid to
serve as the bulk supply point for the South West Growth Sector at 132kV and also the greater
Campbelltown area at 66kV. Macarthur BSP supplies power at 66kV through one 250MVA, 330/66kV
transformer and will supply 132kV through one 375MVA, 330/132kV transformer initially. Ultimately
Macarthur BSP can be configured with two 375MVA 330/132kV and two 250MVA 330/66kV
transformers.
Substation
Ambarvale ZS
Appin ZS
Broughton Pass ZS
Campbelltown ZS
Kentlyn ZS
Oran Park ZS
South Leppington ZS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
66/11kV
66/11kV
66/11kV
132/11kV
132/11kV
2 x 35
1 x 15
2 x 17.5
3 x 35
2 x 33
2 x 45
1 x 45
Installed
Capacity
Total ‘N’
(MVA)
70
15
35
105
66
90
45
Firm Rating
Secure ‘N-1’
(MVA)
35
NA
17.5
70
33
45
NA
95% Peak
Load
Exceeded
(hours)
3.00
5.50
33.75
13.25
4.50
3.50
-
Embedded
Generation
(MW)
2.82
0.43
1.83
2.75
0.216
-
Table 82: Macarthur BSP – transformer rating and substation details
Substation Name
Ambarvale ZS
Appin ZS
Broughton Pass ZS
Campbelltown ZS
Kentlyn ZS
Oran Park ZS
South Leppington ZS
Macarthur BSP
Forecast
PF
0.988
0.932
0.955
0.928
0.994
0.900
0.962
Actual (MVA)
2013
2014
32.5
24.5
59.7
29.0
116.2
50.7
24.7
105.3
2015
25.4
3.7
2.8
58.4
23.7
4.1
263.9
2016
25.5
3.8
2.8
58.5
23.8
4.9
272.1
Forecast (MVA)
2017
25.9
3.8
2.8
58.6
23.9
12.9
5.7
291.6
2018
26.3
3.8
2.8
58.7
24.0
14.8
6.5
298.0
2019
26.3
3.8
2.8
58.7
24.0
16.7
7.3
304.2
2014
17.5
3.6
2.8
38.0
25.9
6.2
0.1
258.7
2015
17.5
3.6
2.8
36.8
25.9
7.9
4.4
266.2
Forecast (MVA)
2016
17.5
3.6
2.8
36.8
25.9
10.6
5.2
272.2
2017
17.5
3.6
2.8
36.8
25.9
12.8
6.2
278.9
2018
17.5
3.6
2.8
36.8
25.9
15.4
7.5
287.2
Table 83: Macarthur BSP – summer demand forecast
Substation Name
Ambarvale ZS
Appin ZS
Broughton Pass ZS
Campbelltown ZS
Kentlyn ZS
Oran Park ZS
South Leppington ZS
Macarthur BSP
Forecast
PF
0.996
0.959
0.955
0.995
0.993
0.900
0.900
0.975
Actual (MVA)
2012
2013
18.6
17.8
36.8
27.8
97.6
37.7
25.9
97.6
Table 84: Macarthur BSP – winter demand forecast
3.2.17.2 MACARTHUR BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Macarthur BSP is at 66kV & 132kV.
Capacity
(MVA)
Feeder Name
853 TS – Ambarvale
854 TS – Campbelltown
859 TS – Campbelltown
867 Ambarvale – Kentlyn
85T Campbelltown – Kentlyn
85T Tee – Minto
85T Tee – Campbelltown
67.0
64.0
67.0
73.0
72.0
72.2
72.2
Actual
(MVA)
2014
49.2
50.7
50.7
24.5
49.2
24.5
24.5
Forecast (MVA)
2015
49.1
58.4
58.4
25.4
49.1
25.4
25.4
2016
49.3
58.5
58.5
25.5
49.3
25.5
25.5
2017
49.8
58.6
58.6
25.9
49.8
25.9
25.9
2018
50.2
58.7
58.7
26.3
50.2
26.3
26.3
2019
50.2
58.7
58.7
26.3
50.2
26.3
26.3
Table 85: Macarthur BSP – summer
Network Constraint
Outage of feeder 851 or 852 results in an
overload on the other feeder (see Nepean
TS)
Year
S2016
Outage of the single 330/66kV transformer
at Macarthur causes load at risk on
feeders 9L1.
S2015
Oran Park 132/11kV Mobile ZS has been
established to provide supply to initial
loads.
The permanent ZS will be required to meet
the forecast load.
S2016
Investigation
Constraint is dependent on the level of generation
activity. Solutions include a load curtailment agreement
and power factor correction to defer the construction of
a 66kV feeder. A screening test was conducted and
found that demand management was possible by
approaching major customers in the area to negotiate
viable demand management options. An in-house nonnetwork option investigation will be conducted.
Transfer Kentlyn ZS and half of Ambarvale ZS to the
Ingleburn system via Minto if required.
Area diversity levels will likely defer this constraint to
beyond the planning period.
Establish the permanent 132/11kV ZS when required.
Subject to the rate of new housing development.
Establish the permanent 132/11kV ZS.
The line works to provide a second feeder are in the
process of being established, approved as part of the
initial Mobile ZS project
Table 86: Macarthur BSP – identified limitations
Solution
Investigate
nonnetwork
options
Possible
build option
Continue to
Monitor
Joint
Planning
with
TransGrid
PR 408
PR 255
3.2.17.3 MACARTHUR BSP NETWORK MAP
3.2.18
MT DRUITT TRANSMISSION SUBSTATION
3.2.18.1 MT DRUITT TS CONNECTION POINTS
Mt Druitt TS is currently supplied from Sydney West BSP via feeder 932 and feeder 939/219 via Mamre
ZS. Backup supply is available via feeders 936 and 933 from Regentville BSP via Penrith TS for a loss of
feeder 932 and a combined Mamre and Mt Druitt load above the rating of feeder 939. It has three 120
MVA 132/33kV transformers with provision for an additional one.
Substation
Claremont Meadows ZS
Horsley Park ZS
Plumpton ZS
St Marys ZS
Werrington ZS
Whalan ZS
Mt Druitt TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 25
2 x 25
3 x 25
2 x 25 + 1 x 19
3 x 35
3 x 25
3 x 120
Installed
Capacity
Total ‘N’
(MVA)
50
50
75
69
105
75
360
Firm Rating
Secure ‘N-1’
(MVA)
25
25
50
44
70
50
240
95% Peak
Load
Exceeded
(hours)
3.00
1.75
7.00
8.75
5.00
3.25
1.50
Embedded
Generation
(MW)
1.28
0.49
3.06
2.66
1.37
2.00
10.8
Table 87: Mt Druitt TS – transformer rating and substation details
Substation Name
Horsley Park ZS
Plumpton ZS
St Marys ZS
Werrington ZS
Whalan ZS
Mount Druitt TS
Forecast
PF
0.991
0.961
0.969
0.987
0.973
0.979
Actual (MVA)
2013
2014
24.0
15.2
11.2
30.8
29.5
38.3
31.4
40.4
35.0
36.5
32.8
126.6
158.0
2015
24.7
33.6
32.8
37.9
37.2
160.9
2016
25.9
33.8
33.0
39.4
37.3
163.9
Forecast (MVA)
2017
27.2
33.8
33.0
40.7
37.3
166.4
2018
28.2
33.8
33.0
41.0
37.3
167.6
2019
28.6
33.8
33.0
41.0
37.3
168.0
2014
26.8
23.3
22.1
32.9
22.1
113.2
2015
27.9
23.3
22.5
33.8
22.1
115.1
Forecast (MVA)
2016
29.7
23.3
22.7
35.3
22.1
118.1
2017
30.9
23.3
22.7
36.6
22.1
120.2
2018
31.3
23.3
22.7
36.9
22.1
120.8
Table 88: Mt Druitt TS – summer demand forecast
Substation Name
Horsley Park ZS
Plumpton ZS
St Marys ZS
Werrington ZS
Whalan ZS
Mount Druitt TS
Forecast
PF
0.994
0.991
0.997
0.990
0.999
0.997
Actual (MVA)
2012
2013
14.5
11.4
8.6
23.6
22.2
25.3
26.6
33.9
32.9
24.9
23.3
115.8
127.8
Table 89: Mt Druitt TS – winter demand forecast
3.2.18.2 MT DRUITT TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Mt Druitt TS is at 33kV.
Capacity
(MVA)
Feeder Name
490 TS – St Marys
491 TS – St Marys
492 TS – Werrington
488 TS – Plumpton
495 TS – Whalan
487 Mt Druitt TS – Tee
487 Tee – Plumpton ZS
487 Tee – Whalan ZS
489 TS – East Wallgrove
48C Eastern Creek SS – Horsley Park
497 Werrington ZS – Tee
497 Tee – HVC
497 Tee – Cambridge Park ZS
34.0
34.0
32.0
34.0
45.0
42.0
42.0
42.0
42.0
42.0
34.0
42.0
34.0
21.0
34.0
Actual
(MVA)
2014
31.4
31.4
21.9
20.2
21.9
29.5
32.8
32.8
29.5
32.8
11.2
11.2
26.6
7.1
19.5
Forecast (MVA)
2015
32.8
32.8
23.3
21.5
23.3
33.6
37.2
37.2
33.6
37.2
11.2
11.2
28.3
7.0
21.3
2016
33.0
33.0
24.1
22.3
24.1
33.8
37.3
37.3
33.8
37.3
9.0
9.0
28.3
7.0
21.3
2017
33.0
33.0
24.8
22.9
24.8
33.8
37.3
37.3
33.8
37.3
9.1
9.1
28.3
7.0
21.3
2018
33.0
33.0
25.0
23.0
25.0
33.8
37.3
37.3
33.8
37.3
9.1
9.1
28.3
7.0
21.3
2019
33.0
33.0
25.0
23.0
25.0
33.8
37.3
37.3
33.8
37.3
9.1
9.1
28.3
7.0
21.3
Table 90: Mt Druitt TS – summer
Network Constraint
Feeders 490 and 491-St Marys ZS,
exceed capacity (34 MVA) under an
outage of the other feeder.
Year
S2015
Investigation
LAR is 0.6MVA, however a temporary transfer
capacity of approximately 2MVA to Mamre ZS and
Whalan ZS exists if required.
Table 91: Mt Druitt TS – identified limitations
Solution
Utilise transfer
capacity
3.2.18.3 MT DRUITT TS NETWORK MAP
3.2.19
MOUNT PIPER BULK SUPPLY POINT
3.2.19.1 MOUNT PIPER BSP CONNECTION POINTS
Mt Piper BSP is owned by TransGrid and supplies both Endeavour Energy and Essential Energy.
Endeavour Energy’s demand is limited to 45MVA on each feeder, being the rating of the metering
equipment. Mt Piper TS has two 120MVA 132/66/11kV transformers with no provision for any additional,
each with a cyclic rating of 150MVA.
Substation
Blackmans Flat ZS
Hartley Vale ZS
Ilford TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
66/11kV
132/66kV
2 x 10
2 x 2.5
1 x 60
Installed
Capacity
Total ‘N’
(MVA)
20
5
60
Firm Rating
Secure ‘N-1’
(MVA)
10
2.5
NA
95% Peak
Load
Exceeded
(hours)
0.75
0.25
4.00
Embedded
Generation
(MW)
0.24
0.07
-
Table 92: Mount Piper BSP – transformer rating and substation details
Substation Name
Blackmans Flat ZS
Hartley Vale ZS
Ilford TS
Mount Piper TS
Forecast
PF
0.961
0.979
0.970
0.895
Actual (MVA)
2013
2014
4.5
4.4
0.9
1.5
5.4
6.0
34.8
39.5
2015
5.6
1.9
5.2
38.9
2016
5.6
1.9
5.3
42.0
Forecast (MVA)
2017
2018
5.6
5.6
1.9
1.9
5.4
16.5
43.6
54.0
2019
5.6
1.9
16.6
54.0
2014
6.0
1.4
5.3
38.7
2015
8.0
1.7
5.4
39.3
Forecast (MVA)
2016
2017
8.0
8.0
1.7
1.7
5.5
14.4
42.3
51.2
2018
8.0
1.7
18.2
54.6
Table 93: Mount Piper BSP – summer demand forecast
Substation Name
Blackmans Flat ZS
Hartley Vale ZS
Ilford TS
Mount Piper TS
Forecast
PF
0.961
0.989
0.970
0.922
Actual (MVA)
2012
2013
5.6
5.4
1.2
1.4
6.8
7.7
38.4
36.8
Table 94: Mount Piper BSP – winter demand forecast
3.2.19.2 MOUNT PIPER BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Mount Piper BSP is at 66kV.
Capacity
(MVA)
Feeder Name
811 Blackmans Flat ZS – HVCs
812 Hartley Vale ZS – HVC
835 TS – Tee
835 Tee – HVC
835/2 Tee – Blackmans Flat ZS
831 TS – Blackmans Flat ZS
840 Blackmans Flat ZS – HVCs
828 BSP – HVCs
80.0
83.0
60.0
45.0
50.0
50.0
80.0
31.0
Actual
(MVA)
2014
32.9
32.9
48.6
0.1
32.9
48.6
11.1
5.2
Forecast (MVA)
2015
31.7
31.7
50.9
0.1
31.7
50.9
6.7
7.0
2016
30.2
30.2
44.9
0.1
30.2
44.9
6.7
12.1
2017
26.8
26.8
41.5
0.1
26.8
41.5
6.7
15.5
2018
28.7
28.7
43.4
0.1
28.7
43.4
6.7
15.5
Table 95: Mount Piper BSP – summer
Network Constraint
Nil
Year
Investigation
Table 96: Mount Piper BSP – identified limitations
Solution
2019
28.7
28.7
43.4
0.1
28.7
43.4
6.7
15.5
3.2.19.3 MOUNT PIPER BSP NETWORK MAP
3.2.20
MOUNT TERRY TRANSMISSION SUBSTATION
3.2.20.1 MOUNT TERRY TS CONNECTION POINTS
Mt Terry Transmission Substation has two 120MVA 132/33kV transformers providing a firm capacity of
120 MVA. The substation is fed from Dapto BSP via 132kV feeders 98F and 98W. Feeders 98L and
98U from Mt Terry provide supply to Shoalhaven TS and onto the south coast substations of West
Tomerong, Ulladulla, Moruya North and Batemans Bay.
Substation
Voltage
Levels
Albion Park ZS
Gerringong ZS
Jamberoo ZS
Kiama ZS
33/11kV
33/11kV
33/11kV
33/11kV
Shellharbour ZS
Warilla ZS
33/11kV
33/11kV
Mount Terry TS
132/33kV
Transformer
Description
(MVA)
3 x 12.5
2x5
1 x 3.75
2 x 12.5 + 1 x
15
2 x 20 + 1 x 25
2 x 10 + 1 x
12.5
2 x 120
Installed
Capacity
Total ‘N’
(MVA)
37.5
10
3.75
40
Embedded
Generation
(MW)
25
5
NA
25
95% Peak
Load
Exceeded
(hours)
0.75
7.00
0.50
2.50
65
32.5
40
20
3.00
7.25
2.49
2.14
240
120
4.25
-
Firm Rating
Secure ‘N-1’
(MVA)
2.47
0.91
0.26
1.64
Table 97: Mount Terry TS – transformer rating and substation details
Substation Name
Albion Park ZS
Gerringong ZS
Jamberoo ZS
Kiama ZS
Shellharbour ZS
Warilla ZS
Mount Terry TS
Forecast
PF
0.949
0.962
0.928
0.959
0.990
0.945
0.948
Actual (MVA)
2013
2014
25.0
19.0
5.9
4.2
3.5
2.6
12.9
9.8
28.7
21.8
19.6
15.2
124.9
78.1
2015
18.5
4.3
2.8
10.2
22.3
15.1
76.5
2016
19.3
4.3
2.8
10.3
23.5
16.4
79.9
Forecast (MVA)
2017
19.5
4.3
2.8
10.4
23.8
16.4
80.6
2018
19.7
4.3
2.9
10.4
23.9
16.5
83.0
2019
19.9
4.3
2.9
10.5
24.0
16.6
83.3
2014
18.8
6.0
1.9
14.1
24.7
19.0
89.2
2015
19.4
6.0
1.9
14.1
25.1
19.0
90.2
Forecast (MVA)
2016
19.6
6.0
1.9
14.1
26.0
19.7
92.0
2017
19.7
6.0
1.9
14.1
26.0
19.7
94.1
2018
19.8
6.0
1.9
14.1
26.1
19.7
94.2
Table 98: Mount Terry TS – summer demand forecast
Substation Name
Albion Park ZS
Gerringong ZS
Jamberoo ZS
Kiama ZS
Shellharbour ZS
Warilla ZS
Mount Terry TS
Forecast
PF
0.983
0.975
0.980
0.978
0.995
0.978
0.948
Actual (MVA)
2012
2013
18.9
18.3
6.7
6.0
2.4
2.3
13.7
14.6
23.2
26.8
19.3
20.1
97.3
96.3
Table 99: Mount Terry TS – winter demand forecast
3.2.20.2 MOUNT TERRY TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Mount Terry TS is at 33kV.
Capacity
(MVA)
Feeder Name
7058 TS – Albion Park
7054 TS – Albion Park
7158 Albion Park – Warilla
7041 TS – Dapto ZS
7004 Shellharbour – Warilla
7047 TS – Croom SS
7147 Shellharbour – Croom SS
7059 TS – Shellharbour
7005 Shellharbour – Kiama
7050 TS – Jerrara SS
7043 TS – Tee
7006 Tee – Jerrara SS
7007 Jerrara SS – Kiama
7175 Jerrara SS – Gerringong
7008 Kiama – Gerringong
7381 Port Central – Warilla
7176 Berry – Gerringong
7060 HVC – HVC
7341 Dapto – Kembla Grange
45.7
45.7
32.0
27.4
32.1
33.2
33.2
33.2
13.4
22.5
11.9
13.1
54.4
13.4
20.6
16.0
16.4
15.4
32.1
Actual
(MVA)
2014
30.2
30.2
17.6
8.8
15.2
24.7
20.7
21.8
9.8
13.7
12.7
8.2
11.6
4.2
4.2
10.6
6.6
3.4
4.4
Forecast (MVA)
2015
29.7
29.7
17.6
9.3
15.1
25.2
21.2
22.3
10.2
14.2
13.2
8.4
12.1
4.3
4.3
10.3
8.0
3.3
4.4
2016
31.3
31.3
18.9
10.0
16.4
26.4
22.4
23.5
10.3
14.3
13.3
8.4
12.2
4.3
4.3
10.3
8.1
3.3
4.5
2017
31.7
31.7
19.1
10.1
16.4
26.7
22.6
23.8
10.4
14.4
13.3
8.4
12.3
4.3
4.3
10.3
8.1
3.3
4.5
2018
31.9
31.9
19.2
9.6
16.5
26.8
22.7
23.9
10.4
14.4
13.4
8.5
12.3
4.3
4.3
10.3
8.2
3.3
4.5
2019
32.1
32.1
19.2
9.8
16.6
26.9
22.8
24.0
10.5
14.5
13.4
8.5
12.4
4.3
4.3
10.3
8.4
3.3
4.5
Table 100: Mount Terry TS – summer
Network Constraint
Transfer of Berry ZS from Shoalhaven
TS, overloads feeder 7043.
Year
S2022
Investigation
LAR is 6.7% over firm. The situation will continue to
be monitored. Options include augmentation and
demand management. Screening test to be conducted
to investigate non-network options.
Table 101: Mount Terry TS – identified limitations
Solution
Continue to
monitor
Investigate
Non-Network
Options
3.2.20.3 MOUNT TERRY TS NETWORK MAP
3.2.21
NEPEAN TRANSMISSION SUBSTATION
3.2.21.1 NEPEAN TS CONNECTION POINTS
Nepean TS is supplied from Sydney West BSP on feeder 93X and Liverpool BSP via West Liverpool TS
on feeder 93Y. It has three 60 MVA 132/33kV transformers and two 120 MVA 132/66kV autotransformers. The substation is limited by the 132kV feeders 93X and 93Y to a firm rating of
145/190MVA summer/winter, less the demand of Bringelly ZS and the Oran Park Mobile ZS, which are
teed to feeder 93X. The substation is also supported by embedded generation on the 66kV subtransmission system.
Substation
Appin ZS
Cawdor ZS
Maldon ZS
Narellan ZS
Nepean ZS
Oakdale ZS
Tahmoor ZS
The Oaks ZS
Wilton ZS
Nepean TS
Nepean TS
Voltage
Levels
Transformer
Description
(MVA)
66/11kV
33/11kV
66/11kV
66/11kV
66/11kV
33/11kV
66/11kV
33/11kV
66/11kV
132/33kV
132/66kV
1x5
2 x 25
2 x 35
3 x 35
2 x 35
2 x 10
2 x 25
1 x 15
2 x 10
3 x 60
2 x 120
Installed
Capacity
Total ‘N’
(MVA)
5
50
70
105
70
20
50
15
20
180
240
Firm Rating
Secure ‘N-1’
(MVA)
NA
25
35
70
35
10
25
NA
10
120
120
95% Peak
Load
Exceeded
(hours)
5.50
1.50
6.00
7.00
2.25
3.00
3.75
0.00
2.50
0.25
Embedded
Generation
(MW)
0.43
1.47
1.60
2.85
1.40
0.23
1.52
0.54
0.35
100
Table 102: Nepean TS – transformer rating and substation details
Substation Name
Appin ZS
Cawdor ZS
Maldon ZS
Narellan ZS
Nepean ZS
Oakdale ZS
Tahmoor ZS
The Oaks ZS
Wilton ZS
Nepean TS 33kV
Nepean TS 66kV
Forecast
PF
0.948
0.980
0.965
0.968
0.934
0.992
0.900
0.900
0.965
0.983
Actual (MVA)
2013
2014
5.2
3.8
14.4
24.6
22.1
17.5
50.6
47.4
35.3
22.8
9.1
1.5
16.1
14.4
6.1
2.2
49.0
34.5
140.7
147.6
2015
28.0
17.5
52.9
20.7
1.6
14.9
6.5
3.3
37.8
115.9
2016
28.0
17.6
61.6
23.0
1.6
14.9
6.6
3.8
37.8
125.5
Forecast (MVA)
2017
28.0
17.6
62.3
24.0
1.6
14.9
6.6
4.2
37.8
127.4
2018
28.0
17.6
63.0
25.0
1.6
14.9
6.6
4.6
37.8
129.1
2019
28.0
17.6
63.7
25.9
1.6
14.9
6.6
4.9
37.8
130.6
2014
20.2
15.5
29.7
14.7
2.9
12.5
5.8
2.0
32.6
90.4
2015
20.2
15.5
30.8
15.5
2.9
12.5
5.8
2.4
32.6
92.3
Forecast (MVA)
2016
20.2
15.5
32.1
16.3
2.9
12.5
5.8
2.8
32.6
94.5
2017
20.2
15.5
33.7
17.2
2.9
12.5
5.8
3.1
32.6
96.9
2018
20.2
15.5
35.5
18.1
2.9
12.5
5.8
3.4
32.6
99.6
Table 103: Nepean TS – summer demand forecast
Substation Name
Appin ZS
Cawdor ZS
Maldon ZS
Narellan ZS
Nepean ZS
Oakdale ZS
Tahmoor ZS
The Oaks ZS
Wilton ZS
Nepean TS 33kV
Nepean TS 66kV
Forecast
PF
0.900
0.980
0.997
0.986
0.963
0.997
0.900
0.900
0.968
0.992
Actual (MVA)
2012
2013
5.1
3.5
15.7
18.4
17.0
29.6
29.8
16.7
7.8
4.1
13.5
13.0
5.3
49.8
37.9
109.3
128.8
Table 104: Nepean TS – winter demand forecast
3.2.21.2 NEPEAN TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Nepean TS is at 33kV & 66kV.
Capacity
(MVA)
Feeder Name
303 Cawdor – Tee
306 TS – Cawdor
309 TS – Oakdale
311 TS – Cawdor
TS – Camden
TS – Camden
TS – Camden
858 TS – Narellan
870 TS – Narellan
852 Brooks Point SS – Douglas Park SS
851 TS – Maldon
850 Douglas Park SS – Maldon
868 Douglas Park –Tee
869 Douglas Park –Tee
869 Tee Wilton
85C Maldon – Wilton
848 Tahmoor – Maldon
845 Tahmoor – Maldon
25.0
25.0
29.0
29.0
26.0
26.0
26.0
50.0
91.0
60.0
60.0
51.0
60.0
40.0
40.0
73.0
60.0
42.0
Actual
(MVA)
2014
1.5
29.2
1.5
32.1
11.4
11.4
13.6
47.4
47.4
-47.4
51.6
51.6
38.2
14.3
2.2
2.2
14.4
34.1
Forecast (MVA)
2015
1.6
29.2
1.6
32.1
11.3
11.3
13.5
52.9
52.9
63.0
52.0
52.0
38.8
14.4
3.3
3.3
14.9
34.5
2016
1.6
29.2
1.6
32.1
11.3
11.3
13.5
61.6
61.6
63.9
52.1
52.1
38.8
14.4
3.8
3.8
14.9
34.5
2017
1.6
29.2
1.6
32.1
11.3
11.3
13.5
62.3
62.3
65.1
52.2
52.2
31.9
14.4
4.2
4.2
14.9
34.6
2018
1.6
29.2
1.6
32.1
11.3
11.3
13.5
63.0
63.0
66.1
52.2
52.2
31.9
14.4
4.6
4.6
14.9
34.6
2019
1.6
29.2
1.6
32.1
11.3
11.3
13.5
63.7
63.7
66.9
52.2
52.2
31.9
14.4
4.9
4.9
14.9
34.6
Table 105: Nepean TS – summer
Network Constraint
Outage of feeder 311 Nepean TS –
Cawdor ZS will cause 306 to exceed its
rating.
Year
S2015
Investigation
This constraint will need to be further investigated.
Outage of feeder 306 Nepean TS –
Cawdor ZS will cause 311 to exceed its
rating.
S2015
Outage of Feeder 870 Nepean TS –
Narellan ZS will cause 858 to exceed its
rating.
S2015
Outage of either feeders 851 or 852
results in an overload on the other feeder
S2016
This constraint will need to be further investigated to
determine if the line needs to be augmented. SDF
transfer loads are indicative. Monitor actual loads for
next year. Screening test to be conducted to
investigate non-network options.
The load on Narellan ZS will be split between feeders
858 & 861 from Minto for an outage of feeder 870.
Network capacity will not be exceeded within the
planning period.
Constraint is dependent on the level of generation
activity. Solutions include a load curtailment
agreement and power factor correction to defer the
construction of a 66kV feeder. A screening test was
conducted and found that demand management was
possible by approaching major customers in the area
to negotiate viable demand management options. An
in-house non-network option investigation will be
conducted.
Table 106: Nepean TS – identified limitations
Solution
Investigate
non-network
options.
Continue to
monitor.
Investigate
non-network
options.
Continue to
monitor.
Utilise transfer
capacity
Investigate
non-network
options
Possible build
option
3.2.21.3 NEPEAN TS NETWORK MAP
3.2.22
OUTER HARBOUR TRANSMISSION SUBSTATION
3.2.22.1 OUTER HARBOUR TS CONNECTION POINTS
Outer Harbour TS is supplied from Dapto Bulk Supply Point via Springhill TS by 132kV feeders 985 &
989. 132kV feeder 985 previously consisted of a tee connection to BOC Gasses. Outer Harbour
Transmission Substation has one 30/45/60 MVA and one 30/60 MVA 132/33kV transformer providing a
firm rating of 60MVA.
Substation
Port Central ZS
Outer Harbour TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
132/33kV
2 x 19
2 x 60
Installed
Capacity
Total ‘N’
(MVA)
38
120
Firm Rating
Secure ‘N-1’
(MVA)
19
60
95% Peak
Load
Exceeded
(hours)
23.25
2.25
Embedded
Generation
(MW)
0.42
-
Table 107: Outer Harbour TS – transformer rating and substation details
Substation Name
Port Central ZS
Outer Harbour TS
Forecast
PF
0.982
0.952
Actual (MVA)
2013
2014
12.5
10.6
29.4
23.7
2015
10.3
37.6
2016
10.3
37.6
Forecast (MVA)
2017
2018
10.3
10.3
37.6
37.6
2019
10.3
37.6
2014
10.4
40.0
2015
10.4
40.0
Forecast (MVA)
2016
2017
10.4
10.4
40.0
40.0
2018
10.4
40.0
Table 108: Outer Harbour TS – summer demand forecast
Substation Name
Port Central ZS
Outer Harbour TS
Forecast
PF
0.995
0.954
Actual (MVA)
2012
2013
9.9
10.4
35.7
29.6
Table 109: Outer Harbour TS – winter demand forecast
3.2.22.2 OUTER HARBOUR TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Outer Harbour TS is at 33kV.
Capacity
(MVA)
Feeder Name
7032 TS – Port Central
7038 TS – Port Central
7381 Port Central – Warilla
7321 Port Central – Port Kembla
7034 TS – HVC
7039 TS – HVC
7033 TS – HVC
7031 TS – HVC
45.7
45.7
16.0
16.0
15.0
15.0
35.0
50.0
Actual
(MVA)
2014
10.6
10.6
10.6
0.0
1.5
1.5
9.9
9.9
Forecast (MVA)
2015
10.3
10.3
10.3
0.0
1.5
1.5
10.0
10.0
2016
10.3
10.3
10.3
0.0
1.5
1.5
10.0
10.0
2017
10.3
10.3
10.3
0.0
1.5
1.5
10.1
10.1
2018
10.3
10.3
10.3
0.0
1.5
1.5
10.3
10.3
Table 110: Outer Harbour TS – summer
Network Constraint
Nil
Year
Investigation
Table 111: Outer Harbour TS – identified limitations
Solution
2019
10.3
10.3
10.3
0.0
1.5
1.5
10.5
10.5
3.2.22.3 OUTER HARBOUR TS NETWORK MAP
3.2.23
PENRITH TRANSMISSION SUBSTATION
3.2.23.1 PENRITH TS CONNECTION POINTS
Penrith TS is supplied from Regentville BSP on 132kV feeders 222 and 238. Penrith TS has three
60MVA 132/33kV transformers, providing a firm capacity of 120MVA.
Substation
Cambridge Park ZS
Cranebrook ZS
Emu Plains ZS
Jordan Springs ZS
Kingswood ZS
Penrith TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 25
3 x 25
3 x 25
2 x 25
3 x 25
3 x 60
Installed
Capacity
Total ‘N’
(MVA)
50
75
75
50
75
180
Firm Rating
Secure ‘N-1’
(MVA)
25
50
50
25
50
120
95% Peak
Load
Exceeded
(hours)
5.00
6.00
7.75
13.00
-
Embedded
Generation
(MW)
1.48
1.51
2.05
2.09
-
Table 112: Penrith TS – transformer rating and substation details
Substation Name
Cambridge Park ZS
Cranebrook ZS
Emu Plains ZS
Jordan Springs ZS
Kingswood ZS
Penrith TS
Forecast
PF
0.993
0.992
0.991
0.900
0.953
0.986
Actual (MVA)
2013
2014
24.0
19.5
39.8
32.7
28.5
30.2
6.4
10.4
57.8
40.6
135.6
105.4
2015
21.3
35.0
34.8
12.9
45.4
115.0
2016
21.3
40.7
34.8
14.3
45.6
120.7
Forecast (MVA)
2017
21.3
40.7
34.8
15.7
46.1
122.0
2018
21.3
40.7
34.8
16.9
47.3
123.7
2019
21.3
40.7
34.8
17.4
48.5
125.1
2014
14.0
28.4
23.7
9.5
25.9
83.7
2015
14.0
32.9
24.0
10.6
26.4
88.9
Forecast (MVA)
2016
14.2
32.9
24.0
11.9
27.4
90.8
2017
14.7
32.9
24.0
13.1
28.3
92.9
2018
15.4
32.9
24.0
13.7
28.6
94.3
Table 113: Penrith TS – summer demand forecast
Substation Name
Cambridge Park ZS
Cranebrook ZS
Emu Plains ZS
Jordan Springs ZS
Kingswood ZS
Penrith TS
Forecast
PF
0.987
0.990
0.987
0.900
0.951
0.972
Actual (MVA)
2012
2013
17.7
19.5
35.7
27.8
24.7
23.6
6.8
39.0
27.7
101.8
85.7
Table 114: Penrith TS – winter demand forecast
3.2.23.2 PENRITH TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Penrith TS is at 33kV.
Capacity
(MVA)
Feeder Name
459 TS – Cranebrook
451 Penrith TS – tee
451 Tee – Cranebrook ZS
451 Tee – Jordan Springs ZS
454 TS – Emu Plains
462 TS – Emu Plains
457 Penrith TS – Tee
461 TS – Kingswood
456 TS – Cambridge Park
497 Tee – HVC
497 Tee – Cambridge Park ZS
464 Glenmore Park ZS – Tee
464 Tee – Kingswood ZS
464 Tee – Luddenham ZS
42.0
42.0
42.0
31.0
42.0
29.0
42.0
42.0
34.0
21.0
34.0
36.0
17.0
36.0
Actual
(MVA)
2014
32.7
33.2
32.7
0.5
30.2
30.2
27.1
27.1
19.5
7.1
19.5
20.6
13.5
20.6
Forecast (MVA)
2015
35.0
35.5
35.0
0.5
34.8
34.8
30.2
30.2
21.3
7.0
21.3
22.2
15.1
22.2
2016
40.7
41.2
40.7
0.5
34.8
34.8
30.4
30.4
21.3
7.0
21.3
22.3
15.2
22.3
2017
40.7
41.2
40.7
0.5
34.8
34.8
30.7
30.7
21.3
7.0
21.3
22.3
15.3
22.3
2018
40.7
41.2
40.7
0.5
34.8
34.8
31.5
31.5
21.3
7.0
21.3
22.3
15.7
22.3
Table 115: Penrith TS – summer
Network Constraint
Nil
Year
Investigation
Table 116: Penrith TS – identified limitations
Solution
2019
40.7
41.2
40.7
0.5
34.8
34.8
32.3
32.3
21.3
7.0
21.3
22.3
16.1
22.3
3.2.23.3 PENRITH TS NETWORK MAP
3.2.24
REGENTVILLE BULK SUPPLY POINT
3.2.24.1 REGENTVILLE BSP CONNECTION POINTS
Regentville Bulk Supply Point is owned by TransGrid and has two 375 MVA 330/132kV transformers
installed, providing a firm capacity of 375MVA. The load at Regentville 132kV is forecast to reach
268MVA by the end of the forecast period. Endeavour Energy’s Penrith and Warrimoo Transmission
Substations are supplied at 132kV from Regentville BSP as are Glenmore Park, North Warragamba and
Penrith 11kV Zone Substations.
Substation
Glenmore Park ZS
Luddenham ZS
North Warragamba ZS
Penrith ZS
Penrith TS
Warrimoo TS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
132/33kV
2 x 45
2 x 15
1 x 25 + 1 x 15
2 x 65
3 x 60
2 x 60
Installed
Capacity
Total ‘N’
(MVA)
90
30
40
130
180
120
Firm Rating
Secure ‘N-1’
(MVA)
45
15
15
65
120
60
95% Peak
Load
Exceeded
(hours)
4.75
6.25
4.00
5.00
3.75
1.25
Embedded
Generation
(MW)
2.56
0.40
0.62
0.45
-
Table 117: Regentville BSP – transformer rating and substation details
Substation Name
Glenmore Park ZS
Luddenham ZS
North Warragamba ZS
Penrith ZS
Penrith TS
Warrimoo TS
Regentville BSP
Forecast
PF
0.972
0.912
0.918
0.975
0.986
0.926
0.967
Actual (MVA)
2013
2014
38.3
36.9
8.9
8.6
9.5
9.2
47.2
42.9
135.6
105.4
53.8
46.9
290.6
243.6
2015
42.5
9.5
10.1
45.1
115.0
49.0
250.3
2016
43.1
9.5
10.2
47.6
120.7
49.3
258.8
Forecast (MVA)
2017
43.8
9.5
10.2
49.8
122.0
49.6
263.1
2018
44.5
9.5
10.2
49.8
123.7
49.8
265.5
2019
44.9
9.5
10.2
49.8
125.1
50.0
267.3
2014
21.2
6.4
8.2
39.4
83.7
43.9
184.6
2015
22.1
6.4
8.2
39.8
88.9
43.9
190.6
Forecast (MVA)
2016
22.7
6.4
8.2
39.9
90.8
43.9
193.0
2017
23.4
6.4
8.2
39.9
92.9
43.9
195.5
2018
24.1
6.4
8.2
39.9
94.3
43.9
197.4
Table 118: Regentville BSP – summer demand forecast
Substation Name
Glenmore Park ZS
Luddenham ZS
North Warragamba ZS
Penrith ZS
Penrith TS
Warrimoo TS
Regentville BSP
Forecast
PF
0.993
0.915
0.918
0.997
0.972
0.962
0.978
Actual (MVA)
2012
2013
20.9
20.4
6.5
6.8
7.6
7.4
38.3
35.7
101.8
85.7
50.1
43.9
327.4
187.9
Table 119: Regentville BSP – winter demand forecast
3.2.24.2 REGENTVILLE BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Regentville BSP is at 33kV.
Capacity
(MVA)
Feeder Name
465 Luddenham ZS – Tee
465 Tee – Kemps Creek ZS
933 Mt Druitt TS – Penrith TS
936 Mt Druitt TS – Penrith TS
222 BSP – Penrith TS
238 BSP – Penrith TS
231 BSP – Glenmore Park
232 BSP – Glenmore Park
93E Penrith TS – Warimoo TS
940 Katoomba North TS – Warimoo TS
937 BSP – North Warragamba
21.0
21.0
120.0
120.0
448.0
448.0
172.0
172.0
90.0
90.0
62.0
Actual
(MVA)
2014
12.0
12.0
52.7
52.7
152.3
152.3
36.9
36.9
46.9
46.9
0.0
Forecast (MVA)
2015
12.7
12.7
57.5
57.5
164.0
164.0
42.5
42.5
49.0
49.0
10.1
2016
12.8
12.8
60.3
60.3
170.0
170.0
43.1
43.1
49.3
49.3
10.2
2017
12.8
12.8
61.0
61.0
171.6
171.6
43.8
43.8
49.6
49.6
10.2
2018
12.8
12.8
61.9
61.9
173.5
173.5
44.5
44.5
49.8
49.8
10.2
2019
12.8
12.8
62.5
62.5
175.1
175.1
44.9
44.9
50.0
50.0
10.2
Table 120: Regentville BSP – summer
Network Constraint
Penrith 11kV ZS is forecast to exceed
firm rating transformer cables.
Year
Existing
Glenmore Park ZS is forecast to exceed
its firm capacity.
S2019/20
Investigation
Replacement of the transformer 11kV cables or nonnetwork options. Temporarily install temperature
sensor to allow dynamic rating for the 11kV
transformer cables. Screening test to be conducted to
Load is within acceptable limits. The load will
continue to be monitored. A non-network option will
be investigated. Screening test to be conducted to
Table 121: Regentville BSP – identified limitations
Solution
Investigate
non-network
options
Continue to
monitor
3.2.24.3 REGENTVILLE BSP NETWORK MAP
3.2.25
SHOALHAVEN TRANSMISSION SUBSTATION
3.2.25.1 SHOALHAVEN TS CONNECTION POINTS
Shoalhaven TS is supplied from Dapto BSP via Mt Terry TS by 132kV feeders 98L and 98U. The
Shoalhaven 132kV busbar supplies the West Tomerong TS, Evans Lane and Ulladulla system on
feeders 98J and 98P as well as Essential Energy's Batemans Bay and Moruya North substations.
Shoalhaven TS has three 60MVA 132/33kV transformers giving it a firm rating of 120MVA.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Berry ZS
Bolong ZS
Bomaderry ZS
Culburra ZS
Huskisson ZS
Kangaroo Valley ZS
Nowra ZS
South Nowra ZS
Sussex Inlet ZS
Shoalhaven TS
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 15
1 x 12.5
3 x 15
2 x 10
2 x 20
1 x 5 + 1 x 2.5
2 x 35
2 x 25
1 x 5 + 1 x 15
3 x 60
Installed
Capacity
Total ‘N’
(MVA)
30
12.5
45
20
40
7.5
70
50
20
180
Firm Rating
Secure ‘N-1’
(MVA)
15
NA
30
10
20
2.5
35
25
5
120
95% Peak
Load
Exceeded
(hours)
2.00
6.00
2.75
2.25
7.25
3.25
1.50
6.25
2.50
10.25
Embedded
Generation
(MW)
0.87
0.21
1.88
1.49
1.44
0.24
2.70
0.31
0.87
-
Table 122: Shoalhaven TS – transformer rating and substation details
Substation Name
Berry ZS
Bolong ZS
Bomaderry ZS
Culburra ZS
Huskisson ZS
Kangaroo Valley ZS
Nowra ZS
South Nowra ZS
Sussex Inlet ZS
Shoalhaven TS
Forecast
PF
0.958
0.952
0.951
0.933
0.975
0.966
Actual (MVA)
2013
2014
9.1
6.6
2.8
1.8
21.2
17.6
11.3
8.9
23.0
15.6
2.7
2.4
25.4
21.1
11.0
10.6
6.5
4.8
136.7
109.2
2015
8.0
1.9
19.4
3.0
23.9
78.2
2016
8.1
1.9
19.6
3.0
23.9
81.9
Forecast (MVA)
2017
8.1
1.9
19.7
3.0
23.9
82.1
2018
8.2
1.9
20.0
3.1
23.9
82.4
2019
8.4
1.9
20.3
3.1
23.9
82.9
2014
7.2
2.1
17.0
2.9
20.2
74.4
2015
7.2
2.1
17.0
2.9
20.3
74.5
Forecast (MVA)
2016
7.2
2.1
17.1
2.9
20.3
78.3
2017
7.2
2.1
17.1
2.9
20.3
78.3
2018
7.2
2.1
17.1
2.9
20.3
78.3
Table 123: Shoalhaven TS – summer demand forecast
Substation Name
Berry ZS
Bolong ZS
Bomaderry ZS
Culburra ZS
Huskisson ZS
Kangaroo Valley ZS
Nowra ZS
South Nowra ZS
Sussex Inlet ZS
Shoalhaven TS
Forecast
PF
0.981
0.979
0.978
0.917
0.986
0.981
Actual (MVA)
2012
2013
7.8
7.3
5.0
2.2
15.8
17.6
11.5
9.8
20.4
20.3
3.3
2.8
20.5
19.2
11.3
10.7
6.1
5.3
118.7
118.4
Table 124: Shoalhaven TS – winter demand forecast
3.2.25.2 SHOALHAVEN TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Shoalhaven TS is at 33kV.
Capacity
(MVA)
Feeder Name
7501 TS – Tee
7501/1 7501/2 Tee – Bomaderry
7539 TS – HVC
7516 Bomaderry – Tee 81719
7510 Bomaderry tee – 66737
7535 TS – Tomerong ZS (New)
7512/7513 Tee – Kangaroo Valley
7514/7515 Tee – Berry
7514/1 Tee – HVC
7536 Tee – HVC
7502/7517 TS – Bolong
7176 Berry – Gerringong
7503 TS – Nowra
7506 TS – Nowra
7519 TS – Huskisson (Reconfigured)
7507 TS – South Nowra
7520/7532/7530 TS – Yatte Yattah
7528 TS – Culburra
7542 South Nowra – Culburra
7508 TS – HVC
7518 Tomerong – 33525 Sussex (Reconfig)
7525/7526 Tee – Sussex Inlet
7532 (See 7520)
7523 Tee Sussex – Yatte Yattah
35.2
33.3
46.6
13.3
13.6
55.0
13.3
13.3
13.3
34.9
46.6
16.4
56.2
56.2
20.7
20.9
35.1
14.1
13.3
20.7
20.7
33.3
14.1
14.1
13.3
Actual
(MVA)
2014
22.6
17.6
38.2
2.7
2.4
20.0
2.4
6.6
9.1
32.0
38.2
6.6
21.1
21.1
15.6
15.6
15.4
4.8
9.3
8.9
9.3
4.8
4.8
4.3
4.3
Forecast (MVA)
2015
25.0
19.4
40.8
4.6
3.0
22.5
3.0
8.0
11.0
32.4
40.8
8.0
23.9
23.9
4.7
4.7
15.3
4.9
9.3
8.9
9.3
4.9
4.9
4.3
4.3
2016
25.2
19.6
40.8
4.6
3.0
22.6
3.0
8.1
11.1
32.4
40.8
8.1
23.9
23.9
5.2
5.2
11.8
5.1
9.3
8.9
9.3
5.1
5.1
4.3
4.3
2017
25.3
19.7
40.8
4.6
3.0
22.8
3.0
8.1
11.1
32.4
40.8
8.1
23.9
23.9
6.0
6.0
14.7
5.2
9.3
8.9
9.3
5.2
5.2
4.3
4.3
2018
25.6
20.0
40.8
4.6
3.1
23.0
3.1
8.2
11.2
32.4
40.8
8.2
23.9
23.9
6.0
6.0
14.8
5.3
9.3
8.9
9.3
5.3
5.3
4.3
4.3
2019
26.0
20.3
40.8
4.6
3.1
23.4
3.1
8.4
11.5
32.4
40.8
8.4
23.9
23.9
6.0
6.0
14.9
5.3
9.3
8.9
9.3
5.3
5.3
4.3
4.3
Table 125: Shoalhaven TS – summer
Network Constraint
Kangaroo Valley ZS firm rating is
exceeded.
Year
Existing
Feeders 7514, 7514/1, 7515 & 7516 are
overloaded for an outage of feeder 7510,
Berry ZS.
S2022
Investigation
The situation will continue to be monitored against
network capacity limits. A transformer augmentation
project or alternate non-network options to be
investigated in the future. Demand is below 10 MVA.
The situation will be monitored. Berry ZS can be off
loaded to Feeder 7176. However, this will create a
constraint on feeder 7515. Other options include
network augmentation (PR354) and a screening test
to be conducted to investigate non-network options.
Table 126: Shoalhaven TS – identified limitations
Solution
Continue to
monitor
Continue to
monitor
3.2.25.3 SHOALHAVEN TS NETWORK MAP
3.2.26
SPRINGHILL TRANSMISSION SUBSTATION
3.2.26.1 SPRINGHILL TS CONNECTION POINTS
Springhill Transmission Substation has been rebuilt on the land behind the old transmission substation,
under project TS081. The substation consists of an indoor GIS 132kV busbar as well as indoor 33kV
switchgear. There are three 120MVA 132/33kV transformers that are used to supply the Endeavour
Energy network with a firm capacity of 240MVA. There are also five 60MVA 132/33kV transformers that
supply BlueScope Steel.
Substation
Voltage
Levels
Dapto ZS
Figtree ZS
Inner Harbour ZS
Kembla Grange ZS
Kenny Street ZS
North Wollongong ZS
Port Kembla ZS
South Wollongong ZS
Unanderra ZS
West Wollongong ZS
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
Springhill TS
132/33kV
Transformer
Description
(MVA)
3 x 25
2 x 25
2 x 12.5
2 x 10
2 x 25
2 x 19
3 x 10
2 x 19
3 x 12
1 x 10 + 2 x
12.5
3 x 120
Installed
Capacity
Total ‘N’
(MVA)
75
50
25
20
50
38
30
38
36
35
Embedded
Generation
(MW)
50
25
12.5
10
25
19
20
19
24
22.5
95% Peak
Load
Exceeded
(hours)
1.25
1.50
5.75
1.75
3.00
10.75
8.50
6.50
3.25
1.25
240
6.25
7.25
Firm Rating
Secure ‘N-1’
(MVA)
360
3.51
1.92
0.24
0.02
0.18
0.96
0.30
0.37
0.92
Table 127: Springhill TS – transformer rating and substation details
Substation Name
Dapto ZS
Figtree ZS
Inner Harbour ZS
Kembla Grange ZS
Kenny Street ZS
North Wollongong ZS
Port Kembla ZS
South Wollongong ZS
Unanderra ZS
West Wollongong ZS
Springhill TS
Forecast
PF
0.994
0.963
0.906
0.863
0.903
0.987
0.971
0.962
0.976
0.943
0.972
Actual (MVA)
2013
2014
33.4
26.6
11.5
20.4
9.1
9.1
4.2
4.4
19.4
17.6
12.9
10.8
12.9
9.9
15.7
13.2
23.6
13.0
20.2
9.4
166.5
153.5
2015
28.2
20.3
10.0
4.4
21.5
10.9
10.0
13.5
14.8
8.9
163.9
2016
30.2
20.4
10.0
4.5
21.7
10.9
10.0
14.0
15.9
9.0
167.6
Forecast (MVA)
2017
30.6
20.5
8.8
4.5
21.7
10.9
10.1
14.5
16.4
9.0
180.9
2018
29.1
20.6
8.8
4.5
21.8
10.9
10.3
14.6
16.7
9.2
180.8
2019
29.6
20.7
8.8
4.5
21.8
10.9
10.5
14.7
16.8
9.4
182.8
2014
23.6
19.7
9.3
3.9
17.8
13.1
12.4
13.4
17.7
10.6
2015
24.0
20.4
10.1
3.9
18.0
13.1
12.4
13.6
19.0
10.7
Forecast (MVA)
2016
25.5
20.5
8.9
4.0
18.1
13.1
12.4
13.6
19.8
10.7
2017
23.8
20.6
8.9
4.1
18.1
13.1
12.4
13.6
20.1
10.7
2018
23.9
20.7
8.9
4.1
18.1
13.1
12.4
13.6
20.2
10.7
Table 128: Springhill TS – summer demand forecast
Substation Name
Dapto ZS
Figtree ZS
Inner Harbour ZS
Kembla Grange ZS
Kenny Street ZS
North Wollongong ZS
Port Kembla ZS
South Wollongong ZS
Unanderra ZS
West Wollongong ZS
Forecast
PF
0.998
0.900
0.921
0.994
0.917
0.998
0.981
0.979
0.997
0.977
Actual (MVA)
2012
2013
23.6
24.1
18.7
9.8
9.3
4.6
3.9
15.6
14.9
11.6
12.5
15.0
13.2
14.4
12.7
25.4
16.5
16.9
11.2
Table 129: Springhill TS – winter demand forecast
3.2.26.2 SPRINGHILL TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Springhill TS is at 33kV.
Capacity
(MVA)
Feeder Name
7001 TS – HVC
7002 TS – HVC
7010 TS – Port Kembla
7013 TS – Port Kembla
7321 Port Central – Port Kembla
7012 TS – Unanderra
7016 TS – Unanderra
7017/ 7117 TS – Kembla Grange
7018 BSP – South Wollongong
7011 South Wollongong – Kenny St
7019 TS – Inner Harbour
7113 Inner Harbour – South Wollongong
7115 South Wollongong – Kenny St
7014 TS – West Wollongong
7015 West Wollongong – Figtree
7142 West Wollongong – North Wollongong
7111 North Wollongong – Kenny St
7091 Figtree – HVC
7120 Unanderra – Dapto
7341 Dapto – Kembla Grange
33.3
46.6
19.7
19.7
16.0
44.4
33.2
33.2
41.4
28.6*
28.6*
22.9*
28.6*
28.6*
46.3
28.6
28.6*
21.3
33.2
32.1
Actual
(MVA)
2014
32.5
32.5
9.9
9.9
0.0
13.0
13.0
4.4
27.8
20.6
15.1
6.0
17.6
6.5
8.3
4.1
1.1
13.2
26.6
4.4
Forecast (MVA)
2015
32.9
32.9
10.0
10.0
0.0
14.8
14.8
4.4
31.7
24.7
16.1
6.1
21.5
13.7
7.9
15.1
12.0
12.6
28.2
4.4
2016
32.9
32.9
10.0
10.0
0.0
15.9
15.9
4.5
32.3
25.0
16.4
6.4
21.7
13.8
7.9
15.2
12.0
12.6
30.2
4.5
2017
32.9
32.9
10.1
10.1
0.0
16.4
16.4
4.5
32.8
25.1
15.4
6.6
21.7
13.8
8.0
15.4
12.0
12.6
30.6
4.5
2018
32.9
32.9
10.3
10.3
0.0
16.7
16.7
4.5
32.9
25.2
15.5
6.7
21.8
13.9
8.1
15.4
12.0
12.6
29.1
4.5
2019
32.9
32.9
10.5
10.5
0.0
16.8
16.8
4.5
33.0
25.2
15.5
6.7
21.8
14.1
8.3
15.5
12.1
12.6
29.6
4.5
Table 130: Springhill TS – summer *Feeder rating limited by the current transformers in the switchgear
Network Constraint
Outage of feeder 7002 overloads feeder
7001.
Year
S2015
Investigation
The load on 7001 is dedicated to a HV customer
93013 (Lysaghts). A solution to the constraint will be
negotiated with the private customer should they wish
to improve their supply security.
Table 131: Springhill TS – identified limitations
Solution
Continue to
monitor
3.2.26.3 SPRINGHILL TS NETWORK MAP
3.2.27
SYDNEY NORTH BULK SUPPLY POINT
3.2.27.1 SYDNEY NORTH BSP CONNECTION POINTS
Sydney North Bulk Supply Point is owned by TransGrid and has five 375 MVA 330/132kV transformers.
Both Endeavour Energy and Ausgrid take supply at 132kV from this BSP. Kellyville and Kenthurst zone
substations are normally supplied from Sydney North while Carlingford TS is capable of being supplied
from Sydney North under contingency conditions, subject to rearrangement of the Ausgrid system.
Substation
Kellyville ZS
Kenthurst ZS
Voltage
Levels
Transformer
Description
(MVA)
33/11kV
66/11kV &
33/11kV
2 x 25
1 x 25(33kV) +
1 x 25(66kV)
Installed
Capacity
Total ‘N’
(MVA)
50
50
Firm Rating
Secure ‘N-1’
(MVA)
25
25
95% Peak
Load
Exceeded
(hours)
5.00
5.25
Embedded
Generation
(MW)
1.42
0.81
Table 132: Sydney North BSP – transformer rating and substation details
Substation Name
Kellyville ZS
Kenthurst ZS
Sydney North BSP
Forecast
PF
0.978
0.971
0.995
Actual (MVA)
2013
2014
22.2
19.1
22.2
21.4
30.5
41.3
2015
21.0
17.6
34.8
2016
21.0
17.6
34.9
Forecast (MVA)
2017
21.1
17.6
34.9
2018
21.1
17.6
34.9
2019
21.1
17.6
34.9
2014
14.0
13.9
27.9
2015
14.0
13.9
27.9
Forecast (MVA)
2016
14.0
13.9
27.9
2017
14.0
13.9
27.9
2018
14.0
13.9
27.9
Table 133: Sydney North BSP – summer demand forecast
Substation Name
Kellyville ZS
Kenthurst ZS
Sydney North BSP
Forecast
PF
0.993
0.992
0.995
Actual (MVA)
2012
2013
14.3
13.1
16.8
17.7
31.5
30.5
Table 134: Sydney North BSP – winter demand forecast
3.2.27.2 SYDNEY NORTH BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Sydney North BSP is at 132kV.
Capacity
(MVA)
Feeder Name
221 BSP – Kenthurst
476 Kenthurst – Kellyville
128.0
19.0
Actual
(MVA)
2014
40.4
19.1
Forecast (MVA)
2015
38.5
21.0
2016
38.6
21.0
2017
38.7
21.1
2018
38.7
21.1
2019
38.7
21.1
Table 135: Sydney North BSP – summer
Network Constraint
The thermal capacity of feeder 476 to
Kellyville is exceeded under normal
operating conditions.
Year
2014/15
Investigation
Supply half of the Kellyville load from Baulkham Hills
to avoid overloads on feeder 476 on peak demand
days. Additional load will be transferred to Mungerie
Park ZS.
Investigate contingency ratings.
Table 136: Sydney North BSP – identified limitations
Solution
Utilise transfer
capacity
3.2.27.3 SYDNEY NORTH BSP NETWORK MAP
3.2.28
SYDNEY WEST BULK SUPPLY POINT
3.2.28.1 SYDNEY WEST BSP CONNECTION POINTS
Sydney West Bulk Supply Point is owned by TransGrid and presently has five 375 MVA 330/132kV
transformers installed, providing a firm capacity of 1,500MVA. Endeavour Energy is supplied at 132kV
from Sydney West BSP.
Transformer
Description
(MVA)
Substation
Voltage
Levels
Arndell Park ZS
Baulkham Hills ZS
Bringelly ZS
Doonside ZS
Eastern Creek ZS
Huntingwood ZS
Mamre ZS
North Eastern Creek ZS
North Parramatta ZS
Oran Park ZS (proposed)
Quakers Hill ZS
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
Rooty Hill ZS
West Wetherill Park ZS
Wetherill Park ZS
Baulkham Hills TS
Blacktown TS
Camellia TS
Carlingford TS
Guildford TS
Mount Druitt TS
Nepean TS 33kV
Nepean TS 66kV
West Wetherill Park TS
132/11kV
132/11kV
132/11kV
132/33kV
132/33kV
132/33kV
132/33kV
132/33kV
132/33kV
132/33kV
132/66kV
132/33kV
90
90
44
135
90
90
135
90
110
20
95
Firm
Rating
Secure ‘N1’
(MVA)
45
45
19
90
45
45
90
45
55
20
50
90
90
90
240
480
360
480
240
360
180
240
120
45
45
45
180
360
240
360
180
240
120
120
NA
Installed
Capacity
Total ‘N’
(MVA)
2 x 45
2 x 45
1 x 19 + 1 x 25
3 x 45
2 x 45
2 x 45
3 x 45
2 x 45
2 x 55
1 x 20
2 x 25(33kV) + 1 x
45(132kV)
2 x 45
2 x 45
2 x 45
4 x 60
4 x 120
3 x 120
4 x 120
4 x 60
3 x 120
3 x 60
2 x 120
1 x 120
95% Peak
Load
Exceeded
(hours)
Embedded
Generation
(MW)
12.00
3.00
11.00
5.75
21.75
15.50
1.25
0.75
4.50
3.50
9.00
1.21
2.30
0.56
5.75
0.01
1.92
0.57
2.83
6.50
0.25
0.50
12.00
3.75
17.50
2.25
14.50
1.50
0.25
0.25
3.00
0.26
-
Table 137: Sydney West BSP – transformer rating and substation details
Substation Name
Arndell Park ZS
Baulkham Hills ZS
Bringelly ZS
Doonside ZS
Eastern Creek ZS
Huntingwood ZS
Mamre ZS
North Parramatta ZS
Oran Park ZS
Quakers Hill ZS
Rooty Hill ZS
Wetherill Park ZS
Baulkham Hills TS
Blacktown TS
Camellia TS
Carlingford TS
Guildford TS
Mount Druitt TS
Nepean TS
Sydney West BSP
Forecast
PF
0.986
0.924
0.991
0.958
0.977
0.900
0.966
0.955
0.900
0.975
0.990
0.902
0.979
0.995
0.982
0.980
0.979
0.949
0.991
0.992
Actual (MVA)
2013
2014
44.3
38.9
33.7
30.4
13.2
13.5
17.0
15.6
8.9
33.0
32.3
11.8
9.1
37.9
33.9
1.6
5.6
42.1
35.4
40.2
35.1
33.8
32.0
30.7
29.2
141.8
112.1
269.4
244.0
122.3
95.5
220.5
195.8
231.3
207.3
126.6
158.0
447.8
467.5
1522.6
1391.2
Table 138: Sydney West BSP – summer demand forecast
2015
28.2
35.2
12.6
41.1
18.2
31.1
49.3
9.4
6.7
38.1
35.4
33.1
30.6
110.7
219.8
230.3
160.9
452.1
43.2
1150.4
2016
28.2
36.0
12.6
41.2
18.2
32.4
50.1
9.4
10.4
38.9
35.5
33.5
30.6
111.8
222.9
231.4
163.9
460.1
39.1
1161.5
Forecast (MVA)
2017
2018
28.2
28.2
36.1
36.1
11.9
11.9
41.2
41.2
18.2
18.2
33.2
33.8
50.1
50.1
9.4
9.4
39.0
39.0
35.6
35.7
33.5
33.5
30.6
30.6
112.5
112.9
224.9
225.5
238.3
231.1
166.4
167.6
450.5
452.3
39.2
39.2
1164.8
1161.6
2019
28.2
36.2
11.9
41.2
18.2
35.5
50.1
9.4
39.0
35.8
33.5
30.6
113.1
225.7
234.2
168.0
471.2
39.3
1182.8
Substation Name
Arndell Park ZS
Baulkham Hills ZS
Bringelly ZS
Doonside ZS
Eastern Creek ZS
Granville ZS
Huntingwood ZS
Mamre ZS
North Parramatta ZS
Oran Park ZS
Quakers Hill ZS
Rooty Hill ZS
Wetherill Park ZS
Baulkham Hills TS
Blacktown TS
Camellia TS
Carlingford TS
Guildford TS
Mount Druitt TS
Nepean TS
Sydney West BSP
Forecast
PF
0.995
0.924
0.989
0.976
0.980
0.900
0.990
0.992
0.994
0.994
0.900
0.979
0.987
0.994
0.968
0.997
0.994
0.999
Actual (MVA)
2012
2013
34.3
32.2
24.6
24.4
10.2
10.4
14.7
13.0
17.7
23.7
23.0
4.5
7.3
28.8
27.4
3.3
3.2
31.0
25.7
29.6
27.0
31.1
30.2
30.3
31.1
152.1
115.3
186.3
191.2
167.0
80.3
186.3
187.4
184.3
181.1
115.8
127.8
57.3
60.0
1300.1
1165.1
Table 139: Sydney West BSP – winter demand forecast
2014
21.0
26.7
10.6
33.9
15.0
18.7
25.1
8.2
22.1
21.0
30.2
30.2
118.1
160.3
173.9
113.2
19.0
855.9
2015
21.0
26.7
8.7
34.2
15.4
18.7
37.2
10.5
23.2
21.8
31.1
31.9
120.4
163.7
180.7
115.1
20.7
887.9
Forecast (MVA)
2016
21.0
26.7
8.0
34.2
15.4
18.7
37.2
11.7
23.2
21.9
31.7
31.9
120.9
164.2
184.8
118.1
20.7
897.0
2017
21.0
26.7
8.0
34.2
15.4
18.7
37.2
12.2
23.2
21.9
32.6
31.9
121.3
164.5
178.1
120.2
20.7
895.3
2018
21.0
26.7
8.0
34.2
15.4
18.7
37.2
12.2
23.2
22.0
33.2
31.9
121.6
164.5
179.5
120.8
20.7
899.8
3.2.28.2 SYDNEY WEST BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Sydney West BSP is at 132kV.
Capacity
(MVA)
Feeder Name
93A BSP – Blacktown TS
93Z BSP – Blacktown TS
9J1 BSP – Blacktown TS
9J2 BSP – Blacktown TS
239 TS – Tee
239 Tee Doonside
239 Tee Arndell
220 TS – Tee
220 Tee1 –Tee2
220 Tee HVC
239 Tee Rooty Hill
220 Tee Arndell
233 Union St – Camellia
237 Sydney West – HVC
9J3 Blacktown TS – Baulkham Hills TS
9J4 Blacktown TS – Baulkham Hills TS
930 Baulkham Hills TS – Carlingford TS
931 Baulkham Hills TS – Carlingford TS
212 Vineyard BSP – Baulkham Hills TS
229 Parklea – WCH
217 Sydney West – Nth Eastern Creek
218 Sydney West – Eastern Creek
93F Holroyd – Guildford
93F Holroyd – Guildford
93L Holroyd – Guildford
93M Sydney West – West Wetherill
93T West Wetherill – Tee
93T Tee Wetherill
93T Tee – Guildford
9J8 Guildford – Camellia
93J Sydney West – Tee
93J Tee Wetherill
93J Tee – Guildford
233 Union St – Camellia
228 Guildford – Union St
505.0
505.0
505.0
505.0
153.0
130.0
80.0
153.0
130.0
130.0
76.0
80.0
111.0
120.0
512.0
512.0
512.0
512.0
172.0
145.0
172.0
172.0
505.0
505.0
505.0
505.0
505.0
120.0
505.0
117.0
505.0
120.0
505.0
111.0
111.0
Actual
(MVA)
2014
264.6
264.6
220.4
220.4
74.4
35.4
38.9
74.0
35.1
19.0
35.1
38.9
35.1
81.5
308.0
308.0
195.8
195.8
37.5
36.6
15.6
15.6
95.5
95.5
0.0
29.2
29.2
29.2
0.0
129.5
158.6
103.3
129.5
33.9
33.9
Forecast (MVA)
2015
356.8
356.8
297.3
297.3
66.3
38.1
28.2
63.6
35.4
19.0
35.4
28.2
35.4
83.1
376.3
376.3
230.3
230.3
49.6
39.6
18.2
18.2
49.4
49.4
229.6
293.3
260.2
30.6
229.6
78.3
108.9
104.8
78.3
28.9
28.9
2016
351.5
351.5
292.9
240.8
67.1
38.9
41.7
63.7
35.5
20.0
35.5
28.2
35.5
83.1
379.1
379.1
231.4
231.4
41.7
39.7
18.2
18.2
51.8
51.8
210.2
274.3
240.8
30.6
210.2
83.1
113.7
105.5
83.1
31.3
31.3
2017
355.6
355.6
296.3
243.8
67.2
39.0
41.8
63.9
35.6
20.0
35.6
28.2
35.6
83.1
386.8
386.8
238.3
238.3
41.8
39.7
18.2
18.2
51.8
51.8
210.4
274.6
241.0
30.6
210.4
85.1
115.7
106.3
85.1
33.3
33.3
2018
353.3
353.3
294.4
241.7
67.2
39.0
41.8
63.9
35.7
20.0
35.7
28.2
35.7
83.1
380.1
380.1
231.1
231.1
41.8
39.7
18.2
18.2
51.8
51.8
210.7
274.9
241.3
30.6
210.7
85.2
115.8
107.2
85.2
33.4
33.4
2019
354.8
354.8
295.6
242.9
67.2
39.0
41.8
64.0
35.8
20.0
35.8
28.2
35.8
83.1
383.5
383.5
234.2
234.2
41.8
39.7
18.2
18.2
51.8
51.8
210.8
275.0
241.4
30.6
210.8
85.3
115.9
108.0
85.3
33.5
33.5
Table 140: Sydney West BSP – summer
Network Constraint
Nil
Year
Investigation
Table 141: Sydney West BSP – identified limitations
Solution
3.2.28.3 SYDNEY WEST BSP NETWORK MAP
3.2.29
VINEYARD BULK SUPPLY POINT
3.2.29.1 VINEYARD BSP CONNECTION POINTS
Vineyard Bulk Supply Point is owned by TransGrid and has three 375 MVA 330/132kV transformers
installed, providing a firm capacity of 750MVA. Endeavour Energy is supplied at 132kV from Vineyard
BSP.
Substation
Bella Vista ZS
Cheriton Avenue ZS
Marsden Park ZS (proposed)
Mungerie Park ZS
Parklea ZS
Schofields ZS
South Marsden Park ZS
(proposed)
West Castle Hill ZS
Hawkesbury TS
Voltage
Levels
Transformer
Description
(MVA)
Installed
Capacity
Total ‘N’
(MVA)
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
132/11kV
3 x 45
2 x 45
1 x 45
3 x 45
3 x 45
2 x 45
1 x 15
135
90
45
135
135
90
15
Firm
Rating
Secure ‘N1’
(MVA)
90
45
NA
90
90
45
NA
132/11kV
132/33kV
2 x 65
3 x 120
130
360
65
240
95% Peak
Load
Exceeded
(hours)
Embedded
Generation
(MW)
2.75
0.75
5.25
7.75
11.25
-
2.82
1.63
2.58
7.60
1.15
-
2.75
11.00
8.98
-
Table 142: Vineyard BSP – transformer rating and substation details
Substation Name
Bella Vista ZS
Cheriton Avenue ZS
Marsden Park ZS
Mungerie Park ZS
Parklea ZS
Schofields ZS
West Castle Hill ZS
Hawkesbury TS
Vineyard BSP
Forecast
PF
0.992
0.996
0.900
0.950
0.975
0.900
0.900
0.929
0.991
0.960
Actual (MVA)
2013
2014
55.7
37.5
30.4
24.4
44.6
38.4
88.2
70.7
17.6
15.4
38.9
36.6
150.5
135.8
418.9
373.6
Table 143: Vineyard BSP – summer demand forecast
2015
49.6
28.3
0.3
47.1
82.7
27.1
2.3
39.6
161.1
428.3
2016
41.7
38.7
4.3
48.1
83.6
29.2
5.1
39.7
158.8
439.7
Forecast (MVA)
2017
41.8
34.4
6.3
49.2
84.2
31.3
10.7
39.7
161.2
449.4
2018
41.8
34.4
9.6
50.1
84.9
33.6
15.0
39.7
162.2
462.4
2019
41.8
38.0
13.6
51.1
85.6
36.0
18.0
39.7
163.6
494.9
Substation Name
Bella Vista ZS
Cheriton Avenue ZS
Marsden Park ZS
Mungerie Park ZS
Parklea ZS
Schofields ZS
West Castle Hill ZS
Hawkesbury TS
Vineyard BSP
Forecast
PF
0.999
0.996
0.996
0.999
0.900
0.963
0.994
0.977
Actual (MVA)
2012
2013
37.5
35.0
21.3
23.0
21.5
48.9
45.4
12.0
37.6
23.1
118.9
102.4
269.1
261.8
2014
34.2
27.4
23.8
47.7
17.2
22.4
111.7
272.4
Forecast (MVA)
2016
34.9
42.9
3.3
26.4
50.4
18.8
3.2
22.4
112.3
300.7
2015
43.7
40.0
2.9
25.4
48.9
19.5
22.4
111.5
300.9
2017
34.9
34.0
4.0
27.5
52.2
19.4
11.1
22.4
113.0
307.3
2018
34.9
36.9
5.0
28.8
54.2
20.1
11.8
22.4
113.5
317.7
Table 144: Vineyard BSP – winter demand forecast
3.2.29.2 VINEYARD BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Vineyard BSP is at 132kV.
Capacity
(MVA)
Feeder Name
9JA Vineyard to Rouse Hill
938 Vineyard to Rouse Hill
21M Rouse Hill to Mungerie Park
21P Rouse Hill to Mungerie Park
214 Rouse Hill – Parklea
215 Rouse Hill – Parklea
227 Vineyard to Hawkesbury
234 Vineyard to Hawkesbury
213 Parklea – Bella
230 Parklea – WCH
500.0
500.0
172.0
172.0
172.0
172.0
230.0
230.0
172.0
85.0
Actual
(MVA)
2014
109.1
109.1
38.4
38.4
108.2
108.2
135.8
135.8
37.5
36.6
Forecast (MVA)
2015
129.8
129.8
47.1
47.1
132.3
132.3
161.1
161.1
49.6
39.6
2016
131.7
131.7
48.1
48.1
125.2
125.2
158.8
158.8
41.7
39.7
2017
133.4
133.4
49.2
49.2
126.0
126.0
161.2
161.2
41.8
39.7
2018
135.0
135.0
50.1
50.1
126.7
126.7
162.2
162.2
41.8
39.7
2019
136.7
136.7
51.1
51.1
127.4
127.4
163.6
163.6
41.8
39.7
Table 145: Vineyard BSP – summer
Network Constraint
The firm rating of Schofields ZS will be
exceeded by S2022.
Year
S2022
Investigation
Continue to monitor lot releases uptake and load
growth. Screening test to be conducted to investigate
non-network options.
Table 146: Vineyard BSP – identified limitations
Solution
Continue to
Monitor
3.2.29.3 VINEYARD BSP NETWORK MAP
3.2.30
WALLERAWANG BULK SUPPLY POINT
3.2.30.1 WALLERAWANG BSP CONNECTION POINTS
Wallerawang Bulk Supply Point is owned by TransGrid and provides supply to both Endeavour Energy
and Essential Energy at both 66kV and 132kV. The 132kV busbar is supplied via two 330/132kV
375MVA transformers, which in turn supply the 66kV busbar through two 132/66kV 60MVA transformers.
The Wallerawang 132kV is winter peaking.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Lithgow ZS
Meadow Flat ZS
Portland ZS
Katoomba North TS
Lawson TS
66/11kV
66/11kV
66/11kV
132/66kV
132/66kV
1 x 30 + 1 x 35
1 x 2.5
2 x 10
2 x 60
2 x 52
Installed
Capacity
Total ‘N’
(MVA)
65
2.5
20
120
104
Firm Rating
Secure ‘N-1’
(MVA)
30
NA
10
60
52
95% Peak
Load
Exceeded
(hours)
2.25
3.50
1.00
1.50
0.75
Embedded
Generation
(MW)
1.44
0.08
0.39
-
Table 147: Wallerawang BSP – transformer rating and substation details
Substation Name
Lithgow ZS
Meadow Flat ZS
Portland ZS
Katoomba North TS
Lawson TS
Wallerawang BSP
Forecast
PF
0.989
0.999
0.998
0.969
0.985
0.938
Actual (MVA)
2013
2014
15.9
12.5
0.7
0.7
2.8
3.1
23.3
21.4
23.7
26.5
100.8
78.0
2015
12.9
0.7
3.1
24.4
22.7
68.1
2016
13.0
0.7
3.1
24.4
22.7
68.1
Forecast (MVA)
2017
13.2
0.7
3.1
24.4
22.7
68.3
2018
13.3
0.7
3.1
24.4
22.7
68.4
2019
13.3
0.7
3.1
24.4
22.7
68.4
2014
16.1
1.0
3.7
29.9
22.2
79.4
2015
16.2
1.0
3.7
29.9
22.3
79.6
Forecast (MVA)
2016
16.3
1.0
3.7
29.9
22.3
79.7
2017
16.4
1.0
3.7
29.9
22.3
79.8
2018
16.5
1.0
3.7
29.9
22.3
79.9
Table 148: Wallerawang BSP – summer demand forecast
Substation Name
Lithgow ZS
Meadow Flat ZS
Portland ZS
Katoomba North TS
Lawson TS
Wallerawang BSP
Forecast
PF
0.989
0.995
0.997
0.961
0.985
0.952
Actual (MVA)
2012
2013
20.1
16.2
0.9
1.0
3.5
3.7
38.0
30.4
19.4
22.8
99.7
105.9
Table 149: Wallerawang BSP – winter demand forecast
3.2.30.2 WALLERAWANG BSP SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Wallerawang BSP is at 66kV and 132kV.
Capacity
(MVA)
Feeder Name
823 TS – Portland
817 TS – Meadow Flat
85X TS – Lithgow
857 TS – Lithgow
811/1 Blackmans Flat ZS – Tee
811/1 Blackmans Flat ZS Tee – HVC
811/2 Tee – HVC
940 BSP – Tee
940 Tee – Katoomba Nth
940 Tee – Warrimoo
941 BSP – Tee
941 Tee – Katoomba North
941 Katoomba North – Lawson
942 Lawson TS – Penrith TS
27.0
21.0
40.0
45.0
80.0
80.0
45.0
102.0
160.0
90.0
109.0
219.0
109.0
90.0
Actual
(MVA)
2014
3.1
0.7
14.1
14.1
20.2
15.6
4.6
57.6
21.4
46.9
47.8
21.4
26.5
26.5
Forecast (MVA)
2015
3.1
0.7
14.8
14.8
20.0
15.2
4.9
61.2
24.4
49.0
47.1
24.4
22.7
22.7
2016
3.1
0.7
14.9
14.9
20.0
15.2
4.9
61.5
24.4
49.3
47.1
24.4
22.7
22.7
2017
3.1
0.7
15.1
15.1
20.0
15.2
4.9
61.8
24.4
49.6
47.1
24.4
22.7
22.7
2018
3.1
0.7
15.2
15.2
20.0
15.2
4.9
62.0
24.4
49.8
47.1
24.4
22.7
22.7
2019
3.1
0.7
15.2
15.2
20.0
15.2
4.9
62.2
24.4
50.0
47.1
24.4
22.7
22.7
Table 150: Wallerawang BSP – summer
Network Constraint
Nil
Year
Investigation
Table 151: Wallerawang BSP – identified limitations
Solution
3.2.30.3 WALLERAWANG BSP NETWORK MAP
3.2.31
WARRIMOO TRANSMISSION SUBSTATION
3.2.31.1 WARRIMOO TS CONNECTION POINTS
Warrimoo TS has two 60MVA 132/66/11kV auto-transformers, providing a firm capacity of 60MVA.
There is no provision for additional transformers. The Warrimoo transmission network supplies Blaxland
ZS on tail-ended transformers via feeders 822 and 827.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Blaxland ZS
Springwood ZS
Warrimoo TS
33/11kV
33/11kV
132/33kV
2 x 35
2 x 35
2 x 60
Installed
Capacity
Total ‘N’
(MVA)
70
70
120
Firm Rating
Secure ‘N-1’
(MVA)
35
35
120
95% Peak
Load
Exceeded
(hours)
5.75
5.00
1.25
Embedded
Generation
(MW)
2.22
2.84
-
Table 152: Warrimoo TS – transformer rating and substation details
Substation Name
Blaxland ZS
Springwood ZS
Warrimoo TS
Forecast
PF
0.945
0.958
0.926
Actual (MVA)
2013
2014
25.7
22.8
26.4
22.6
53.8
46.9
2015
24.2
23.4
49.0
2016
24.4
23.6
49.3
Forecast (MVA)
2017
24.5
23.7
49.6
2018
24.7
23.8
49.8
2019
24.8
23.9
50.0
2014
18.7
24.4
43.9
2015
18.7
24.4
43.9
Forecast (MVA)
2016
18.7
24.4
43.9
2017
18.7
24.4
43.9
2018
18.7
24.4
43.9
Table 153: Warrimoo TS – summer demand forecast
Substation Name
Blaxland ZS
Springwood ZS
Warrimoo TS
Forecast
PF
0.974
0.988
0.962
Actual (MVA)
2012
2013
19.7
18.3
23.8
23.6
50.1
43.9
Table 154: Warrimoo TS – winter demand forecast
3.2.31.2 WARRIMOO TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from Warrimoo TS is at 66kV.
Capacity
(MVA)
Feeder Name
808 Hazelbrook – Springwood
824 TS – Springwood
826 TS – Hazelbrook
822 TS – Blaxland
827 TS – Blaxland
22.0
45.0
50.0
30.0
42.0
Actual
(MVA)
2014
10.0
32.5
32.5
22.8
22.8
Forecast (MVA)
2015
10.3
33.7
33.7
24.2
24.2
2016
10.3
33.8
33.8
24.4
24.4
2017
10.3
34.0
34.0
24.5
24.5
2018
10.3
34.1
34.1
24.7
24.7
2019
10.3
34.2
34.2
24.8
24.8
Table 155: Warrimoo TS – summer
Network Constraint
Thermal capacity of standby feeder 808
is exceeded when supplying Springwood
ZS during outage of Feeder 824.
Year
S2015
Investigation
Load transfer at 11kV from Springwood ZS to
Blaxland ZS and Hazelbrook ZS under emergency.
Distribution works will be required for this load
transfer to be permanent.
Solution
Transfer
capacity
Investigate
non-network
options
Table 156: Warrimoo TS – identified limitations
3.2.31.3 WARRIMOO TS NETWORK MAP
3.2.32
WEST LIVERPOOL TRANSMISSION SUBSTATION
3.2.32.1 WEST LIVERPOOL TS CONNECTION POINTS
West Liverpool TS has four 120MVA 132/33kV transformers providing a firm capacity of 360MVA. Three
of the four transformers will need to be replaced as part of the end of life renewal program. West
Liverpool TS is supplied from TransGrid’s Liverpool Bulk Supply Point at 132kV by three 375MVA tailended transformers and feeders 93B, 93N and 93R. Mutual backup between Sydney West BSP and
West Liverpool TS is supplied via 132kV feeders 93U and 93W.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Anzac Village ZS
Bonnyrigg ZS
Canley Vale ZS
Edmondson Park ZS (proposed)
Hinchinbrook ZS
Homepride ZS
Kemps Creek ZS
Prestons ZS
West Liverpool ZS
West Liverpool TS
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
3 x 25
3 x 35
3 x 25
2 x 35
3 x 25
3 x 25
2 x 25
3 x 25
3 x 35
4 x 120
Installed
Capacity
Total ‘N’
(MVA)
75
105
75
105
75
75
50
75
105
480
Firm Rating
Secure ‘N-1’
(MVA)
50
70
50
70
50
50
25
50
70
360
95% Peak
Load
Exceeded
(hours)
12.00
4.50
7.25
5.50
0.00
3.50
5.25
7.75
7.50
Embedded
Generation
(MW)
1.97
5.03
2.86
3.25
0.55
0.41
2.54
2.08
-
Table 157: West Liverpool TS – transformer rating and substation details
Substation Name
Anzac Village ZS
Bonnyrigg ZS
Canley Vale ZS
Edmondson Park ZS
Hinchinbrook ZS
Homepride ZS
Kemps Creek ZS
Prestons ZS
West Liverpool ZS
West Liverpool TS
Forecast
PF
0.968
0.964
0.954
0.969
0.972
0.934
0.977
0.989
Actual (MVA)
2013
2014
29.1
51.0
46.1
25.8
26.4
40.7
38.4
32.9
33.4
13.8
12.0
34.4
23.7
33.2
31.5
251.5
198.9
2015
48.4
26.5
44.5
34.8
12.7
26.5
35.0
195.6
2016
28.1
26.6
8.4
44.2
35.2
12.8
19.3
36.3
180.3
Forecast (MVA)
2017
29.2
26.7
9.3
45.1
35.8
12.8
23.4
37.2
187.4
2018
30.4
26.8
10.3
45.8
36.3
12.8
24.3
37.5
191.4
2019
31.4
26.8
11.2
46.1
37.0
12.8
24.8
37.5
194.4
2014
11.2
21.9
26.3
27.5
9.6
20.5
30.2
134.3
2015
12.1
21.9
27.0
27.7
9.6
20.4
31.5
137.1
Forecast (MVA)
2016
12.9
21.9
2.6
27.6
28.1
11.3
18.6
32.4
141.6
2017
13.7
21.9
3.1
28.1
28.5
11.3
19.2
33.0
144.5
2018
14.5
21.9
3.8
28.4
28.9
11.3
19.5
33.2
147.0
Table 158: West Liverpool TS – summer demand forecast
Substation Name
Anzac Village ZS
Bonnyrigg ZS
Canley Vale ZS
Edmondson Park ZS
Hinchinbrook ZS
Homepride ZS
Kemps Creek ZS
Prestons ZS
West Liverpool ZS
West Liverpool TS
Forecast
PF
0.996
1.000
0.951
0.991
0.983
0.978
0.995
0.992
Actual (MVA)
2012
2013
20.7
21.2
36.0
31.8
23.1
22.6
24.3
22.9
23.2
24.9
11.6
9.7
20.9
18.8
26.9
27.4
184.9
179.5
Table 159: West Liverpool TS – winter demand forecast
3.2.32.2 WEST LIVERPOOL TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from West Liverpool TS is at 33kV.
Capacity
(MVA)
Feeder Name
525 TS – Hinchinbrook
527 TS – Hinchinbrook
524 TS – Prestons
505 TS – Tee
505 Tee Prestons
505 Tee Casula
504 TS – Moorebank
516 TS – Moorebank
TS – Liverpool ZS (reconfigured)
TS – Liverpool ZS (reconfigured)
503 TS – Bonnyrigg
514 TS – Bonnyrigg
522 TS – Canley Vale
523 Homepride – New Canley Vale
509 TS – Homepride
517 TS – Tee – Homepride
512 TS – Tee
512 Tee – Bringelly
512 Tee – Kemps Creek
465 Luddenham ZS – Kemps Creek
68.0
68.0
68.0
42.0
68.0
42.0
42.0
42.0
42.0
42.0
42.0
42.0
34.0
46.7
42.0
36.0
44.0
21.0
21.0
21.0
Actual
(MVA)
2014
38.4
38.4
23.7
23.7
23.7
18.9
34.4
34.4
17.3
17.2
32.3
32.3
26.4
26.4
33.4
23.4
25.5
13.5
12.0
8.6
Forecast (MVA)
2015
44.5
44.5
26.5
26.5
26.5
28.8
26.2
26.2
16.7
13.1
33.9
33.9
26.5
26.5
34.8
24.4
25.3
12.6
12.7
9.5
2016
44.2
44.2
19.3
19.3
19.3
25.4
26.2
26.2
16.3
13.1
19.7
19.7
26.6
26.6
35.2
24.7
25.4
12.6
12.8
9.5
2017
45.1
45.1
23.4
23.4
23.4
26.3
26.2
26.2
16.6
13.1
20.4
20.4
26.7
26.7
35.8
25.0
24.7
11.9
12.8
9.5
2018
45.8
45.8
24.3
24.3
24.3
27.7
26.2
26.2
16.9
13.1
21.3
21.3
26.8
26.8
36.3
25.4
24.7
11.9
12.8
9.5
2019
46.1
46.1
24.8
24.8
24.8
29.2
26.2
26.2
17.3
13.1
22.0
22.0
26.8
26.8
37.0
25.9
24.7
11.9
12.8
9.5
Table 160: West Liverpool TS – summer
Network Constraint
Nil
Year
Investigation
Table 161: West Liverpool TS – identified limitations
Solution
3.2.32.3 WEST LIVERPOOL TS NETWORK MAP
3.2.33
WEST TOMERONG TRANSMISSION SUBSTATION
3.2.33.1 WEST TOMERONG TS CONNECTION POINTS
West Tomerong TS is located off Blackbutt Range Road Tomerong within the easement of 132kV line
98P (formerly 98M/1) and was commissioned in various stages throughout 2014. It is supplied from
Dapto BSP via Mount Terry TS 132kV feeders 98L and 98U and subsequently supplied via Shoalhaven
TS feeder 98P. A 132kV closed loop is provided through line 28P (West Tomerong to Evans Lane) and
98J (Shoalhaven to Evans Lane). Refer to the Dapto BSP chapter and Geographic drawing for details.
West Tomerong TS has two 60MVA 132/33kV transformers providing a firm rating of 60MVA.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Culburra ZS
Huskisson ZS
South Nowra ZS
Sussex Inlet ZS
Tomerong ZS (proposed)
Yatte Yattah ZS
West Tomerong TS
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
33/11kV
132/33kV
2 x 10
2 x 20
2 x 25
2 x 5 + 1 x 15
2 x 15
1 x 6.5
2 x 60
Installed
Capacity
Total ‘N’
(MVA)
20
40
50
20
30
6.5
120
Firm Rating
Secure ‘N-1’
(MVA)
10
20
25
5
15
NA
60
95% Peak
Load
Exceeded
(hours)
2.25
7.25
6.25
2.50
0.50
2.75
Embedded
Generation
(MW)
1.49
1.44
0.31
0.87
0.47
-
Table 162: West Tomerong TS – transformer rating and substation details
Substation Name
Culburra ZS
Huskisson ZS
South Nowra ZS
Sussex Inlet ZS
Tomerong ZS
Yatte Yattah ZS
West Tomerong TS
Forecast
PF
0.963
0.965
0.909
0.966
0.900
0.946
0.933
Actual (MVA)
2013
2014
-
2015
8.9
4.7
10.4
4.9
11.2
4.3
44.8
2016
8.9
5.2
6.7
5.1
11.2
4.3
41.8
Forecast (MVA)
2017
2018
8.9
8.9
6.0
6.0
9.5
9.5
5.2
5.3
11.2
11.2
4.3
4.3
45.5
45.6
2019
8.9
6.0
9.6
5.3
11.2
4.3
45.7
2014
9.8
9.2
11.0
5.2
11.2
3.4
50.2
2015
9.8
9.7
11.8
5.3
11.2
3.4
51.7
Forecast (MVA)
2016
9.8
9.7
9.9
5.4
11.2
3.4
49.9
2018
9.8
10.4
10.1
5.5
11.2
3.4
50.8
Table 163: West Tomerong TS – summer demand forecast
Substation Name
Culburra ZS
Huskisson ZS
South Nowra ZS
Sussex Inlet ZS
Tomerong ZS
Yatte Yattah ZS
West Tomerong TS
Forecast
PF
0.969
0.980
0.939
0.977
0.900
0.973
0.949
Actual (MVA)
2012
2013
-
Table 164: West Tomerong TS – winter demand forecast
2017
9.8
10.4
10.0
5.5
11.2
3.4
50.7
3.2.33.2 WEST TOMERONG TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from West Tomerong TS is at 33kV.
Capacity
(MVA)
Feeder Name
7529 TS – South Nowra (New)
7531 TS – South Nowra (New)
7533 & /1 TS – Culburra (New)
7524 Culburra – South Nowra
7520 TS – Yatte Yattah
7518 TS – Tee
7522 33525 – AT35174 Tee
7523 TS – Tee
7530 TS –
7525/7526 – Tee – Sussex Inlet
7532 TS – Tee
7507 Shoalhaven TS – South Nowra
7534 Tee – Ulladulla
20.7
25.4
20.9
20.9
20.7
20.9
14.1
55.0
55.0
33.3
14.1
13.3
14.1
14.1
14.1
35.1
11.4
Actual
(MVA)
2014
10.6
10.6
9.3
9.3
15.6
15.6
4.8
20.0
0.0
4.8
9.2
4.3
9.2
4.8
4.3
4.3
11.2
Forecast (MVA)
2015
10.4
10.4
9.3
9.3
4.7
4.7
4.9
22.5
11.2
4.9
9.2
4.3
9.2
4.9
4.3
4.3
11.2
2016
6.7
6.7
9.3
9.3
5.2
5.2
5.1
22.6
11.2
5.1
9.4
4.3
9.4
5.1
4.3
4.3
9.0
2017
9.5
9.5
9.3
9.3
6.0
6.0
5.2
22.8
11.2
5.2
9.6
4.3
9.6
5.2
4.3
4.3
9.1
2018
9.5
9.5
9.3
9.3
6.0
6.0
5.3
23.0
11.2
5.3
9.6
4.3
9.6
5.3
4.3
4.3
9.1
2019
9.6
9.6
9.3
9.3
6.0
6.0
5.3
23.4
11.2
5.3
9.6
4.3
9.6
5.3
4.3
4.3
9.1
Table 165: West Tomerong TS – summer
Network Constraint
Nil
Year
Investigation
Table 166: West Tomerong TS – identified limitations
Solution
3.2.33.3 WEST TOMERONG TS NETWORK MAP
3.2.34
WEST WETHERILL PARK TRANSMISSION SUBSTATION
3.2.34.1 WEST WETHERILL PARK TS CONNECTION POINTS
West Wetherill Park Transmission Substation and Zone Substation are supplied at 132kV from Sydney
West Bulk Supply Point by feeder 93M with the alternate supply provided by feeder 93T via Guilford TS.
West Wetherill Park TS has one 120MVA 132/33kV transformer providing a 33kV non-firm capacity of
120MVA and West Wetherill Park ZS situated on the same site has two 45MVA 132/11kV transformers
providing an 11kV firm capacity of 45MVA.
Substation
Voltage
Levels
Transformer
Description
(MVA)
Bossley Park ZS
Horsley Park ZS
33/11kV
33/11kV
132/33kV
2 x 35
2 x 25
1 x 120
Installed
Capacity
Total ‘N’
(MVA)
70
50
120
Firm Rating
Secure ‘N-1’
(MVA)
35
25
NA
95% Peak
Load
Exceeded
(hours)
2.75
1.75
0.25
Embedded
Generation
(MW)
2.22
0.49
-
Table 167: West Wetherill Park TS – transformer rating and substation details
Substation Name
Bossley Park ZS
Horsley Park ZS
Forecast
PF
0.995
0.979
0.991
Actual (MVA)
2013
2014
-
2015
32.0
11.2
43.2
2016
30.0
9.0
39.1
Forecast (MVA)
2017
2018
30.1
30.2
9.1
9.1
39.2
39.2
2019
30.2
9.1
39.3
2015
14.3
6.5
20.7
Forecast (MVA)
2016
2017
14.3
14.3
6.5
6.5
20.7
20.7
2018
14.3
6.5
20.7
Table 168: West Wetherill Park TS – summer demand forecast
Substation Name
Bossley Park ZS
Horsley Park ZS
Forecast
PF
0.997
0.988
0.994
Actual (MVA)
2012
2013
-
Table 169: West Wetherill Park TS – winter demand forecast
2014
12.5
6.5
19.0
3.2.34.2 WEST WETHERILL PARK TS SUB-TRANSMISSION SYSTEM
The sub-transmission network emanating from West Wetherill Park TS is at 33kV.
Capacity
(MVA)
Feeder Name
744 TS – Horsley Park
74C SS – Horsley Park
21.0
42.0
46.0
Actual
(MVA)
2014
11.2
28.8
28.8
Forecast (MVA)
2015
11.2
32.0
32.0
2016
9.0
30.0
30.0
2017
9.1
30.1
30.1
2018
9.1
30.2
30.2
2019
9.1
30.2
30.2
Table 170: West Wetherill Park TS – summer
Network Constraint
Nil
Year
Investigation
Table 171: West Wetherill Park TS – identified limitations
Solution
3.2.34.3 WEST WETHERILL PARK TS NETWORK MAP
FORECAST OF RELIABILITY TARGET PERFORMANCE
3.3
The Minister for Energy first established Licence Conditions for the distribution network service providers
on 1 August 2005 covering design planning standards, reliability, individual feeder and customer service
standards. The conditions were designed to give guidance to the distributors regarding the performance
levels expected by the NSW Government.
The current Licence Conditions were set on 1 July 2014. Table 172 provides the reliability performance
information required by Licence Conditions 18.2 and 18.3 including:

Performance against the SAIDI average standards and SAIFI average standards by feeder type,
disregarding excluded interruptions

Reasons for any non-compliance by the licence holder with the reliability standards and plans to
improve performance
The data listed in Table 172 is the ‘normalised’ data set i.e. the overall data with ‘excluded’ interruptions
deducted.
‘Excluded’ interruptions are defined in Schedule 4 of the Licence Conditions and are primarily outages of
less than one minute duration or caused by directed load shedding, planned maintenance, failure of the
shared transmission system or ‘major event day’ outages.
Whole Network and Feeder Category
CBD
Urban
Rural Short
Rural Long
N/A
771,332
161,104
313
N/A
63
173
989
N/A
80
300
N/A
N/A
0.9
1.7
3.4
N/A
1.2
2.8
N/A
Customer Numbers (Average over Year to Date)
SAIDI
Actual
Standard from Licence Conditions
SAIFI
Actual
Standard from Licence Conditions
Network*
932,749
83
N/A
1.0
N/A
Table 172: Annual network reliability performance
*Refers to the average performance of the Endeavour Energy’s network overall. This
measure does not form part of the licence conditions but is needed to calculate the overall NSW result.
SAIDI means the sum of the duration of each sustained customer interruption (measured in minutes),
divided by the total number of customers (averaged over the year) of the licence holder.
SAIFI means the total number of sustained customer interruptions divided by the total number of
customers (averaged over the year) of the licence holder.
The Australian Energy Regulator (AER) introduced a Service Target Performance Incentive Scheme
(STPIS) for NSW electricity distributors in 2014/15. This scheme will encourage continuous improvement
in reliability performance by offering financial incentives or penalties based on improvements or
deterioration in performance from benchmark levels set in a prior period. From 2014/15 Endeavour
Energy’s reliability performance will be measured against performance achieved in the 2009/2014
period.
Endeavour’s organisational normalised unplanned SAIDI trend over the last 10 years has largely
plateaued as shown in Figure 5. Year on year variations around the long term trend have been more
prominent in recent years. This longer term trend aligns with the Endeavour’s objective of maintaining
reliability at current average levels over the course of the next regulatory period defined by the expected
target under the AER’s STPIS incentive scheme.
Management of reliability under a STPIS regime requires consideration of desired reliability outcomes as
well as the interactions between expenditure and STPIS bonuses or penalties and the overall impact of
these on customer prices. Incurring capital expenditure on reliability improvement initiatives that result in
STPIS bonuses imposes a double impost on prices. Therefore, where operational efficiencies can be
made that also result in improved reliability outcomes, or at least do not result in worse outcomes,
customer outcomes in terms of reliability and pricing are optimised. Therefore, Endeavour’s approach to
the STPIS scheme will be to focus efforts on operational initiatives.
140
120
100
80
60
40
20
Rolling 12 month SAIDI
Yearly SAIDI
Jul-20
Mar-20
Jul-19
Nov-19
Mar-19
Jul-18
Nov-18
Mar-18
Jul-17
Nov-17
Mar-17
Jul-16
Nov-16
Mar-16
Jul-15
Lower Bound
Nov-15
Mar-15
Jul-14
Nov-14
Mar-14
Jul-13
Upper Bound
Nov-13
Mar-13
Jul-12
Nov-12
Mar-12
Jul-11
Nov-11
Mar-11
Jul-10
Nov-10
Mar-10
Jul-09
Nov-09
Mar-09
Jul-08
Nov-08
Mar-08
Jul-07
Nov-07
Mar-07
Jul-06
Nov-06
Mar-06
Jul-05
Nov-05
0
Linear (Rolling 12 month SAIDI)
Figure 5: Long term organisational SAIDI trend (log-normalised)
More specifically, Endeavour has a reliability plan intended to achieve the following objectives:

Stable reliability performance

Performance levels that prevent the Company incurring efficiently avoidable penalties under the
AER’s STPIS scheme

Ensure that the performance experienced by those customers who currently experience worse
than average reliability on the Endeavour Energy network does not materially deteriorate

Maintenance of compliance with the Licence Condition reliability objectives

Ensure that the reliability impact of equipment defects is managed to a level consistent with or
better than historic performance

Raise the profile of reliability as a key indicator of corporate performance and in so doing
encourage a culture that observes, identifies and learns from issues on the network that may
impact asset life, reliability performance or safety issues

Improve data analysis, reliability performance reporting and explanation through better data
gathering and statistical analysis tools
3.4
OTHER FACTORS WHICH HAVE A MATERIAL IMPACT ON THE NETWORK
Endeavour Energy defines, for the purpose of this report, that ‘material impact’ is greater than 1% of
annual capital expenditure and relates to expenditures in excess of $2m.
The forward planning work program extends until the end of the current regulatory period in 2019.
3.4.1
FAULT LEVELS
Within the forward planning work program, there are no single replacement projects in excess of $2m
that are driven by fault level issues.
3.4.2
VOLTAGE LEVELS
that are driven by voltage level issues.
3.4.3
POWER SYSTEM SECURITY REQUIREMENTS
that are driven by power system security issues.
3.4.4
QUALITY OF SUPPLY
that are driven by quality of supply issues.
3.4.5
AGEING ASSETS
There are a number of projects and programs that are being undertaken or are proposed to be
undertaken during the forward planning period that replace assets that have reached the end of their
serviceable life. These are summarised below. Further detail of the committed projects is provided in
Section 5.3.1.
Asset Name
Asset Type
DS005 - Pole
Replacement
Capital
DS006 - LV Consac
Cable Replacement
Poles in
distribution lines
DS007 - Service
Mains replacement
program
DS011 - HV
Distribution Steel
Mains Replacement
DS013 – Lapstone
distribution network
renewal
DS301 - Ground
Substation
Refurbishment
Program
DS302 - Distribution
Transformer
Replacement
Program
DS405 - Air break
Switch Replacement
DS414 – Copper
distribution mains
replacement
Age
(yrs)
Various
Asset Condition
Replacement
Timeline
2015 - 2025
New poles
Short-circuit and open
circuit neutral failures, poor
reliability
Degraded insulation –
safety risk.
2015 - 2025
PVC cables
2015 - 2025
XLPE service mains
Various
Corrosion and fatigue –
bushfire risk
2015 - 2025
New ACSR, AAAC or
steel conductor
Condemned poles
Asset Replacement
LV Consac cable
in the distribution
network
Overhead service
mains to
customers
premises
Steel conductors
in 11 and 22kV
lines
LV distribution
network at
Lapstone
36 - 44
50
Failure of direct buried LV
feeder and service cables
and roadside pillars
2015 - 2019
11kV ground
mounted
distribution subs
Various
Exposed conductors,
maintenance requirements
2015 - 2025
Standard URD
padmount substations,
XLPE LV feeder
cables and service
cables and LV pillars
Padmount substation
Distribution
transformers
Various
Corrosion, oil leaks
2015 - 2025
New transformers
Air-break switches
in the 11 and 22kV
network
Copper
conductors in the
11 and 22kV
network
Various
Switch failures
2015 – 2025
Enclosed switches
Various
Corrosion and fatigue
related failures – safety and
bushfire risk
2015 - 2019
New aluminium
conductor
Various
Asset Name
Asset Type
PS008 - Substation
Protection Relay
Refurbishment
TM012 Transmission Pole
Replacement
TM014 - Renewal of
33kV and 66kV gas
and oil filled cables
Protection relays
in TS and ZS
Age
(yrs)
Various
Asset Condition
End of life failures
Replacement
Timeline
2015 – 2025
Asset Replacement
Numerical relays
Transmission line
poles
Various
Replacement of
condemned poles
2014 -
New poles, generally
concrete
66kV and 33kV
gas and oil
insulated cables at
Port Kembla TS
Various
2014 – 2016
(Port Kembla)
XLPE cables
TM023 - 132kV
Feeders 233 cable
replacement
TM134 Wollongong – Port
Kembla pilot cable
Replacement
TM171 Replacement of
corroded earthwire
TM174 - Hardex
Pilot Cable
Replacement
132kV oil
insulated cable
233
Copper protection
pilots on 33kV
feeders
49
Replace cables with
specialist maintenance
requirements at end of life
and simplify network
arrangement.
Cable failed due to fatigue
of sheath
2014 - 2016
XLPE cable along
different route
Various
Pilots failed due to moisture
ingress, damage due to
lightning and corrosion
2019 - 2022
ADSS and UG optical
fibre
Steel EW on
132kV lines
60
EW at risk of failure due to
corrosion
2015 - 2024
Aluminium earthwires
Hardex earthwire
on 66 and 33kV
feeders
Various
2015 - 2025
OPGW or aluminium
earthwire
TM404 Avon/Nepean Dam
Feeder
refurbishment
TS102 - Rydalmere
ZS Redevelopment
33kV woodpole
line
Up to
86
2013 - 2017
New 33kV concrete
pole line
Zone substation
47 - 54
2008 - 2016
New indoor 66/11kV
substation
TS122 - Leabons
Lane ZS Renewal
Zone substation
48
Replacement of the
earthing and lightning
shielding function when at
end of mechanical strength
due to corrosion and fatigue
Failures of the copper
conductor, insulators,
crossarms due to age and
bushfire damage
66kV and 11kV switchgear,
P&C and auxiliaries at end
of life
of life
2012 - 2015
TS123 - St Marys
ZS Renewal
Zone substation
48
of life
2012 - 2016
TS125 – Guildford
TS Renewal
Transmission
substation
55
2009 - 2015
TS127 - Castle Hill
ZS Renewal
Zone substation
54
132kV and 33kV
switchyard, P&C and power
transformers at end of life.
33kV CBs with inadequate
switching capability.
66kV and 11kV switchyard,
of life
Indoor 33/11kV
substation in extension
of existing control
building, Low noise
TX
Indoor 33/11kV
substation in extension
of existing control
building. Low noise
TX
New indoor 132/33
substation. New low
noise TX
TS143 – Westmead
ZS Renewal
Zone substation
36
Power transformers, 33kV
switchgear and auxiliaries
at end of life. 11kV CB
failure risk threatens supply
to Westmead Hospital
2012 - 2016
TS146 - Marayong
ZS Renewal
Zone substation
49
2019 – 2022
TS155 - Sussex
Inlet ZS Stage 2
Zone substation
46
11kV switchgear, P&C and
auxiliaries at end of life.
Excessive double cabling
on 11kV
11kV switchgear and
switchyard, P&C and
control building not fit for
purpose
2012 - 2015
2019 – 2023
Refurbished outdoor
66kV switchyard and
11kV switchboard.
Existing low noise TX
New power
transformers, 11kV
vacuum trucks, 33kV
SF6 switchgear,
auxiliaries and
protection
New 11kV, P&C and
auxiliaries
New control
building,11kV, P&C
and auxiliaries
Asset Name
Asset Type
TS163 - Unanderra
ZS Redevelopment
Zone substation
Age
(yrs)
51
TS165 - Greystanes
ZS
Zone substation
45
TS167 - Carlingford
TS Control Building
Transmission
Substation control
building
62
TS168 - Carramar
ZS Switchgear
Zone substation
33
TS173 – 11kV
Switchboard Truck
Replacement
621 X 11kV CB in
various zone
substations
29 – 47
TS174 – West
Wollongong ZS
11kV part of zone
substation
50
Asset Condition
Building has issues with
foundations and cable
basement not fit for
purpose. Replace 11kV oil
CBs in new building to
reduce risks to ALARP.
33kV switchyard reaching
end of life and noisy TX in
close proximity to
residences
Control building contains
asbestos and houses aged
auxiliary equipment and
wiring
33kV MG switchboard with
mechanical failures, 11kV
vacuum truck replacement
and 11kV oil aux
switchboard.
Program addresses low
probability but high
consequence risk of CB
failure, explosion and oil fire
in the control building.
Reduces risk to ALARP.
11kV oil switchboard not
suitable for truck
replacement so whole SB
replacement
Replacement
Timeline
2019 – 2023
Asset Replacement
2019 - 2023
Possible indoor 33kV
switchboard and low
noise TX
2019 – 2023
New compact control
building with new P&C
2015 - 2017
New 33kV SF6 and
11kV vacuum CGB
trucks and arc-fault
contained aux S/G
2015 – 2025
Vacuum CB trucks
2019 – 2023
New 11kV vacuum
switchboard
New control
building,11kV, P&C
and auxiliaries
Table 173: Projects driven by ageing assets
3.4.6
POTENTIALLY UNRELIABLE ASSETS
that are driven by unreliable assets.
4.0
IDENTIFIED SYSTEM LIMITATIONS
A major part of the planning process involves performing network analysis using the latest demand
forecast to identify upcoming network limitations. The process then identifies whether a corrective action
is required to address the network limitation. If action is required, then the RIT-D process is initiated to
identify and analyse the credible options for addressing the limitation.
The National Electricity Rules (NER) requires distribution network service providers to investigate nonnetwork options by utilising a thorough consultation process to facilitate input into the planning of major
network upgrades. This provides opportunity for interested parties and the community to submit options
and ideas allowing for the development of cost effective demand management and other system support
options.
The NER calls for a ‘screening test’ to be performed for all capital projects above $5 million to determine
if a non-network option is credible and should be investigated further. If a non-network option is deemed
to be feasible Endeavour Energy will conduct a detailed investigation to determine the objective and
targets for a non-network option to be successful and publish this information in a Non-Network Options
Report. The consultation process which coincides with the release of the report may include the release
of a request for information (RFI) for demand management services. The Non-network Options
Report/RFI is a public process in which Endeavour Energy invites interested stakeholders to make
submissions for system support options, to be evaluated against network options.
Alternatively, an in-house demand management investigation may be conducted to identify a suitable
non-network option. An in-house investigation is only appropriate where a potential non-network solution
is low cost and removes the constraint. For example, an identified network limitation requires a peak
demand reduction of 1,500 kVA to defer the constraint for three years. The network options to address
the limitation cost around $10 million. It is identified that power factor at seven identified customer’s sites
will have the potential to reduce peak demand by 2,000 kVA. The power factor correction (PFC)
program would cost Endeavour Energy $200,000 to implement. In this situation Endeavour Energy
would proceed directly with the implementation of the PFC demand management program without
issuing a non-network options report as the cost of the Non-network Options Report consultation process
would be disproportional to the identified non-network solution. Another situation where an in-house
demand management investigation is appropriate is where there are a small number of major customers
that individually, or as a group, could provide all the demand reduction required to defer or avoid a
network limitation. The customers will be approached for participation in the demand management
program.
This section details the identified network limitations where a screening test to determine the potential for
non-network options is to be conducted. It also provides an indication of potential solutions.
4.1
NOTES ON INDICATIVE NETWORK SOLUTIONS
Remedial action is required where the risk of loss of supply due to demand exceeding capacity is
considered unacceptable. Constrained network and indicative solutions are listed in transmission
substation and sub-transmission feeder groupings, with the following information:
Substation:
The name of the location, usually a zone or transmission substation.
Feeder Location:
The location of the sub-transmission feeder.
Feeder Number:
The identifying number of the sub-transmission feeder.
Critical Season:
The season of most critical peak demand (summer or winter). The demand
and capacity data relates to the nominated season.
Existing Capacity:
The Firm capacity that the network element can supply whilst preserving the
appropriate level of backup capacity.
Demand Forecast:
The following year forecast demand for the most critical season.
Limitation Date:
The date the network element will reach its capacity limitation.
RIT-D Start Date:
The year in which Endeavour Energy anticipates investigation to commence.
Investment decisions can take up to 3 years to finalise the agency and
regulatory approvals. Given this, RIT-D start is timed to meet capacity
limitations.
Transfer Potential:
The load in MVA that could potentially be transferred away from the
constrained network on a permanent basis.
Required Load Reduction: The required level of load reduction to achieve a one year deferral of the
network limitation.
Potential Solutions:
4.2
The currently identified credible options to resolve the network limitation
including network and non-network solutions (subject to public consultation).
TRANSMISSION AND ZONE SUBSTATIONS
Listed below are the identified network limitations on Endeavour Energy’s transmission and zone
substations where a screening test to determine the potential for non-network options is to be conducted.
The Limitation Date indicates when both the firm rating (F) and capacity limitation rating (C) is exceeded.
The ‘Capacity Limitation Rating Reached’ is when the limit is reached within the five year planning
period. The acronym (NWP) means ‘Not within period’.
Substation
Existing 2014/15
Capacity Demand
(firm)
Forecast
(MVA)
(MVA)
Guildford Transmission Substation
Sherwood
S
25
27.7
ZS
Capacity
Limitation
Rating
Reached
Limitation
Date
RITD
Start
Date
Load
Transfer
Potential
(MVA)
Required
Load
Reduction
(MVA)
Yes
(F) Nov 15
(C) NWP
Oct
2020
0
1.5
Hawkesbury Transmission Substation
Riverstone
S
25
13.7
ZS
No
(F) Nov 24
(C) NWP
Oct
2020
0
3
1. New 11kV
Feeders
2. New ZS
3. Demand
management
Regentville Bulk Supply Point
Penrith
S
62*
11kV ZS
45.1
Yes
(F) Nov 15
(C) Nov
15
Oct
2015
3
1
45
42.5
No
(F) Nov 19
(C) NWP
Oct
2023
1
1
1. Uprate Tx
cables
2. Demand
management
1. ZS
augmentation
2. Demand
management
Vineyard Bulk Supply Point
Schofields
S
45
ZS
27.1
No
(F) Nov 22
(C) Nov
24
Oct
2021
0
8
Glenmore
Park ZS
Critical
Season
S
Potential
Solutions
1. Load Transfer
2. Augment ZS
3. Demand
management
1. New ZS
2. Demand
management
Table 174: Zone substation limitations *Limited by transformer cable rating (rating between 32 and 43MVA).
The network limitations listed above were identified as potentially having a non-network solution as part
of the credible options resulting from non-network option screening. For each identified constraint, details
of the limitation and the main areas where demand reduction opportunities exist are discussed, including
the time frame over which a non-network investigation and program implementation would need to
operate.
Sherwood ZS
Sherwood ZS currently supplies the Merrylands commercial area, surrounding residential and high
density residential areas. The commercial area is experiencing slow growth while the surrounding
residential areas are experiencing small pocket of in-fill development.
Screening Test
The area supplied by Sherwood ZS has opportunity for demand reduction within the commercial sector
and potentially opportunities in the residential sector. Thermal rating is expected to be reached by
summer 2015/16 but the planning standards indicates that network augmentation may be deferred till the
end of the forecast period. Permanent load transfers will also be investigated. A screening test for Nonnetwork option feasibility will need to commence three years prior to this occurring to ensure sufficient
time is allocated to implement demand reducing initiatives. A watching brief will be maintained to
monitor demand growth on Sherwood ZS.
Non-network Opportunities
The main contribution to the peak demand increase comes from the commercial sector and in-fill
residential development. Opportunities for demand reduction exist with air conditioning cycling,
voluntary load reduction schemes in both the residential and commercial sectors and potentially
embedded generation. Endeavour Energy will investigate the potential for demand management and the
level of demand reduction potentially available. A non-network options report will be issued in due course
to initiate submissions for non-network solutions with a positive outcome of the screening test.
A non-network solution would need to reduce the summer afternoon peak demand, between the hours of
12:00 to 19:00 weekdays, by 1.0 MVA by summer 2021/22 in order to be effective.
Network Options
Network options will be investigated in due course.
30
25
MVA
20
15
10
5
Figure 6: Sherwood ZS Load Profile 20 December 2013
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Riverstone ZS
Riverstone ZS currently supplies the Riverstone industrial area and the surrounding residential areas.
The industrial area is experiencing slow growth while the surrounding residential area is experiencing
strong and consistent growth which is expected to continue for the forecast period, due to the
development of the North West Sector.
Screening Test
The area supplied by Riverstone ZS has opportunity for demand reduction within the residential sector
and potentially limited opportunities in the industrial sector. Thermal rating is expected to be reached by
summer 2023/24 but the planning standards indicates that network augmentation may be deferred till the
end of the forecast period. Non-network investigation will need to commence three years prior to this
occurring to ensure sufficient time is allocated to implement demand reducing initiatives. A watching
brief will be maintained to monitor demand growth on Riverstone ZS.
The main contribution to the peak demand comes from the residential sector air conditioning on hot
summer days. Opportunities for demand reduction exist with residential air conditioning cycling,
voluntary load reduction schemes and potentially embedded generation. Endeavour Energy will
investigate the potential for residential demand management and the level of demand reduction
potentially available. A non-network options report will be issued in due course to initiate submissions for
non-network solutions with a positive outcome of the screening test.
12:00 to 19:00 weekdays, by 3.0 MVA by summer 2024/25 in order to be effective.
Network Options
Network options that will be investigated include the construction a new zone substation in the North
West Sector to cater for the load growth.
16
14
12
MVA
10
8
6
4
2
Figure 7: Riverstone ZS Load Profile 29 Jan 2014
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Penrith 11kV ZS
The constraint at Penrith ZS is driven by growth in the commercial sector and new industrial load
applications. There is also a small amount of residential development west of the zone substation. The
constraint is due to the 11kV transformer cables which have ratings less than the power transformers to
which they are connected. A study will be conducted on the cables to determine their actual rating. It is
anticipated that option investigation will commence in 2017.
Screening Test
The area supplied by Penrith 11kV ZS has opportunity for demand reduction within the commercial and
industrial sectors and potentially within the residential sector. As the constraint is dependent on the spot
loads appearing and residential growth, customer activity will be closely monitored. A watching brief
will be maintained to monitor demand growth on Penrith 11kV ZS.
The main contributors to peak demand are from the commercial centre and the industrial sector. The
residential area is contributing to load growth and the air conditioning load is contributing to the volatile
summer peak demand. Opportunities for demand reduction exist with assisting the commercial and
industrial sectors to become more efficient and in residential voluntary load reduction schemes.
Endeavour Energy will investigate the potential for demand management and the level of demand
reduction potentially available. Load curtailment opportunities in the commercial and industrial sectors
will also be investigated. A non-network options report will be issued in due course to obtain submission
for non-network solutions with a positive outcome of the screening test.
11:00 to 17:00 weekdays. The level of demand reduction will be determined once the 11kV cable rating
study is complete.
Network Options
Network options that will be investigated include replacing or uprating the 11kV transformer cables. In
the longer term and dependant on load applications, a new substation may be required.
50
45
40
35
MVA
30
25
20
15
10
5
Figure 8: Penrith 11kV ZS Load Profile 16 January 2014
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Glenmore Park ZS
Glenmore Park ZS currently supplies the Glenmore Park residential area. The residential growth has
been strong and is expected to continue at the same rate for the forecast period. The firm rating of the
substation is expected to be reached in summer 2019/20 whereas the planning standards indicates that
network augmentation may be deferred till the end of the forecast period.
Screening Test
The area supplied by Glenmore Park ZS has opportunity for demand reduction within the residential
sector. An air conditioning cycling and voluntary load reduction residential program will be investigated
as part of the screening test. A watching brief will be maintained to monitor demand growth on
Glenmore Park ZS
The main contributor to peak demand is the residential sector air conditioning demand on hot summer
days. Opportunities for demand reduction exist with residential air conditioning cycling and voluntary
load reduction, load curtailment of other appliances such as pool pumps and potentially embedded
generation. Endeavour Energy will investigate the potential for residential demand management and the
to obtain submissions for non-network solutions with a positive outcome of the screening test.
15:00 to 19:00 weekdays, by 1.0 MVA at the end of the forecast period.
Network Options
Network options that will be investigated include the augmentation of Glenmore Park zone substation.
40
35
30
MVA
25
20
15
10
5
Figure 9: Glenmore Pare ZS 22 December 2013
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Schofields ZS
Schofield ZS supplies the new release areas of Schofield, Rouse Hill and The Ponds. The residential
growth has been strong and is expected to continue at the same rate for the forecast period. The firm
rating of the substation is expected to be reached in summer 2021/22 whereas the planning standards
indicates that network augmentation may be deferred till the end of the forecast period.
Screening Test
The area supplied by Schofield Park ZS has opportunity for demand reduction within the residential
sector. An air conditioning cycling and voluntary load reduction residential program will be investigated
as part of the screening test. A watching brief will be maintained to monitor demand growth on
Schofield ZS
days. Opportunities for demand reduction exist with residential air conditioning cycling and voluntary
load reduction, load curtailment of other appliances such as pool pumps and potentially embedded
generation. Endeavour Energy will investigate the potential for residential demand management and the
to obtain submissions for non-network solutions with a positive outcome of the screening test.
Network Options
Network options that will be investigated include the construction of a new zone substation.
18
16
14
12
MVA
10
8
6
4
2
Figure 10: Schofields ZS Load Profile 18 January 2014
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
4.3
SUB-TRANSMISSION FEEDERS
Listed below are the identified network limitations on Endeavour Energy’s sub-transmission network.
The Limitation Date indicates when both the firm rating (F) and capacity limitation rating (C) is exceeded.
The ‘Capacity Limitation Rating Reached’ is when the limit is reached within the five year planning
period. The acronym (NWP) means ‘Not within period’.
Feeder
Location
Fdr
No.
Critical
Season
Existing
Capacity
(MVA)
Lawson Transmission Substation
Hazelbrook
808
S
22
ZS to
Springwood
Mt Druitt Transmission Substation
TS to
490
S
34
St Marys
&
ZS
491
Mt Terry Transmission Substation
TS to
7043
S
11.9
Tee Berry
&
&
ZS*
7514
13.3
Nepean Transmission Substation
TS to
311
S
29
Cawdor ZS
&
306
2014/15
Demand
Forecast
(MVA)
Capacity
Limitation
Rating
Reached
Limitation
Date
RITD
Start
Date
Required
Load
Reduction
(MVA)
Potential Solutions
23.4
Yes
(F) Nov 21
(C) Nov
21
Oct
2018
2
1. Transfer capacity
2. LDC at Lawson TS
3. Demand
management
32.8
No
(F) Nov 23
(C) NWP
Oct
2021
1
1. Design
temperature
2. Demand
management
12.7
&
13.9
No
(F) Nov 22
(C) Nov
22
Oct
2020
1
1. Design
temperature
2. Demand
management
32.1
Yes
(F) Nov 15
(C) Nov
15
Oct
2015
3
1. Design
temperature
2. Augment feeder
3. Demand
management
Table 175: Sub-transmission feeders limitations *Feeder 7514 to Berry ZS is supplied from Shoalhaven TS
The network limitations listed above were identified as requiring a screening test for a non-network
solution as part of the development of credible solutions. For each identified constraint details of the
limitation and the main areas where demand reduction opportunities exist are discussed, including the
time frame over which a non-network investigation and program implementation would need to operate.
Hazelbrook to Springwood Feeder 808
Feeder 808 exceeds its capacity limitation when supplying Springwood ZS via Hazelbrook ZS on outage
of feeder 824. There exists a 2 MVA transfer capacity via the 11kV network from Springwood ZS to
Blaxland ZS and Hazelbrook ZS. This will assist in maintaining the peak demand to below the capacity
limitation until summer 2022/23.
Springwood ZS supplies the predominantly residential sector in the Blue Mountains. This area is
experiencing a slow growth of about 0.1 MVA per annum. The summer peak demand is the issue for
this part of the network due to the lower summer rating of feeder 808 being the limiting factor. It is a
typical residential load profile driven by evening peak loads made up of mainly air conditioning and
household appliances.
Screening Test
The area supplied by Springwood ZS has opportunity for demand reduction within the residential sector.
An air conditioning cycling and voluntary load reduction residential program will be investigated as part of
the screening test. A watching brief will be maintained to monitor demand growth on Springwood
ZS.
days and cooking. Opportunities for demand reduction exist with residential air conditioning cycling,
voluntary load reduction, load curtailment of other appliances such as pool pumps and potentially
embedded generation. Endeavour Energy will investigate the potential for demand management and the
level of demand reduction available. A Non-network Options Report will be issued in due course to
obtain submission for non-network options with a positive outcome of the screening test.
A non-network option would need to reduce the summer afternoon peak demand between the hours of
16:00 to 20:00 weekdays by 1.0 MVA summer.
Network Options
Network options that will be investigated include the development of additional 11kV transfer capacity
and the installation of Line Drop Compensation (LDC) at Lawson TS. This will reduce the level of
demand to be supplied via feeder 808.
25
20
MVA
15
10
5
Figure 11: Springwood ZS Load Profile 22 December 2013
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Mount Druitt TS to St Marys ZS Feeders 490 & 491
Feeders 490 and 491 supply St Marys ZS. Each feeder exceeds its capacity limitation on an outage of
the other feeder. The limitation is reached in summer 2013/14. There exists a 2 MVA transfer capacity
via the 11kV network from St Marys ZS to Mamre ZS. This will assist in maintaining the peak demand to
below the capacity limitation until summer 2014/15.
St Marys ZS supplies the residential areas of St Marys, Colyton, St Clair and Erskine Park. It also
supplies St Marys commercial centre. This area is experiencing a slow growth of about 0.2 MVA per
annum and exhibits a typical summer residential load profile driven by evening peak loads made up of
mainly air conditioning and other household appliances.
Screening Test
The area supplied by St Marys ZS has opportunity for demand reduction within the residential sector with
the potential of some demand reduction in the commercial. The feasibility of a residential air condition
cycling and voluntary load reduction program will be investigated as part of the screening test. A
watching brief will be maintained to monitor demand growth on St Marys ZS.
days coinciding with the use of other household appliances. Opportunities for demand reduction exist
with residential air conditioning cycling, voluntary load reduction, load curtailment of other appliances
such as swimming pool pumps and potentially embedded generation. The commercial sector contains
several large shopping centres and a major customer. Endeavour Energy will investigate the potential for
demand management and the level of demand reduction available. A Non-network Options Report will
be issued in due course to obtain submissions for non-network options with a positive outcome of the
screening test.
A non-network option would need to reduce the summer afternoon peak demand between the hours of
Network Options
Network options that will be investigated include the development of additional 11kV transfer capacity
and the re-rating of feeders 490 and 491 to a higher temperature design rating. This will defer the
network limitation to beyond the planning period.
35
30
25
MVA
20
15
10
5
Figure 12: St Marys ZS Load Profile 22 December 2013
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Mt Terry TS to Berry ZS Feeder 7043 & 7514
Feeder 7043 supplies Berry ZS from Mt Terry TS via a Tee connection. On loss of feeder 7515
(Shoalhaven TS to Berry ZS) feeder 7043 exceeds its thermal capacity. The limitation is reached in
summer 2019/20 when the back-up supply to Berry ZS is required.
Berry ZS supplies the township of Berry and surrounding rural / residential load type. This area is
experiencing slow growth of about 0.3 MVA per annum. There is a small residential development within
the Berry ZS load area. The area experiences an increase in demand during school holiday period and
the network limitation is experienced during summer peak periods driven by hot weather coinciding with
the holiday period.
Screening Test
The area supplied by Berry ZS has limited opportunity for demand reduction within the residential / rural
sector. Notwithstanding this, the feasibility of a residential voluntary load reduction program will be
investigated as part of the screening test. A watching brief will be maintained to monitor demand
growth on Berry ZS.
days coinciding with the holiday period. Opportunities for demand reduction exist with residential air
conditioning cycling, voluntary load reduction and potentially embedded generation. Endeavour Energy
will investigate the potential for demand management and the level of demand reduction available. A
Non-network Options Report will be issued in due course to obtain submissions for non-network options
with a positive outcome of the screening test.
A non-network option would need to reduce the summer afternoon peak demand, between the hours of
14:00 to 20:00 weekdays, by 0.5 MVA in summer 2020/21 growing by 0.3 MVA per annum.
Network Options
Network options will be investigated in due course.
8
7
6
MVA
5
4
3
2
1
Figure 13: Feeder 7043 Mt Terry TS to Berry ZS Load Profile 6 July 2013
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
Nepean TS to Cawdor ZS Feeders 311 & 306
Feeders 311 and 306 connect Nepean 33kV TS and Cawdor ZS. On loss of either feeder the other
feeder exceeds their thermal capacity. The limitation is reached in summer 2015/16.
Cawdor ZS supplies Cawdor, Camden South, Camden Park and Menangle. The load type is residential /
rural with some township centres. This area is experiencing slow growth of about 0.1 MVA per annum.
Screening Test
The area supplied by Cawdor ZS has limited opportunity for demand reduction within the rural /
residential sector. The feasibility of voluntary load reduction and other demand management programs
will be investigated as part of the screening test. An investigation is planned to be conducted during
2014/15.
The main contributor to peak demand is the rural / residential sector air conditioning demand on hot
summer days. Opportunities for demand reduction exist with residential air conditioning cycling,
voluntary load reduction and potentially embedded generation. Endeavour Energy will investigate the
potential for residential demand management and the level of demand reduction available. A Nonnetwork Options Report will be issued in due course to obtain submissions for non-network options with
a positive outcome of the screening test.
A non-network option would need to reduce the summer afternoon peak demand, between the hours of
13:00 to 20:00 weekdays, by 4.2 MVA.
Network Options
Network options will be investigated including reactive support to boost voltage levels.
30
25
MVA
20
15
10
5
Figure 14: Cawdor ZS Load Profile 15 January 2014
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
12 AM
0
PRIMARY DISTRIBUTION FEEDERS
4.4
For any primary distribution feeders for which Endeavour Energy has prepared forecasts of maximum
demands and which are currently experiencing an overload, or are forecast to experience an overload in
the next two years, Endeavour Energy must set out:

The location of the primary distribution feeder;

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);

The types of potential solutions that may address the overload or forecast overload; and

Where an estimated reduction in forecast load would defer a forecast overload for a period of 12
months, including:

An estimate of the month and year in which the overload is forecast to occur;

A summary of the location of relevant connection points at which the estimated reduction in
forecast load would defer the overload;

The estimated reduction in forecast load in MW needed to defer the forecast system
limitation.
Note: The normal rating of an 11kV feeder cable emanating from a zone substation is 4/5 of 300 amps,
(the rating of the cable). This equates to 240 amps. The 4/5 rule allows for 1/5 of the full thermal rating of
the feeder to be available for transfer of load from an adjacent feeder under first level emergency
conditions.
Note: In the table below, “Cap + Fdr” means that the feeder is double cabled with a capacitor bank and
the actual load will be subject to further investigation.
Location
Feeder
Ambarvale
t868
Ambarvale
t869
Anzac Village
az1227
Anzac Village
az1272
Bella Vista
49319
Bella Vista
49341
Blaxland
r256
Bonnyrigg
52238
Bonnyrigg
8762
Bonnyrigg
8773
Bonnyrigg
8774
Bonnyrigg
8780
Bossley Park
l510
Bossley Park
l516
Bossley Park
l519
Bossley Park
l519-b
Bow Bowing
w185
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Extent of Primary Feeder Overload
(% above normal cyclic rating)
13/14 Actual
14/15
15/16
15.4%
20.0%
21.5%
0.0%
0.0%
0.0%
1.3%
5.2%
6.6%
2.1%
6.1%
7.5%
0.0%
2.6%
7.3%
0.0%
0.0%
0.0%
4.2%
6.8%
11.7%
0.0%
0.0%
0.0%
16.9%
0.0%
10.7%
0.0%
0.0%
0.0%
13.0%
0.0%
4.4%
0.0%
0.0%
0.0%
0.0%
6.2%
9.4%
0.0%
0.0%
0.0%
6.1%
12.5%
15.5%
0.0%
0.0%
0.0%
21.9%
32.2%
35.7%
0.0%
0.0%
0.0%
24.8%
30.1%
33.5%
0.0%
0.0%
0.0%
4.9%
13.5%
16.5%
0.0%
0.0%
0.0%
13.4%
22.9%
26.2%
0.0%
0.0%
0.0%
12.9%
28.2%
29.7%
0.0%
0.0%
0.0%
13.9%
28.5%
30.0%
0.0%
0.0%
0.0%
19.8%
33.0%
34.5%
0.0%
0.0%
0.0%
20.1%
33.4%
35.0%
0.0%
0.0%
0.0%
12.5%
3.6%
2.0%
0.0%
0.0%
0.0%
Reduction
Required
(MVA)
0.98
Potential
Solution
Do Nothing
0.34
Existing Project
0.33
Monitor
0.54
Monitor
0.77
Load Transfer
Rq'd
Monitor
0.59
0.43
0.71
Load Transfer
Rq'd
Existing Project
1.63
Cap + Fdr
1.53
Existing Project
0.76
Existing Project
1.20
Cap + Fdr
1.36
Cap + Fdr
1.37
Existing Project
1.58
Do Nothing
1.60
Load transfer
Rq'd
Cap + Fdr
0.57
Location
Feeder
Bow Bowing
w191
Bow Bowing
w194
Bringelly
x877
Bringelly
x879
Campbelltown
ct1202
Campbelltown
ct1210
Campbelltown
ct1225
Campbelltown
ct1296
Carramar
d845
Casula
ca1254
Casula
ca1269
Casula
ca1284
Cawdor
cd1204
Cawdor
cd1241
Cawdor
cd1260
Cawdor
cd1267
Cawdor
cd1271
Cawdor
cd1297
Cheriton Ave
cj1245
Chipping
Norton
Chipping
Norton
Chipping
Norton
Chipping
Norton
Chipping
Norton
Claremont
Meadows
Cranebrook
cn1210
c806
Cranebrook
c809
Doonside
ds1204
Doonside
ds1235
Doonside
ds1256
Dundas
2815
Dundas
5495
Eastern Creek
54701
cn1213
cn1254
cn1258
cn1261
cs1284
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
13/14 Actual
14/15
15/16
18.8%
9.4%
7.6%
0.0%
0.0%
0.0%
12.1%
3.2%
1.6%
15.0%
0.0%
0.0%
43.8%
61.7%
41.6%
14.1%
26.2%
10.5%
0.0%
0.0%
0.0%
0.0%
7.9%
0.0%
9.2%
11.6%
19.0%
0.0%
0.0%
0.0%
0.0%
1.3%
8.1%
0.0%
0.0%
0.0%
25.8%
28.6%
37.2%
28.3%
29.0%
37.6%
23.8%
26.5%
34.9%
0.0%
0.0%
0.0%
3.4%
20.6%
23.2%
0.0%
0.0%
2.1%
0.0%
0.0%
26.7%
0.0%
0.0%
0.0%
7.5%
0.0%
60.2%
0.0%
0.0%
0.0%
30.5%
0.0%
94.6%
0.0%
0.0%
0.0%
0.0%
6.0%
20.9%
0.0%
0.0%
0.0%
2.9%
75.7%
100.4%
0.0%
34.4%
53.4%
0.0%
0.0%
0.0%
0.0%
15.2%
31.5%
10.4%
88.5%
115.0%
0.0%
25.9%
43.6%
0.0%
61.5%
84.2%
0.0%
2.4%
16.9%
0.0%
62.2%
85.0%
0.0%
24.5%
42.0%
9.9%
0.0%
2.1%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
47.8%
0.0%
0.0%
0.0%
10.2%
0.0%
260.4%
0.0%
0.0%
0.0%
0.0%
0.0%
20.0%
0.0%
0.0%
0.0%
0.0%
0.0%
106.2%
0.0%
0.0%
0.0%
0.0%
0.0%
20.5%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
100.0%
83.4%
86.7%
67.1%
53.2%
55.9%
39.5%
18.3%
20.4%
18.4%
0.7%
2.5%
0.0%
0.0%
1.3%
0.0%
0.0%
13.7%
0.0%
0.0%
59.2%
0.0%
0.0%
23.4%
0.0%
0.0%
44.7%
0.0%
0.0%
57.9%
0.0%
0.0%
0.0%
0.0%
0.0%
0.9%
0.0%
0.0%
0.0%
14.1%
20.9%
28.9%
0.0%
0.0%
3.8%
0.0%
0.0%
0.4%
Reduction
Required
(MVA)
0.86
Potential
Solution
Cap + Fdr
0.69
Monitor
2.82
Do Nothing
0.36
Load transfer
Rq'd
New Feeder
0.87
0.37
1.72
1.60
1.06
1.22
Load transfer
Rq'd
Load Transfer
Rq'd
Load Transfer
Rq'd
Monitor
0.96
Load Transfer
Rq'd
Load Transfer
Rq'd
Load Transfer
Rq'd
Monitor
4.59
Monitor
1.44
Monitor
5.26
Monitor
3.85
Monitor
3.89
Monitor
0.45
Load Transfer
Rq'd
Load Transfer
Rq'd
Load Transfer
Rq'd
Do Nothing
2.75
4.32
2.18
11.91
0.91
4.86
0.94
Load Transfer
Rq'd
Do Nothing
0.00
Monitor
4.57
HVC
1.81
HVC
0.62
Monitor
2.71
Monitor
2.65
Monitor
0.04
Monitor
1.32
Load transfer
Rq'd
Monitor
0.18
Location
Feeder
Emu Plains
55354
Emu Plains
c848
Emu Plains
c851
Emu Plains
c852
Emu Plains
c854
Emu Plains
c857
Emu Plains
c868
Emu Plains
c869
Fairfield
ff1280
Figtree
ft1202
Figtree
ft1208
Figtree
ft1209
Figtree
ft1210
Glenmore
Park
Glenmore
Park
Glenmore
Park
Glenmore
Park
Hinchinbrook
s766
48159
Hinchinbrook
48168
Hinchinbrook
48189
Homepride
a319
Huntingwood
ht1219
Huntingwood
ht1238
Huntingwood
ht1246
Huntingwood
ht1267
Huntingwood
ht1268
Huntingwood
ht1279
Huntingwood
ht1291
Huntingwood
ht1293
Inner Harbour
ihj2
Jasper Road
55885
Kellyville
8641
Kenthurst
s738
s768
s772a
s776
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
13/14 Actual
14/15
15/16
0.0%
3.5%
5.3%
0.0%
0.0%
0.0%
0.0%
10.6%
12.5%
0.0%
19.4%
21.5%
0.0%
5.8%
7.6%
0.0%
0.0%
0.0%
0.0%
9.1%
11.0%
0.0%
0.0%
0.0%
0.0%
13.5%
15.5%
0.0%
0.0%
0.5%
0.0%
14.7%
16.8%
0.0%
0.0%
0.0%
0.0%
22.5%
24.7%
0.0%
22.5%
24.6%
0.0%
6.9%
8.8%
0.0%
0.0%
0.0%
9.4%
0.0%
0.2%
0.0%
0.0%
0.0%
0.0%
11.5%
15.9%
0.0%
7.5%
11.7%
0.0%
11.3%
15.7%
0.0%
11.6%
16.0%
0.0%
41.8%
47.4%
0.0%
0.0%
0.0%
0.0%
7.2%
11.5%
0.0%
0.0%
0.2%
3.6%
13.7%
14.5%
0.0%
0.0%
0.0%
0.0%
2.3%
3.0%
0.0%
0.0%
0.0%
0.0%
4.7%
5.4%
0.0%
0.0%
0.0%
4.8%
17.0%
17.8%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
3.2%
9.2%
20.3%
43.6%
52.1%
3.2%
23.2%
30.4%
22.5%
41.0%
49.3%
0.0%
4.1%
10.3%
0.0%
0.0%
0.0%
12.8%
14.6%
19.4%
0.0%
0.0%
0.0%
0.0%
0.0%
14.5%
0.0%
0.0%
16.9%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
197.0%
0.0%
0.0%
0.0%
0.0%
0.0%
28.7%
0.0%
0.0%
65.2%
0.0%
0.0%
0.0%
0.0%
0.0%
145.4%
0.0%
0.0%
140.3%
0.0%
0.0%
0.0%
0.0%
0.0%
154.0%
0.0%
0.0%
97.2%
0.0%
0.0%
0.0%
0.0%
0.0%
5.9%
0.0%
0.0%
7.6%
8.3%
16.2%
18.4%
25.2%
34.3%
36.8%
0.0%
0.0%
0.5%
0.0%
0.0%
0.0%
2.1%
22.0%
0.0%
4.2%
24.5%
1.2%
Reduction
Required
(MVA)
0.24
Potential
Solution
Monitor
0.98
Cap + Fdr
0.35
Monitor
0.50
Monitor
0.71
Monitor
0.77
Monitor
1.13
HVC
0.40
Monitor
0.43
Monitor
0.73
Do Nothing
0.73
Do Nothing
2.17
Do Nothing
0.52
Do Nothing
0.66
New Feeder
0.14
Cap + Fdr
0.25
Monitor
0.82
Existing Project
0.42
Monitor
2.38
0.89
Load Transfer
Rq'd
Load Transfer
Rq'd
Cap + Fdr
0.66
Do Nothing
0.77
Do Nothing
9.01
Do Nothing
1.31
Do Nothing
2.98
Do Nothing
6.65
Do Nothing
7.04
Do Nothing
4.44
Do Nothing
0.35
Do Nothing
1.68
0.02
Load Transfer
Rq'd
Monitor
1.12
Monitor
2.25
Location
Feeder
Kenthurst
s743
Kenthurst
s744
Kentlyn
j489
Kingswood
9025
Luddenham
a096
Macquarie
Fields
Mamre
m388
mm1112
Mamre
mm1192
Mamre
mm1202
Mamre
mm1292
Mamre
mm1362
Marayong
1949
Marayong
1949-a
Marayong
1959
Marayong
1962
Marayong
1963
Minto
j467
Jordan
Springs
Jordan
Springs
Moorebank
53312-1b
6420
Moorebank
6431
Mungerie
Park
Narellan
mr2299
27027
Narellan
27029
Narellan
27030
Narellan
27039
Narellan
55163
Narellan
55169
Narellan
55173
Newton
l543
North
Richmond
North
Parramatta
Northmead
27446
53314-2a
16647
3351
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
13/14 Actual
14/15
15/16
0.0%
4.9%
0.0%
0.0%
0.0%
0.0%
0.7%
18.5%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
15.0%
9.9%
10.7%
0.0%
0.0%
0.0%
25.5%
9.2%
8.4%
4.8%
18.1%
18.1%
0.0%
0.0%
0.0%
0.0%
2.3%
0.6%
0.0%
0.0%
0.0%
0.0%
0.0%
29.1%
0.0%
0.0%
29.8%
0.0%
0.0%
52.3%
0.0%
0.0%
0.0%
0.0%
0.0%
33.1%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
1.8%
0.0%
0.0%
0.0%
0.0%
0.0%
3.4%
0.0%
0.0%
0.0%
39.1%
36.3%
37.3%
20.5%
20.1%
21.0%
10.2%
6.7%
7.5%
0.0%
0.0%
0.0%
35.5%
32.6%
33.6%
10.0%
9.7%
10.5%
12.6%
12.3%
13.1%
19.2%
18.8%
19.7%
12.9%
6.6%
7.4%
4.2%
1.3%
0.0%
0.0%
0.0%
0.0%
19.8%
112.7%
141.0%
0.0%
48.0%
67.7%
17.3%
103.6%
130.7%
0.0%
37.3%
55.6%
0.0%
0.0%
0.0%
14.6%
3.7%
0.0%
25.0%
13.2%
0.0%
27.0%
14.1%
0.0%
0.0%
0.0%
7.7%
0.0%
0.0%
0.0%
4.6%
20.5%
21.3%
0.0%
0.0%
0.0%
0.4%
15.7%
16.5%
0.0%
2.3%
2.9%
0.0%
7.5%
8.2%
0.0%
0.0%
0.0%
5.4%
21.5%
22.3%
0.0%
0.0%
0.0%
25.3%
41.4%
42.4%
0.0%
0.0%
0.0%
0.0%
10.9%
11.6%
0.0%
0.0%
0.0%
0.0%
1.8%
2.4%
0.0%
0.0%
0.0%
17.5%
21.2%
18.0%
0.0%
0.0%
0.0%
29.5%
51.5%
47.4%
0.0%
13.6%
10.6%
25.5%
0.8%
0.0%
0.0%
0.0%
0.0%
0.0%
0.1%
6.1%
0.0%
0.0%
0.0%
Reduction
Required
(MVA)
0.22
Monitor
0.85
Monitor
0.69
1.17
Load Transfer
Rq'd
Do Nothing
0.83
Monitor
0.10
Monitor
1.36
0.08
Solution
Required
Solution
Required
Solution
Required
Do Nothing
0.16
Monitor
1.79
Do Nothing
0.96
HVC
1.62
Monitor
0.60
Do Nothing
0.90
HVC
0.19
Cap + Fdr
6.45
Existing Project
5.98
Existing Project
0.67
Cap + Fdr
1.23
HVC
0.35
Monitor
0.97
Cap + Fdr
0.75
Monitor
0.38
Monitor
1.02
Monitor
1.94
Do Nothing
0.53
Monitor
0.11
Monitor
0.97
2.35
Load Transfer
Rq'd
Existing Project
1.17
Existing Project
0.28
Monitor
2.39
1.51
Potential
Solution
Location
Feeder
Northmead
3354
Northmead
3360
Oran Park
Parklea
mc1252a
mc1252b
25773
Parklea
25777
Plumpton
8693
Plumpton
8694
Quakers Hill
b713
Quakers Hill
b720
Quarries
27500
Richmond
4368
Richmond
4369
Richmond
4374
Riverstone
a051
Rooty Hill
t888
Rooty Hill
t889
Rooty Hill
t895
Rosehill
rs1207
Schofields
sc1238
Schofields
sc1241
Schofields
sc1271
Schofields
sc1289
Seven Hills
8621
Sherwood
9046
Sherwood
9055
Sherwood
9056
South
Windsor
Springwood
sz1122
19857
Werrington
35767
West Castle
Hill
West
Liverpool
West Pennant
Hills
27194
Oran Park
wl1292
x859
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
13/14 Actual
14/15
15/16
0.0%
0.0%
0.4%
0.0%
0.0%
0.0%
0.0%
6.2%
12.6%
0.0%
0.0%
4.1%
0.0%
120.2%
163.5%
0.0%
64.8%
97.2%
0.0%
0.0%
0.0%
0.0%
10.8%
32.6%
13.1%
23.4%
21.8%
0.0%
0.0%
0.0%
0.0%
0.9%
0.0%
0.0%
0.0%
0.0%
0.0%
2.1%
3.3%
0.0%
0.0%
0.0%
0.0%
0.0%
1.0%
0.0%
0.0%
0.0%
0.0%
2.5%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
8.2%
1.7%
4.7%
36.2%
52.5%
60.5%
108.7%
133.7%
21.8%
19.1%
0.0%
0.0%
0.0%
0.0%
23.9%
23.6%
0.0%
8.5%
7.3%
0.0%
1.4%
1.4%
0.0%
0.0%
0.0%
0.0%
0.0%
0.5%
5.1%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.5%
0.0%
9.5%
20.5%
7.9%
0.0%
0.0%
0.0%
10.0%
21.5%
8.7%
0.0%
0.0%
0.0%
0.0%
5.4%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
20.5%
0.0%
0.0%
0.0%
0.0%
0.0%
25.2%
0.0%
0.0%
5.7%
0.0%
0.0%
15.1%
0.0%
0.0%
0.0%
0.0%
3.9%
50.8%
0.0%
0.0%
14.7%
14.6%
0.0%
0.3%
7.3%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
10.5%
13.6%
0.0%
1.1%
4.0%
0.0%
0.0%
0.0%
0.0%
1.6%
4.4%
0.0%
0.0%
0.0%
16.6%
11.5%
19.2%
0.0%
0.0%
0.0%
64.5%
50.4%
58.4%
32.3%
27.4%
34.2%
3.8%
0.0%
2.1%
0.0%
0.0%
0.0%
17.3%
24.2%
24.5%
0.0%
0.0%
0.0%
5.6%
5.3%
11.2%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
0.0%
18.0%
Reduction
Required
(MVA)
0.02
Potential
Solution
Monitor
0.57
Monitor
7.47
Existing Project
1.49
Existing Project
1.07
0.04
Solution
Required
Monitor
0.15
Monitor
0.04
Monitor
0.11
Monitor
0.37
Cap + Fdr
6.11
HVC
1.00
Existing Project
1.09
HVC
0.07
Cap + Fdr
0.23
Monitor
0.02
Do Nothing
0.94
Monitor
0.98
Monitor
0.25
Monitor
0.94
Monitor
1.15
Monitor
0.69
Monitor
2.32
Monitor
0.67
HVC
0.62
Monitor
0.18
Monitor
0.20
Monitor
0.88
2.95
Load Transfer
Rq'd
Do Nothing
0.17
Monitor
1.12
0.51
Solution
Required
Do Nothing
0.82
Monitor
Location
Feeder
West Pennant
Hills
West Pennant
Hills
West Wetherill
Park
West Wetherill
Park
Wetherill Park
x866
wq1253
Whalan
wh1224
Whalan
wh1257
Whalan
wh1276
Windsor
wd1225
Windsor
wd1251
Windsor
wd1258
Woodpark
m169
x867
wx1244
wx1280
Season
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
Summer
Winter
13/14 Actual
14/15
15/16
0.0%
0.0%
0.0%
0.0%
0.0%
1.9%
0.0%
0.0%
0.0%
0.0%
0.0%
37.1%
22.9%
16.5%
19.4%
20.5%
13.7%
16.5%
47.1%
38.2%
41.6%
2.9%
0.0%
0.0%
14.0%
5.0%
10.1%
3.0%
0.0%
0.0%
0.0%
5.4%
6.0%
0.0%
0.0%
0.0%
0.0%
5.8%
6.5%
0.0%
0.0%
0.0%
0.0%
2.1%
2.7%
0.0%
0.0%
0.0%
0.0%
13.2%
17.1%
0.0%
0.0%
0.0%
41.2%
57.6%
62.9%
15.9%
32.7%
37.2%
11.5%
29.5%
33.9%
0.0%
0.0%
0.0%
17.5%
6.3%
9.1%
0.0%
0.0%
0.0%
Table 176: Overloaded primary distribution feeders
Reduction
Required
(MVA)
0.09
Monitor
1.70
Monitor
1.04
0.64
Load Transfer
Rq'd
Load Transfer
Rq'd
HVC
0.27
Monitor
0.30
Monitor
0.12
Monitor
0.78
Monitor
2.88
1.55
Load Transfer
Rq'd
Existing Project
0.80
Cap + Fdr
2.15
Potential
Solution
5.0
NETWORK INVESTMENT
5.1
RIT-D’S COMPLETED OR IN PROGRESS
For more information regarding the Screening Results see Section 9.1.1.
There are no RIT-Ds currently in progress. The following is a list of projects that are in progress under
the former Regulatory Test as part of transitional arrangements to the new rules.
RIT-D Project
Far South Coast
132kV Voltage
constraints
(PR479)
Menangle Park
ZS (PR258)
Liverpool CBD
(PR673)
RIT-D
Status
Transitional
Project
Identified need
Voltage issues in the
far South Coast area
(Shoalhaven/Nowra)
Options
Analysis
underway
New residential
development driven by
Urban Growth NSW
Transitional
Project
Thermal capacity
constraints in Liverpool
CBD
Impact on
Network Users
Project Cost
Improved
voltage in
subject area
Project Cost
Screening
Result
Not
Feasible
Credible options
Not
Feasible
Project Cost and
ability for new
customers to
connect
Not
Feasible
1. Build new ZS
2. Install temporary or mobile
substation
3. Develop 11kV capacity
1. Augment 11kV feeder
capacity and 11kV
switchboard
2. Build new zone substation
1. Build new TransGrid BSP
2. Install reactive voltage
support
Table 177: Project proposed for transitional RIT-D exemption – high level summary
Discussion on RIT-D Projects Proposed to be Exempt from RIT-D
Far South Coast 132kV Voltage Constraints
The existing ‘Southern’ South Coast 132kV network extends from Dapto BSP in the Wollongong area
down to the interface with Essential Energy’s Batemans Bay and Moruya North system (beyond Evans
Lane SS). Following a review of forecasts and transmission line ratings for the area, it has been
established via joint planning with TransGrid, that a new bulk supply point for the area can be deferred
indefinitely if voltage constraints in Endeavour Energy’s network are able to be managed. Current
analysis indicates that transformers in the transmission and zone substations in the region reach their
tapping range limits under peak load conditions from 2014. Since capacity constraints are no longer
present, a bulk supply point is no longer the preferred network option to address the remaining voltage
related constraints. Accordingly, this project will address the issue of voltage constraints.
Menangle Park ZS
The Menangle Park urban release area was rezoned by the Minister for Planning and Infrastructure as
part of the Gateway Determination process and allows for approximately 3,400 lots, a commercial
centre, employment lands and community and recreational facilities. A significant proportion of this area
is being developed by Urban Growth NSW. The existing electrical infrastructure in the area caters for
existing rural uses. The closest zone substations are Nepean ZS, 6km to the North, and Ambarvale ZS,
approximately 6km to the North East. Two 66kV feeders run on either side of the development area and
TransGrid’s Macarthur Bulk Supply point is located on the northern boundary of the area. Approximately
200 lots are able to be supplied from the existing distribution network and any further growth in demand
will require a new zone substation to be established.
Liverpool CBD
This project is required to mitigate existing thermal capacity constraints associated with the 11kV CBD
underground feeder cable network and to provide capacity for ongoing development in the Liverpool City
Centre. Residential and commercial developments currently occurring in the CBD include 29 registered
development applications with Liverpool City Council to September 2013 with 19 of these approved or
under construction and 14 load applications processed by Endeavour Energy. Load growth from CBD
development has depleted spare capacity in several 11kV CBD feeders. Proposed development over the
next 3 years is at risk of being compromised if nothing is done to address the identified capacity
constraints.
Projects in Progress
RIT-D Project
Feeders 851 &
582 Southern
Nepean *
Cost of Preferred
Option ($m)
Under investigation
Construction
Timetable
2015/16
Credible Options
1. Third 66kV Feeder
2. Non-network option –
embedded generation
Net economic Benefit
($m)
Under investigation
Table 178: RIT-D projects in progress – high level summary *Endeavour is seeking formal clarification as to whether this project may
be exempted from RID-D.
Discussion on RIT-D Projects in Progress
Feeder 308 Nepean TS – Douglas Park SS
The 66kV feeders 851 and 852 supply the southern Nepean area which includes eight major customer
zone substations and five Endeavour Energy substations The feeders are rated at 60 MVA Summer
each. There are two major embedded generation plants at major customer sites. There is a potential of a
combined generation output is 55 – 60 MW. However, there is no guarantee of supply and any minimum
generation level. At times, during peak, the generation output has dropped below critical levels exposing
the sub-transmission network to load at risk.
Projects Completed
No RIT-D projects have been completed.
RIT-D Project
Cost of Preferred
Option ($m)
Construction
Timetable
Credible Options
Net economic Benefit
($m)
Nil entry
Table 179: RIT-D projects completed – high level summary
Discussion on RIT-D Projects Completed
Nil entry
5.2
UPCOMING RIT-D’S FOR SYSTEM LIMITATIONS
This section provides an estimate of the month and year when the regulatory investment test for
distribution is expected to commence for each identified system limitation requiring the test.
The following table lists the projects that Endeavour Energy expects to commence in the next regulatory
period. All of these projects will service greenfield housing and employment development areas. The
RIT-D dates have not been finalised due to two factors: firstly, a funding determination for the 2014-2019
regulatory period is still in progress; and secondly the projects are all development dependent and the
pace of development and the extent of existing capacity available in the adjacent network will determine
the network need for a particular project which will then determine the RIT-D timing.
RIT-D Project
Limitation
PR184 Box Hill ZS
New release area - Development
dependent project
dependent project
dependent project
PR656 South Leppington
ZS (permanent ZS)
PR190 Eschol Park ZS
PR292 South Marden Park
Stage 2
PR425 Austral ZS
RIT-D
Commencement
To be determined
To be determined
To be determined
To be determined
PR444 Culburra Beach
Development
dependent project
dependent project
dependent project
dependent project
dependent project
PR499 Oakdale Industrial
ZS
dependent project
To be determined
PR427 Leppington North
ZS
PR437 Catherine Field ZS
To be determined
To be determined
To be determined
To be determined
Credible Options




















Establish new ZS
Extend existing distribution network
Establish new ZS
Establish new ZS
Demand Management
Establish new ZS
Establish new ZS
Establish new ZS
Establish new ZS
Establish new ZS
Establish new sub-transmission feeder
Establish new ZS
Table 180: RIT-D projects identified for future analysis – high level summary
depend on pace and progress of development for development dependent projects.
*RIT-D Commencement are indicative and
5.3
COMMITTED INVESTMENTS
A committed project is one that is included in the works program and allocated a scheduled
commencement date. The projects identified below are those that are included in the five year planning
period and have an estimated capital cost of $2 million or more. The projects are also those that
address a refurbishment or replacement need or an urgent and unforeseen network issue.
5.3.1
REFURBISHMENT AND REPLACEMENT INVESTMENTS
Endeavour Energy has identified refurbishment or replacement projects as tabulated below. Discussion
of the alternative options considered by Endeavour Energy is provided below the table.
Project
Number
DS005
Project Name
Description Purpose
Estimated
Cost ($m)
$12.2
Approval
Date
April 2014
Distribution pole
replacement (capital)
Replacement of distribution poles at end of
life
DS006
LV CONSAC cable
replacement
DS007
Replacement of LV CONSAC distribution
cables which are failing at end of life
$9.8
April 2014
Service mains
replacement program
Distribution HV steel
mains replacement
program
Ground substation
refurbishment
Replacement of LV service mains at end of
life
The replacement of 90km of high risk steel
mains in the 2013/14 and 2014/15 years
$59.1
$12.90
January
2014
June 2013
The replacement of ground substations with
padmount substations at end of life
$4.34
June 2014
Distribution
transformer
replacement
Air-break switch
replacement
The replacement of distribution transformers
at end of life
$3.17
June 2014
The replacement of distribution air-break
switches at end of life
$3.03
June 2014
TM012
Sub-transmission
pole replacement
Replacement of sub-transmission poles at
end of life
$2.14
June 2014
TM014
Gas and oil cable
replacement
$7.40
August
2012
TM023
Replacement of
132kV cable 233
Hardex replacement
Replacement of gas and oil insulated 33kV
with specialist maintenance requirements at
end of effective life at Port Kembla.
Replacement of 132kV oil cable 233 at end of
life (After sheath failure and loss of oil)
End of life replacement of Hardex pilot wire
systems on 33kV feeders throughout western
Sydney. Replace with OPGW and/or ADSS
optical fibre. Complete the optical fibre
network between zone substations,
transmission substations and depots
Replacement of steel overhead earthwires on
sub-transmission lines which are corroded
and at risk of failure
Substantial reconstruction of the 33kV
feeders which have reached the end of their
life and which supply the Avon and Nepean
Dam facilities
End of life replacement of Rydalmere ZS.
Indoor 66kV and 11kV switchgear. One new
power transformer, two existing transformers
refurbished and retained.
End of life replacement of Leabons Lane ZS.
New 33kV and 11kV switchgear and low
noise power transformers. Utilising existing
control building with extension.
End of life replacement of St Marys ZS,
utilising existing control building and retaining
some sections of 11kV switchgear
End of life replacement of Guildford TS with
new indoor 132kV and 33kV switchgear and
new power transformers
$8.70
August
2012
September
2012
2015
$5.48
Oct 2013
2015
$8.70
Feb 2014
2017
$22.40
August
2010
2017
$16.10
July 2011
2015
$18.10
July 2011
2015
$62.5
December
2008
2015
DS011
DS301
DS302
DS405
TM133
TM171
Replacement of
overhead earthwires
TM404
TS102
Refurbishment of the
Mittagong to
Avon/Nepean Dam
33kV feeders
Rydalmere ZS
TS122
Leabons Lane ZS
TS123
St Marys ZS
TS125
Guildford TS
$24.90
Completion
Date
June 2015
(ongoing
program)
June 2015
(ongoing
program)
June 2019
June 2015
(ongoing
program)
June 2015
(ongoing
program)
June 2015
(ongoing
program)
June 2015
(ongoing
program)
June 2015
(ongoing
program)
2016
2015
Project
Number
TS127
Project Name
Description Purpose
Castle Hill ZS
TS143
Westmead ZS
End of life replacement of Castle Hill ZS.
Refurbished outdoor 66kV and indoor 11kV
switchgear. Retain existing new low noise
power transformers and 66kV CBs.
Replacement of power transformers, 33kV
switchgear, auxiliary switchgear and
protection and control. Replacement of 11kV
oil CB’s with vacuum trucks
Estimated
Cost ($m)
$14.0
Approval
Date
September
2009
Completion
Date
2015
$7.40
April 2012
2016
Table 181: Refurbishment, replacement need
Discussion of Alternative Options Identified
The following table provides further detail of each of the projects listed above including a discussion of
alternative options considered.
Project
Number
DS005
Project Name
Location
Distribution pole
replacement
Various
Alternative Options
Considered
Nil
DS006
LV CONSAC cable
replacement
Various
Nil
DS007
Service mains
replacement
program
Distribution HV
steel mains
replacement
Various
Nil
Various
rural
locations
Nil
DS301
Ground substation
refurbishment
Various
DS302
Distribution
transformer
replacement
Air-break switch
replacement
Various
 Decommissioning of the
substation
 Replacing with a
padmount substation
 Replacing with an indoor
substation
Nil
Various
Nil
TM012
Sub-transmission
pole replacement
Various
Nil
TM014
Gas and oil cable
replacement
Outer
Harbour –
Port Kembla
TM023
Replacement of
132kV cable 233
Parramatta Rosehill
 Run to failure
 Continued maintenance
of the cables
 Replacement with low
maintenance XLPE
technology
 Replace failed section in
same route
 Replace whole cable on
new route
TM133
Hardex
replacement with
optical fibre
Western
Sydney
 Continued maintenance
of existing HARDEX
pilot/earthwire system.
 Replacement like for like
with copper pilots
TM171
Replacement of
overhead
earthwires
South Coast
 Earthwires removed
 Earthwires replaced
DS011
DS405
Preferred Option Rationale
Poles are replaced at end of life. The lines are
required in their current positions for the
foreseeable future
No feasible alternative at present. The cables
are required to supply customers for the
foreseeable future
No feasible alternative at present. The service
mains are required to supply customers for the
foreseeable future
No feasible alternative at present. Risk of
initiating bushfire and safety impacts to rural
personnel are drivers. In the future, stand-alone
remote area power supplies may provide an
alternative option
Different solutions are selected based on the
needs at each site
The transformers are replaced at end of life.
The substations are required in their current
positions for the foreseeable future
Switches are replaced at end of life. The
switches are required in their current positions
for the foreseeable future
Poles are replaced at end of life. The lines are
required in their current positions for the
foreseeable future
EE does not have the skills to continue to
maintain these types of cables. Furthermore,
EE currently has a policy of replacing subtransmission assets prior to failure so that
replacement can be affected in an efficient
manner
EE does not have the skills to continue to
maintain these types of cables. Furthermore,
EE currently has a policy of replacing subtransmission assets prior to failure. Existing
route was congested and failure occurred under
major roadway. Cable capacity required for
foreseeable future. New route selected for
replacement cable.
Continued failures causing loss of feeders ruled
out continuance of maintenance. Optical fibre
replacement similar cost as copper and
provided additional benefits of SCADA, security,
engineering and corporate communications.
Earthwires are removed and or replaced at
different locations depending on the
requirements at each location
Project
Number
TM404
Project Name
Location
Refurbishment of
the Mittagong to
Avon/Nepean Dam
33kV feeders
Mittagong
TS102
Rydalmere ZS
Redevelopment
Rydalmere
TS122
Leabons Lane ZS
Redevelopment
Seven Hills
TS123
St Marys ZS
Redevelopment
St Marys
TS125
Guildford TS
Guildford
TS127
Castle Hill ZS
Redevelopment
Castle Hill
Alternative Options
Considered
 Rebuild line in situ
 Rebuild line on a new
alignment
 Provide a new line to the
dams from either
Cordeaux or Tahmoor
 Use existing network
 Like for like piecemeal
replacement
 Replacement on another
site
 Redevelopment within
existing site
 Redevelopment on
existing site including
purchase of adjacent
property
replacement
existing site with new
control building
11kV in control building
and outdoor 33kV
switchyard
 Redevelopment of 33kV
and 11kV within existing
site retaining and
extending existing
control building.
replacement
control building.
existing site retaining
and extending existing
control building.
replacement
control building.
 Redevelopment on
adjacent site
(remove after Cheriton
Ave ZS commissioned).
replacement.
Rebuilding the line on a new alignment provide
the lowest cost option which met with outage
requirements. There were no non-network
solutions available for these lines given the
critical water supply infrastructure which they
supplied.
The substation was required in the same
location with the same capacity for the
foreseeable future. Primary, secondary and
ancillary equipment had reached the end of its
life. Transformer noise levels needed to be
reduced. Rebuilding on the existing site
including purchase of the property next door
was the lowest cost practicable option.
reduced. New 33kV and 11kV indoor switchgear
within the existing control building after
extension was the lowest cost practicable option
reduced. New indoor switchgear within the
existing control building after extension was the
lowest cost practicable option
location with the same capacity but increased
functionality as the 132kV switching hub for the
Parramatta CBD area. The 132kV switchyard
and power transformers reached the end of
their lives and there were limitations on the
33kV switchgear fault rating. Given the critical
role the substation played in supplying
Parramatta CBD, construction of a new indoor
GIS substation adjacent the existing substation
whilst the existing substation remained in
service was the most practicable option
reduced. New indoor switchgear within the
existing control building after extension was the
lowest cost practicable option
Project
Number
TS143
Project Name
Location
Westmead ZS
Westmead
Alternative Options
Considered
 Decommission 33kV
switchgear
 Replace 11kV
switchboard
 Replacement of 11kV
CBs with vacuum trucks
The piecemeal replacement approach in this
instance allowed the substation to be renewed
and transformers and 33kV switchgear replaced
whilst maintaining supply to the principle
customer, which was Westmead Hospital
Table 182: Refurbishment, replacement need – project details
5.3.2
URGENT AND UNFORSEEN INVESTMENTS
The identified urgent and unforeseen network issues are tabulated below.
Project
Number
Nil entry
Project Name
Description Purpose
Estimated
Cost ($m)
Table 183: Urgent and unforseen network issues
Approval
Date
Completion
Date
Alternative Options
6.0
JOINT PLANNING
Joint Planning is carried out with TransGrid on a biannual basis. Minutes are maintained and action
plans developed. Areas where network limitations and/or network developments affect the electricity
networks on both TransGrid and Endeavour Energy as discussed below.
6.1
JOINT PLANNING WITH TRANSGRID
6.1.1
PROCESS & METHODOLOGY
Endeavour Energy confers with TransGrid on technical matters relating to Endeavour Energy’s
connections with TransGrid at all TransGrid bulk supply points (TransGrid connection points). These
matters include:

Forecast loads for all BSP’s supplying Endeavour Energy

Supply capability at all BSP’s supplying Endeavour Energy

Exchange of system modelling data

Coordination of loading requirements on individual BSP’s and across other BSP’s

New BSP requirements and connection arrangements

Coordination of communication, protection and control requirements

Coordination of other operational requirements
Clause 5.14.1 of 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
planning process are:

DNSP supply point load forecasts

Review of network capacity and utilisation

Planning criteria and indicators

Condition, operational and risk assessments

Transmission network load-flow analysis

TransGrid planning reviews
Endeavour Energy does not have any assets that are classed as “dual function assets” under the NER.
The relationship between the various elements in the planning process is shown in Figure 15.
Network Limitation Identification
Condition Assessment, Network Capability & Utilisation, Load-flow
Analysis, Risk & Operational Issues, Planning Standards
Network
Analysis
(Endeavour)
Network
Analysis
(TransGrid)
Network Limitations
Network Limitations
Supply Side
Options
Joint Planning
Non-network
Options
Proposed
Project
Future
Connection
Point
DNSPs
Load
Forecast
Annual Planning Review
Publish
Annual Planning Report
Figure 15: Joint planning process with TNSP
6.1.2
DESCRIPTION OF INVESTMENTS
Tomerong Bulk Supply Point (Deferred)
Following a review of forecasts and transmission line ratings for the South Coast area, it has been
established via joint planning with TransGrid, that a new bulk supply point for the area can be deferred
indefinitely if voltage constraints in the Endeavour network and at Esssential Energy substation supplied
out of this network, are able to be managed. Current analysis indicates that the transformers in
transmission and zone substations in the region begin to reach their maximum tapping range during
peak load conditions from 2014. Since capacity constraints have been eliminated, a bulk supply point is
no longer the preferred network option to address the remaining voltage related constraints. Accordingly
Endeavour Energy has initiated a project to address the issue of voltage constraints and this project is
being developed in consultation with Transgrid and Essential Energy.
6.1.3
ADDITIONAL INFORMATION
Endeavour Energy and TransGrid have engaged in a process to formalise joint planning arrangements
between the two entities.
Endeavour Energy has also entered into a joint planning process for planning the supply strategy for the
Broader Western Sydney Employment Area and South West Growth Centres.
There are plans to expand the joint planning arrangements from a working group model to a working
group and executive steering committee model. The terms of reference for this arrangement are
currently being developed.
6.2
JOINT PLANNING WITH OTHER DNSP
Endeavour Energy follows the same principles outlined above when jointly planning with Ausgrid and
Essential Energy. However due to the limited number of network dependencies between the
organisations, joint planning meetings may only take place once per year unless a particular issue has
been identified and particularly needs to be progressed and monitored.
With the formation of Networks NSW closer cooperation with Essential Energy and Ausgrid has become
‘business as usual’ which facilitates formal joint planning when the need arises.
6.2.1
PROCESS & METHODOLOGY
Endeavour Energy enters into joint planning processes with Ausgrid and Essential Energy as needs
dictate. Formal joint planning meetings between the planning groups of the two organisations form the
basis of the joint planning process.
6.2.2
JOINT DNSP PLANNING COMPLETED IN PRECEEDING YEAR
Endeavour Energy conducted joint planning with Ausgrid in relation to

A proposal to take supply from Camellia Sub-transmission Station for Ausgrid’s Auburn and
Lidcombe Zone Substations and development of a draft operating agreement for this proposal

Options for temporary and permanent supply the North West Rail Link

Options to supply cross border developments at South Dural

Options for temporary and permanent supply to the North Connex Project
Endeavour Energy conducted joint planning with Essential Energy in relation to:

The Endeavour Energy project to address voltage constraints in the far South Coast region
where Essential Energy takes supply from the Endeavour Energy network in the area
6.2.3
PLANNED DNSP JOINT NETWORK INVESTMENTS
There are currently no planned joint network investments with other DNSPs.
6.2.4
ADDITIONAL INFORMATION
Nil entry.
7.0
NETWORK PERFORMANCE
7.1
NETWORK RELIABILITY
Reliability of supply is an important measure of the performance of the electrical network. Network
reliability is indicated with the System Average Interruption Duration Index (SAIDI). This measure shows
the number of unplanned minutes that Endeavour Energy’s customers are without electricity each year,
on average excluding the impact of significant storms.
Endeavour Energy’s SAIDI has improved from 126 minutes in 2003/04 to 83 minutes at the end of June
2014. This means Endeavour Energy’s network is among the most reliable in Australia. Events that had
a significant impact on the reliability result in 2013/14 include:

46 interruptions to the sub-transmission network (zone substations, sub-transmission substations
and sub-transmission feeders) which contributed approximately 7.1 minutes of SAIDI, mainly due
to adverse weather and defective equipment and interference on the lines;

2,092 interruptions to the distribution network (distribution feeder and distribution substation)
which contributed 70.4 minutes of SAIDI, mainly due to defective equipment, interference to the
lines, adverse weather and trees and branches contacting lines.

1,894 interruptions to the Low Voltage network (low voltage substation and below) which
contributed 5.2 minutes of SAIDI, mainly due to defective equipment and interference to the lines.
Climate conditions continue to be a major factor in overall reliability outcome with record mild and warm
weather conditions over autumn and early winter. This resulted in a decrease in the number of days
where SAIDI was above 1 minute (nominally 40% of the Major Event exclusion threshold. These days
are typically associated with adverse weather conditions that are not severe enough to be excluded as
Major Events. The chart below demonstrates that there is a direct relationship between these days and
the overall SAIDI performance of the network. The impact of major events is excluded from the
performance statistics. Notwithstanding this, Endeavour Energy’s average level of reliability is
significantly better than that defined in the Licence Conditions.
100
90
80
70
60
50
40
30
20
10
0
2009/10
2010/11
Cumulative High SAIDI
2011/12
No. days High SAIDI
Figure 16: Historical reliability performance
2012/13
Endeavour Energy annual SAIDI
2013/14
7.2
NETWORK QUALITY OF SUPPLY
Endeavour Energy has published its technical service standards within Section 3.2 of its Customer
Service Standards for Connection Customers (the Customer Service Standards), which has been
prepared in accordance with the NSW Electricity Service Standards Code of Practice.
The Customer Service Standards include descriptions of the power quality that customers can expect to
receive and the disturbances that may occur on the network – including changes in voltage levels, rapid
voltage fluctuations resulting in flicker, voltage transients, voltage dips, waveform distortion (harmonics
and inter-harmonics) and voltage unbalance.
The Customer Service Standards refer to AS/NZS61000.3.6 for harmonic levels and AS/NZS61000.3.7
for voltage fluctuations. These documents require the Network Service Provider to establish acceptable
levels for planning purposes. Endeavour Energy applies the planning levels published in the Standards
Australia Handbook HB264.
AS61000.3.100 specifies that the voltage at the customer connection point for 230/400V systems should
be within the range of +10%, -6% of nominal for 98% of the time (99th and 1st percentile limits). The
Customer Service Standards specify a wider guaranteed range of +14%, -6% of nominal allowing for
abnormal system conditions.
A copy of the Customer Service Standards for Connection Customers can be downloaded from:
http://www.endeavourenergy.com.au/wps/wcm/connect/EE/NSW/NSW+Homepage/forHomesNav/Custo
mer+service+standards/
Details of Endeavour Energy’s quality of supply standards, complaint performance data and
investigations are shown in the following tables.
Power Quality Standard
Frequency of Supply
Low Voltage Supply – Line to Neutral
Low Voltage Supply – Line to Line
Medium Voltage Supply – Line to Line
Nominal
50Hz
230 Volts
400 Volts
11, 22, 33 & 66kV
Generally not exceed
8%
10 V
6%
3%
Refer to Customer Service Standards
Rapid fluctuation in voltage level
Voltage difference – neutral to earth
Voltage unbalance – phase to phase - LV
Voltage unbalance – phase to phase - HV
Harmonic content of the voltage waveform
Interharmonics
Mains signalling
Flicker
Range
49.5 to 50.5 Hz
+14% to -6%
+14% to -6%
+10% to -10%
Maximum Limit
10%
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Table 184: Quality of supply standards
Year
Complaints Total
Complaints per 1,000 Distribution Customers
Complaints regarding Vegetation Management
2009/10
1,024
1.19
183
Previous Years
2010/11
2011/12
995
1,050
1.14
1.19
344
434
2012/13
1,123
1.24
504
Current Year
2013/14
930
1.01
419
Table 185: Complaint performance data
Voltage
Current
Other Quality
Reliability
Safety
Number
232
1
10
240
9
Table 186: Network complaint investigations complete current year
Number Valid*
35
0
0
0
0
*A complaint is valid where non-compliance with published
service and network standards occur
The total complaints given in Table 185 include complaints relating to supply quality, safety, vegetation
management and other miscellaneous complaints. The values given in Table 186 do not include
vegetation management and other miscellaneous complaints included in total complaints given in Table
185.
7.2.1
NETWORK QUALITY OF SUPPLY CORRECTIVE ACTION
There were no substantive issues related to power quality that were not addressed in the 2013/14 year.
7.3
COMPLIANCE PROCESSES
Endeavour Energy is required to design, maintain and operate its network in a cost effective manner to
provide reliable power supply to its connected customers. The objectives of power quality fall within this
overall framework.
Power quality issues are frequently related to specific loads connected to the network. In order to
appropriately manage these effects, Endeavour Energy shall place requirements on connected
customers to ensure that power quality is maintained. These requirements are stated in Company Policy
9.6.1 – Network Connection, the Customer Service Standards for Connected Customers and the Service
and Installation Rules of NSW. Customers are advised of these requirements by reference to the
Customer Service Standards for Connected Customers and the Service and Installation Rules of NSW.
7.4
SERVICE TARGET PERFORMANCE INCENTIVE SCHEME SUBMISSION
100
2.0
90
1.8
80
1.6
70
1.4
60
1.2
50
1.0
40
0.8
30
0.6
20
0.4
10
0.2
SAIFI
SAIDI
As part of the AER’s STPIS scheme Endeavour has proposed an alternative normalisation methodology
to derive major event day exclusion thresholds. This was accepted by the AER. The normalised SAIDI
and SAIFI performance for the last regulatory period based on the alternate normalisation methodology
as well as Endeavour’s proposed targets (5 year average) and the AER draft determination targets for
the next regulatory period are shown in Figure 17.
0.0
0
2009/10
2010/11
2011/12
2012/13
2013/14
2014/15
2015/16
2016/17
Year
Target (5 Year Average)
Target (5 Year Average)
Linear (Organisation SAIFI)
Organisation SAIDI
Organisation SAIFI
Linear (Organisation SAIDI)
2017/18
2018/19
Target (AER draft)
Target (AER draft)
Figure 17: Organisational SAID and SAIFI trends (box-cox normalised) and STPIS targets
The SAIDI and SAIFI unplanned performance results (excluding major events) will be compared to the
STPIS targets as shown in the tables below in future releases of the DAPR.
Category
Urban
Rural
Actual
2014/15
Nil entry
Nil entry
2014/15
60.3
175.9
2015/16
60.3
175.9
SAIDI Targets
2016/17
60.3
175.9
2017/18
60.3
175.9
2018/19
60.3
175.9
2014/15
0.794
1.798
2015/16
0.794
1.798
SAIFI Targets
2016/17
0.794
1.798
2017/18
0.794
1.798
2018/19
0.794
1.798
Table 187: STPIS targets vs actuals
Category
Urban
Rural
Actual
2014/15
Nil entry
Nil entry
Table 188: STPIS targets vs actuals
8.0
ASSET MANAGEMENT
8.1
ENDEAVOUR ENERGY’S ASSET MANAGEMENT APPROACH
A sustainable network is one that enables consistent levels of safety and reliability to be maintained over
long asset lives while minimising volatility in the costs of provision of that service. This objective directly
supports the overall Company objective of ensuring financial sustainability through effective investment
in and efficient operation of the network asset.
The sustainable operation of the network is considered from a number of perspectives.
8.1.1
NETWORK STANDARDS
Engineering standards have been developed that cover the range of network equipment and asset
management activities and take into account consideration of life cycle analysis, the condition of the
assets and the Company’s business needs. The standards that are implemented are not compromised
to obtain short term cost savings. Rather, the standards are implemented that optimise the whole-of-life
asset cost to provide the desired level of safe and reliable operation over the design life of the asset.
The recent restructuring of the three NSW electricity distribution businesses provides Endeavour Energy
with an opportunity to benchmark its engineering standards against those of the other NSW distribution
businesses to ensure that they continue to effectively facilitate the achievement of the companies
objectives.
8.1.2
ASSET RENEWAL
It is an asset management objective of Endeavour Energy that the average age of the network
components will not be allowed to deteriorate to unacceptable levels as this will result in service
outcomes that fall outside of safety and reliability standards and fail to meet customer needs and
expectations. Conversely, a network asset that has an average age that is too young will not represent
an efficient use of resources.
The Weighted Average Remaining Life (WARL) of the asset base measures the remaining life of the
network assets, taking into account both age and condition issues. The projected WARL of Endeavour
Energy’s asset base is shown in the figure below. The figure shows that historic and projected
expenditure levels will arrest the previous decline in WARL and cause it to plateau at a target level of
50% ± 5%. This is considered to be a result with an appropriate balance between network risk and asset
replacement expenditure.
75%
70%
65%
WARL
60%
55%
50%
45%
Past
Future
Figure 18: Weighted average remaining life of network asset
2030
2029
2028
2027
2026
2025
2024
2023
2022
2021
2020
2019
2018
2017
2016
2015
2014
2013
2012
2011
2010
2009
2008
2007
2006
2005
2004
2003
2002
2001
2000
1999
1998
1997
1996
1995
1994
1993
1992
40%
8.1.3
OPTIMISING THE UTILISATION OF THE NETWORK ASSETS
Endeavour Energy has invested during the 2009-2014 regulatory period to provide network capacity that
meets the supply security standards of the NSW Design, Reliability and Performance Licence
Conditions. The Supply Security Standards set out in Schedule 1 of the Licence Conditions have been
repealed by the Minister for Energy and the changes will take effect on 1 July 2014. Reliability Standards
in Schedules 2 and 3 of the Licence Conditions remain in place, as well as a corporate objective to
maintain existing levels of reliability performance. As such, for future network investment, the level of
supply security will be subject to assessment of reliability risk and cost benefit analysis, rather than
mandated minimum supply security levels. An objective of capacity planning is to maximise the length of
time before these assets require further augmentation. This can be achieved by demand side
management to increase asset utilisation and investigation and application of cyclic and emergency
ratings of assets where available.
8.1.4
FUTURE PROOFING THE NETWORK
By the end of the 2014-19 regulatory period the demands expected to be placed on the network will be
significantly different from those that have been placed on it for much of its life to date. These demands
arise mainly from a trend towards lower carbon intensity distributed generation to minimise the
environmental costs associated with the existing large scale coal-fired generation. Effective management
of the network in the presence of distributed generation will require better visibility and controllability of a
range of network parameters and an appropriate degree of intelligence to be built into the network will be
required to assist in the management of these parameters.
The strategy for introducing technology to the network is focused on areas where trials of the intended
systems or technology have proven their cost-effectiveness. The strategy also recognises that
investment in proving technologies that are likely to enable better network management is important to
ensure that appropriate solutions are available for use as new demands on the network require them.
8.1.5
CUSTOMER ENGAGEMENT
To ensure that customers receive an efficient energy distribution service it is necessary to understand
and respond to customers’ needs and concerns. The Networks NSW Customer Value Strategic Plan
details the strategic focus areas and the initiatives to be undertaken in each area to achieve this. The
strategic focus areas set out in the plan are:

Understand our Customers and Stakeholders;

Evaluate and Respond to Customer and Stakeholder feedback;

Communicate with Customers; and

Measure our success in Customer and Stakeholder engagement.
8.2
DEMAND MANAGEMENT
Endeavour Energy considers non-network alternatives to augmentation such as demand management
and embedded generation to be important aspects of optimising the available capacity in the network to
meet the forecast demand. Endeavour’s Demand Management policies and procedures ensure that
investigations into non-network options are conducted in accordance with the National Electricity Rules.
Furthermore, the public consultation process for soliciting non-network options from interested
stakeholders has been adopted. To this end, a Demand Side Engagement Document exists on
Endeavour’s web site that explains how any interested party can make a submission for non-network
options.
Non-network alternatives are generally designed to reduce the need for network capacity by moving
demand that occurs at peak times to times of lower overall demand. The figure below demonstrates the
potential impact on peak demand that may be achieved by controlling air conditioning load for instance.
The demand management strategy is focused on the use of non-network alternatives to augmentation.
Trials have been conducted using innovative systems or technologies to determine their technical and
economic feasibility to reduce peak demand. These proven technologies have added to the Company’s
demand management capability. Pilots and trials of innovative demand management initiatives will
continue to be conducted in order to keep abreast of new technologies as they become available to
deliver the desired outcome of effectively managing peak demand across the network to control the
trend of declining load factor.
7
6
Energy Consumption (kWh)
5
4
3
2
1
Coolsaver Baseline
12 AM
11 PM
10 PM
9 PM
8 PM
7 PM
6 PM
5 PM
4 PM
3 PM
2 PM
1 PM
12 PM
11 AM
10 AM
9 AM
8 AM
7 AM
6 AM
5 AM
4 AM
3 AM
2 AM
1 AM
0
Coolsaver Participants
Figure 19: Peak demand reduction using air conditioning control (CoolSaver) on 31 January 2014
8.2.1
STRATEGIC ASSET MANAGEMENT PLAN
Capital and maintenance expenditure programs to support this strategy are implemented through a suite
of asset management plans termed the Strategic Asset Management Plan (SAMP). The key components
of the SAMP are the Strategic Asset Renewal Plan (SARP), the Network Maintenance Implementation
Plan (NMIP) and plans for managing demand growth that consider forecast demand, forecasts of new
connections and demand management opportunities.
A key function of the SAMP is to prioritise the asset management projects and programs of expenditure
and to discuss and document the trade-offs that are made in developing the year ahead and ten-year
network expenditure forecasts. In combination with the SAMP Delivery Plan the SAMP helps to ensure
the efficient and timely delivery of projects and programs.
Effective achievement of the strategic network objectives requires an assessment of the impact on
network outcomes that each proposed project or work program will have. Individual plans are developed
in the key expenditure areas based on asset need. The SAMP uses a risk-based project prioritisation
framework to integrate and prioritise these plans into an overall capital and operating expenditure
program with appropriate input from relevant stakeholders.
By understanding the relative risks associated with the individual component projects and programs, the
SAMP also enables the effective evaluation of capital and operating expenditure trade-offs.
End to end oversight of this process is provided by the Endeavour Energy Investment Governance
Committee, the Networks NSW Network Steering Committee and ultimately the Board. Together, these
bodies ensure that the content of the asset management plans is prudent and efficient, that it is
developed using a sound process and recognises the Company’s customer value objective and that the
expenditure proposed is subject to appropriate scrutiny in the planning and delivery process.
8.3
NETWORK ISSUES IMPACTING IDENTIFIED SYSTEM LIMITATIONS
Endeavour Energy faces several network challenges and opportunities in relation to managing network
assets and the limitations that arise. These include assessment of asset ratings, the impact of Solar PV
and longer term issues such as energy storage systems and electric vehicles. These issues are being
addressed via: network investigations; industry committees; and production of standards. These are
further discussed below.
8.3.1
ASSET RATINGS
Endeavour Energy investigates potential cyclic or emergency rating of assets to confirm network
constraints. This ensures optimal utilisation of existing network assets and presents opportunities for
deferral of expenditure.
8.3.2
SOLAR PHOTOVOLTAIC (PV)
Thousands
The overall growth in photovoltaic embedded generation has continued despite changes to the feed in
tariffs as shown in Figure 20 below and is continuing to challenge the performance of the distribution
network.
100
90
80
Cumulative Connections
70
60
50
40
30
20
10
Oct 14
Sep 14
Jul 14
Aug 14
Jun 14
Apr 14
May 14
Mar 14
Jan 14
Feb 14
Dec 13
Oct 13
Nov 13
Sep 13
Jul 13
Aug 13
Jun 13
Apr 13
May 13
Mar 13
Jan 13
Feb 13
Dec 12
Oct 12
Nov 12
Sep 12
Jul 12
Aug 12
Jun 12
Apr 12
May 12
Mar 12
Jan 12
Feb 12
Dec 11
Oct 11
Nov 11
Sep 11
Jul 11
Aug 11
Jun 11
Apr 11
May 11
Mar 11
Jan 11
Feb 11
Dec 10
Oct 10
Nov 10
Sep 10
Jul 10
Aug 10
Jun 10
Apr 10
May 10
Mar 10
Jan 10
Feb 10
0
Figure 20: Grid connected solar PV systems
Endeavour Energy continues to monitor the impacts of solar panels which, in some areas, have
materially reduced demand. Areas with demand that peaks later in the afternoon or evening have little
effect from PV generation on peak demand. What it does do is to reduce the duration of the peak and
reduce the thermal heating of some parts of the network during the day.
Other effects from PV include the impact on the quality of supply. Traditionally, distribution networks
were designed to accommodate voltage drops arising from the flow of power from the high voltage
systems through to low voltage system. With the connection of PV on distribution network, particularly
the large number of connections of rooftop solar PV, has come power flows in the reverse direction from
the LV to HV at times of peak solar generation and low demand. This reverse power flow is less
predictable and leads to both voltage rise and voltage drop along the feeding network having to be
managed to ensure voltage at the customer site remains within statutory voltage limits. Listed in Figure
21 is the number of complaints received relating to PV (inverters) compared to total quality of supply
complaints.
70
45%
40%
60
35%
50
40
Jobs
25%
20%
30
% Solar Jobs
30%
15%
20
10%
10
5%
0%
Jun 10
Jul 10
Aug 10
Sep 10
Oct 10
Nov 10
Dec 10
Jan 11
Feb 11
Mar 11
Apr 11
May 11
Jun 11
Jul 11
Aug 11
Sep 11
Oct 11
Nov 11
Dec 11
Jan 12
Feb 12
Mar 12
Apr 12
May 12
Jun 12
Jul 12
Aug 12
Sep 12
Oct 12
Nov 12
Dec 12
Jan 13
Feb 13
Mar 13
Apr 13
May 13
Jun 13
Jul 13
Aug 13
Sep 13
Oct 13
Nov 13
Dec 13
Jan 14
Feb 14
Mar 14
Apr 14
May 14
Jun 14
Jul 14
Aug 14
Sep 14
0
Inverter
No inverter
Total
% Inverter
Cumulative %
Figure 21: Power quality complaints
8.3.3
FUTURE IMPACTS OF BATTERY ENERGY STORAGE SYSTEMS
As with PV connection, batteries will be connected to the network via inverters. Consequently, there is a
natural progression for PV customers to consider installing a Battery Energy Storage System. These
systems could provide flexibility for Endeavour Energy to use the stored energy for export during critical
peak times. It would also allow the consumers to make use of time-of-use tariffs.
It is envisaged that consumers may seek to install a Battery Storage System for usage within the home
rather than for export. Preliminary cost benefit analysis has shown that with the feed-in tariff higher than
electricity price, customers intend to export as much energy as possible into the grid.
Over time, as feed-in tariffs reduce and the benefits dissipate, it is expected that output from solar PVs
will be used more for internal consumption. It is expected that there will be a growing incentive for
consumers to utilise the generation output from solar PVs for internal consumption via battery storage.
This may result in a reduction in voltage complaints as the exporting of energy reduces.
8.3.4
ELECTRIC VEHICLES
Electric Vehicles (EV) is an emerging technology which has attracted a significant amount of interest
over recent years. There exists the potential for EVs charging facilities to be developed with the
capability of discharging the EV battery energy during peak demand times. Endeavour Energy is a
member of the Australian Standards Electric Vehicle Committee, which is charged with the responsibility
of developing standards for connection EVs to the grid and the development of charging / discharging
products.
Network pricing signals will be a key component in developing a demand side participation product to
encourage efficient EV charging behaviour. Controlled EV charging, where the right to charge and
discharge an EV is delegated to the network company (load management) requires technical standards
to be developed that balance the need to maintain network security while enabling different providers to
offer controlled EV charging services. This is part is the Electric Vehicle committee objectives.
8.3.5
OBTAINING FURTHER INFORMATION
MANAGEMENT APPROACH
ON
ENDEAVOUR
ENERGY’S
ASSET
For further information regarding the Endeavour Energy’s Asset Management approach please contact:
Endeavour Energy
Manager – Asset & Network Planning
GPO Box 811
Seven Hills NSW 1730
Email: [email protected]
9.0
DEMAND MANAGEMENT
Endeavour Energy conducts a planning review of the network on an annual basis to identify emerging
network constraints, the timing of the constraint and the level of demand reduction required to remove
the constraint. Each constraint is then analysed to determine credible options to overcome the network
limitation. Network options are developed first to determine if the estimated network cost of the most
expensive credible option is above $5 million. The network constraint is then screened to identify if a
non-network option is feasible. This is the start of the consultation process. The goal is to find the most
cost effective solution that meets the required network reliability standards. The non-network
investigation process is comprised of six separate stages:

Conduct a planning review to identify the emerging network constraints and credible network
options

Conduct Non-network option screening

Where DM is feasible, issue a Non-network Options Report as part of the community consultation
process to obtain proposals from interested parties. This process is run as a Request for
Information (RFI) for probity and due diligence reasons and is subject to internal approval

Evaluate submissions to identify the most cost effective credible non-network option

Perform the RIT-D evaluation on all options to identify the most cost effective options or
combination of options

If a non-network option is identified as the most cost effective option, negotiate with proponents
to implement the program
This is in line with the AER’s RIT-D process and will be followed for all projects where the most
expensive credible option is greater than $5 million
This section of the Distribution Annual Planning Report provides information on Endeavour Energy’s
demand management activities, including a qualitative summary of:

Non-network options that have been considered in the past year, including generation from
embedded generation units

Actions taken to promote non-network proposals in the preceding year, including generation from
embedded generators

Endeavour Energy’s plans for demand management and generation over the forward planning
period
This section should be read in conjunction with Section 4.0 Identified System Limitations.
DEMAND MANAGEMENT ACTIVITIES IN THE PRECEDING YEAR
9.1
The purpose of the screening for non-network options is to determine if the network limitation has a
reasonable opportunity of being deferred or avoided by implementing a non-network option that reduces
the peak demand by the required amount and at the required time of day.
When screening for non-network options Endeavour Energy considers the following areas:


Any measure or program targeted at reducing peak demand, including:

Improvement to or additions of automatic control schemes such as direct load control

Energy efficiency programs or a demand management awareness program for consumers

Installing smart meters with measures to facilitate cost-reflective pricing
Increased local or distributed generation/supply options, including:

Capacity for standby power from existing or new embedded generation

Using energy storage systems, load transfer capacity
Endeavour Energy bears in mind that credible solutions may include a variety of different measures
combined to form one integrated solution when determining whether a non-network option could
constitute part of a credible option.
In deciding if a non-network option is not feasible the RIT-D proponent must provide its reasons and
demonstrate where the non-network option does not meet the criteria for being a feasible option. These
may include such issues as:

could not address the identified need

is not commercially feasible

is not technically feasible

could not be implemented in sufficient time to meet the identified need
9.1.1
SCREENING FOR NON-NETWORK OPTIONS
The following network limitations were screened during 2013/14 for non-network options. The results are
shown in the table below.
Network Connection Point
Marsden Park South ZS
Feeders 851 & 852 Southern
Nepean
Feeder 98P West Tomerong
TS
Liverpool CBD
Constrain Area
New release industrial &
residential areas
Major customer & residential /
rural areas
Supply to Nowra and
Shoalhaven area
Supplying to Liverpool CBD area
Summary of
Constraint
Distribution network
capacity
Feeder capacity
limitation
Feeder capacity
limitation
Feeder capacity
limitation
Screening Test
Result
Not Feasible
Notice
date
*
Feasible
*
Not Feasible
*
Not Feasible
*
Table 189: Screening test results *The requirement to publicly issue the results of screening tests commenced on 1 January 2014. These projects
were screened in 2013/14 and are exempt or classified as being exempt.
Screening Test Result Details
Marsden Park South ZS
The Marsden Park South ZS is required to supply the new release residential and industrial areas. The
existing 11kV network and nearby zone substations do not have sufficient capacity to supply the growth
in demand. The ultimate level of demand for the area is beyond the existing network to supply and the
need for additional network infrastructure cannot be avoided. Consequently, the screening test has
identified that demand management is not feasible and a Non-network Options Report will not be issued.
The planning process will proceed by evaluating the network options.
Feeders 851 & 852 – Southern Nepean
The 66kV feeders 851 and 852 supply the Southern Nepean area. The Southern Nepean area is made
up of eight customer and five Endeavour Energy zone substations. Two of the major customers contain
embedded generation of sufficient size to remove the network constraint. The power factor of the area is
also poor. Consequently, the screening test has identified that a non-network option is feasible to defer
the network limitation. As the main opportunity for demand management exist with the major customers
a Non-Network Options Report will not be issued. Instead, an in-house investigation will be conducted
with the major customers to improve their power factor and negotiate load curtailment agreements. This
will enable the deferment of the network limitation for a seven year period.
Feeder 98P – West Tomerong TS
The 132kV feeder 98P supplies the Southern Shoalhaven area. The Southern Shoalhaven area is made
up of rural / residential load type and multiple township centres. There is a large increase in population
during holiday periods increasing the demand of the area. On outage of this feeder the voltage of the
areas drops to unacceptable levels. The required demand reduction to remove the voltage constraint is
51.6 MVA. The total load of the area is 290 MVA. This represent as load reduction in the order of 18%.
The network option to remove the constraint is to install power factor correction at a relatively low cost.
Consequently, the screening test has identified that demand management is not feasible and a Nonnetwork Options Report will not be issued. The planning process will proceed by evaluating the network
options.
Liverpool CBD
The Liverpool CBD distribution network supplied by the Liverpool Zone Substation and Homepride Zone
Substation (ZS) has diminishing spare capacity across the various feeders of the Liverpool CBD.
Liverpool ZS has 18 feeders, out of which 8 feeders supply the Liverpool CBD, and likewise, Homepride
ZS has 18 feeders, out of which 10 feeders supply the Liverpool CBD. There are currently four feeders
from Liverpool ZS, and four feeders from Homepride ZS that are overloaded or have no spare capacity.
Load switching between feeders has already been implemented to its maximum level, and no further
load switching can be performed between the existing feeders to relieve constrained 11kV feeders.
The screening test identified the required demand reduction to be 3,800 KVA for a two year deferral, and
the available demand reduction potential to be approximately 1,144 KVA in the CBD supplied by the
Liverpool ZS and Homepride ZSs. Other solutions such as embedded generation have limited
opportunity due to space constraints in the Liverpool CBD area. Consequently, the screening test has
identified that demand management is not feasible and a Non-network options report will not be issued.
The planning process will proceed by evaluating the network options.
9.2
DETAILS OF IMPLEMENTED NON-NETWORK PROGRAMS
No non-network programs were implemented during 2013/14.
9.3
PROMOTION OF NON-NETWORK OPTIONS
The promotion of non-network options occurs predominantly through the public consultation process.
The consultation process for non-network option investigation involves the issue of the following reports:

Non-network Options Report

Draft Project Assessment Report

Final Project Assessment Report
Listed below are the actions taken to promote non-network proposals from the preceding year, including
proposals from embedded generating units.
9.3.1
SUMMARY OF NON-NETWORK OPTIONS REPORTS
The network limitations where a non-network options report was issued are shown in Table 190 below.
There are a number of network limitations that will be screened for non-network options during 2014.
These projects are included in Table 191 below. If a non-network option is shown to be feasible then a
Non-network Option Report will be released and the project will be included in Table 190 in the next
release of the DAPR.
Network
Connection Point
Nil entry
Constrain
Area
Summary of
Constraint
Non-Network
Options Issue Date
Timing of
Constraint
Est. Load Reduction
(kVA)
Defer
Years
Table 190: Non-network options reports
Non-network Option Objective-Potential Solutions
No Non-network Option Reports were issued during 2013/14.
9.3.2
SUMMARY OF DRAFT PROJECT ASSESSMENT REPORTS
As the RIT-D process came into force on 1 January 2014, projects that commenced prior to this date are
exempt from the RIT-D process. No new projects have commenced since 1 January 2014. Consequently
no Draft Project Assessment Reports were issue during the 2013/14.
9.3.3
SUMMARY OF FINAL PROJECT ASSESSMENT REPORTS
As the RIT-D process came into force on 1 January 2014, projects that commenced prior to this date are
exempt from the RIT-D process. No new projects have commenced since 1 January 2014. Consequently
no Final Project Assessment Reports were issue during the 2013/14.
9.4
PLANS FOR DEMAND MANAGEMENT AND EMBEDDED GENERATION
Endeavour Energy produces a three year plan where non-network options are investigated in more detail
and potentially a Non-network Options Report is released. The principle factor affecting the investigation
timetable is the forecast load growth. In many situations the load growth is driven by spot load
applications and projected development. The true level of demand that appears on the network needs to
be closely monitored to ensure network limitations are accurately forecast and solutions implemented in
a timely manner.
Listed in Section 4.0 Identified System Limitations, are the current forecast network constraint areas
where a screening test is to be performed for potential feasible non-network options. These limitations
are those that Endeavour Energy will conduct further investigation within the next three years. Demand
management options that are considered may include, but are not limited to, combinations of the
following:


Reduction in electrical energy consumption through:

Improved energy efficiency devices and systems

Thermal insulation

Renewable energy sources

Alternative reticulated energy sources
Reduction in peak electricity consumption through:

Tariff incentives

Load interruption/reduction incentives

Arrangements to transfer load from peak to off-peak times

Energy storage systems

Standby generators

Power factor correction equipment
The network constrained areas where a non-network option will be investigated within the next three
years (2013/14 to 2015/16) and beyond are listed below. These projects have been identified as
network constrained areas in Table 174 and Table 175 in Section 4.0. The constraint year reflects the
year when it is forecast that the capacity limitation will be reached.
Network Connection Point
Load Type
Investigations within the next three years
North Box Hill ZS Establishment
95% residential, 5% commercial – greenfield
development
Leppington South ZS
Establishment
development
Catherine Fields ZS
Establishment
development
Feeder 808-Springwood ZS
10% Commercial, 90% Residential
Feeder 311/306-Cawdor ZS
15% Commercial, 85% Residential / Rural
Penrith 11kV ZS
60% Commercial, 25% Industrial, 15%
Residential
Leppington North ZS
Establishment
development
Austral ZS Establishment
development
Southpipe (Oakdale Estate) ZS
132/11kV Establishment
development
Investigations beyond the next three years
Feeder 7043 & 7514 Berry ZS
10% Commercial, 90% Residential / Rural
Riverstone ZS
Residential
Sherwood ZS
Glenmore Park ZS
Schofield ZS
Feeders 490 & 491 – St Marys
ZS
Residential
Timing of
Consultation
Process
Constraint
Year
Decision
Deadline
TBA
Oct 2014
Apr 2015
TBA
Oct 2015
Apr 2016
TBA
Oct 2015
Apr 2016
TBA
TBA
TBA
Oct 2015
Oct 2015
Oct 2015
Apr 2016
Apr 2016
Apr 2016
TBA
Oct 2016
Apr 2017
TBA
Oct 2016
Apr 2017
TBA
Oct 2016
Apr 2017
TBA
TBA
Oct 2022
Oct 2024
Apr 2019
Apr 2021
TBA
TBA
TBA
TBA
Oct 2024
Oct 2024
Oct 2024
Nov 2023
Apr 2021
Apr 2021
Apr 2021
Oct 2019
Table 191: Future non-network programs investigation
Endeavour Energy currently has no plans for the installation of generation facilities. However, the nonnetwork option consultation process will provide an opportunity for embedded generation options to be
considered for each constrained location.
10.0
INVESTMENTS IN METERING AND INFORMATION TECHNOLOGY
10.1
INFORMATION TECHNOLOGY
Table 192 provides information on the proposed investment for information technology systems for the
preceding year and forward planning period.
Project Name
Period
Enterprise Application
Integration - JBoss
(EAI)
2013/14
and
2014/15
Employee Portal
Improvement
2013/14
and
2014/15
Field Computing
Program
2013/14
and
2014/15
NOSW Automation
Datacentre Refresh
Program (Infrastructure and
databases)
Billing & Metering
rationalisation
program
IP Telephony
Replacement and
Enhancement
2013/14
and
2014/15
2013/14
and
2014/15
2013/14
and
2014/15
2013/14
and
2014/15
WAN Equipment
Refresh
2013/14
and
2014/15
Call Centre
2014/15
Datacentre Refresh
Program (Virtualisation
Roadmap, Storage
and Backup, DC
Environment
Assessment)
2014/15
Description
Integration of key systems has delivered enhanced asset management capability for
Endeavour. Current tools are at end of life and this project will replace SeeBeyond and
JCaps interfaces with new, technically current and supported application integration platform
to ensure continuity of business operations.
The investment in this project is to provide a self-managed online employee portal for
employees and managers to complete employee based administration tasks such as
timesheets, training management, leave, personal details and higher duties. The project’s
purpose is to improve productivity by moving from a largely manual and paper based
system, to an online self-service that can be used at any time with any device.
This program consists of a number of projects that deliver field computing for a number of
inspections and asset maintenance processes including line inspection and repairs, MDI
reads, substation inspections, and other related distribution maintenance activities. The
program’s purpose is to improve data quality and increase productivity by reducing the need
for manual data entry from paper forms completed in the field.
This project aims to automate the current manual data entry processes associated with
Notification of Service Works and Certification of Compliance Electrical Work and to deliver
a field automation component for direct data-entry from job sites into the relevant backend
systems. This automation of processing is expected to deliver efficiency gains and
improved data quality.
Endeavour has aging environments and data infrastructure assets. Many are beyond the
standard life of three to five years. This represents a risk which is increasing the longer the
assets continue to age. The overall objective is to refresh Endeavour Energy’s data
infrastructure assets across both datacentres to reduce total costs of ownership with the
focus on reduced operational expenditure on maintenance and support while ensuring
system reliability required by business operations for critical applications and infrastructure.
This program of work will aim to eliminate the need for Banner (Endeavour’s legacy
customer billing application) by moving required functionality and data to alternative existing
systems until only NUOS Billing remains and then seek a replacement for NUOS billing
process. This program aims to maintain technical currency of metering systems by migrating
metering management functions to Ausgrid’s MBS system and decommission legacy
systems. Business process will be redesigned as part of this program to reduce costs and
risk of manual tasks and improve data quality.
Endeavour Energy’s telecommunication infrastructure is critical for the business to meet the
demands of its employees and customers through more agile and cost-effective access to
technology and information. This program of work enables the replacement/renewal of
currently installed equipment which is at the end of its economic life with a single supported
IP network to provide future integration capabilities and improve reliability of voice and data
services across Endeavour Energy. In the previous year, the ICT group purchased the new
generation and industry standard of telephony hardware. The project is now underway to
implement the hardware and deliver a more productive workforce that can leverage the
capability of unified communications and collaboration by connecting every person in the
corporate directory with the right information, in the right format, at the right time.
This project is to refresh and replace the routers for the wide area network which are critical
to the delivery of computing services to mobile devices, depots and office locations within
Endeavour Energy’s business. Continuing from the last year, the aim of this project is to
refresh and replace the routers for the wide area network that are critical to the delivery of
computing services to depots and office locations within Endeavour Energy’s business
franchise area.
This is investment in the Customer Interaction Centre infrastructure upgrade project. This
includes the replacement of Nortel PABX equipment and peripherals in both Huntingwood
and Coniston locations. The project reduces the risk to the business platform and reduces
the OPEX maintenance cost.
Endeavour will build on last year’s enterprise architecture technology roadmap and continue
to upgrade its data centres. In this AER period the planned program will address the aging
virtual environments and data backup solution assets. The virtualisation of environments
delivers flexibility and lowers risk to positively impact critical systems performance and
contribute to the lower overall cost of applications and systems lifecycle. The cost of storage
on the market is decreasing and Endeavour will take advantage of the opportunity to
consolidate the backup and storage solutions in the data centres and replace the ageing
disc arrays with new solution with lower cost per unit of storage while still delivering the
reliability required to support critical business applications.
Table 192: Information technology program
10.2
METERING
Endeavour Energy current meter population consists of a mix of accumulation, interval data and smart
type meters.
Metering assets are required to meet complex statutory and regulatory requirements including meter
performance obligations as defined by AEMO to ensure accuracy of energy consumption recorded.
Sample test are conducted and meter types that fail to meet the required targets are replaced.
Each technology change in meter type achieves greater benefits from additional functionality. However,
an increase in support costs is required to achieve that functionality and the additional capital and
operational expenditure required to deploy and support an interval or smart meter population must be
offset against benefits to the network business. However, the limited deployment of interval and smart
meter technologies has enabled broader usage of the available information to manage peak demand.
This is particularly evident through Demand Management programs targeting constrained elements of
the network.
The significant changes that have occurred in the metering industry within Australia and the forecast
changes to the NEM Rules means that the metering and tariff strategies need to be frequently monitored
and reviewed. In October 2014, the Minister for Resources and Energy announced that electricity smart
meters in NSW will be installed through a market-led rollout. In the short term Endeavour Energy will
continue its current strategy of utilising the default meter for the situation i.e. accumulation type meters
for small customers and interval meters for medium sized customers. Meter replacement will continue as
per compliance sample testing.
Based on projections of meter test fail rates and assuming the meters will then be replaced over five
subsequent years after failure, a future meter replacement program can be estimated. The metering
forecast change program is shown in Table 193 below.
Meter Type
Single Phase
Three Phase
2014/15
7,200
2015/16
21,626
7,200
2016/17
23,500
7,200
2017/18
25,803
-
2018/19
38,663
-
Table 193: Forecast meter change program
Endeavour Energy’s is currently investing in metering programs outlined in Table 194.
Program Name
Meters - Growth
Relays - Growth
Meters - Renewal
Relays - Renewal
Test Equipment
Demand
Management
Technology
Description
This program is for the metering expenditure required for new installations/additional solar metering
requirements etc.
The Relays – Growth program is for the supply of load control equipment for new installations in
conjunction with new meters.
The meters are maintained and tested in accordance with Australian Standard 1284.13:2002. When a
metering group fails this test, it is a requirement to replace that group as the group is considered as having
reached its end of life. This SAMP program is for the replacement of meters that have reached the end of
their life.
The Relays – Renewal program is for the supply of load control equipment in conjunction with
replacement meters at the end of life.
This program is for the expenditure requirements of metering test equipment and / or calibration of this
equipment.
Provision of equipment to support Endeavour Energy’s demand management initiatives (including DMIA
trials, targeted constraint driven projects and broad based initiatives). Primarily smart meters,
accumulation meters, load control relays and some trial customer technology products (battery storage,
power factor correction inverters and air conditioner control devices).
Table 194: Metering Programs
11.0
REGIONAL DEVELOPMENT PLANS
Maps showing sub-transmission lines, zone substations and transmission-distribution connection points
to assist identifying the location of limitations discussed previously.
11.1
ENDEAVOUR ENERGY REGIONAL NETWORK MAPS
12.0
GLOSSARY
Abbreviations and Definitions
Abbreviation/Phrase
AEMC
AER
DAPR
DNSP
GJ gigajoule
GWh gigawatt hour
HV high voltage
HVC
kV kilovolt
kW kilowatt
kWh kilowatt hour
LV low voltage
MW megawatt
MWh megawatt hour
NER
Primary distribution
feeder
Sub-transmission
Sub-transmission
system
V volt
W watt
Definition
The Australian Energy Market Commission is the rule maker and developer for Australian energy
markets
Australian Energy Regulator
Distribution Annual Planning Report prepared by a Distribution Network Service Provider under
clause 5.13.2
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
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
One GWh = 1000 megawatt hours or one million kilowatt hours
Consists of 11 kV and 22 kV distribution assets (referred to as medium voltage in 7.2)
High voltage customer
One kV = 1000 volts
One kW = 1000 watts
The standard unit of energy which represents the consumption of electrical energy at the rate of one
kilowatt for one hour
Consists of 400V and 230 volt distribution assets
One MW = 1000 kW or one million watts
One MWh = 1000 kilowatt hours
National Electricity Rules
Distribution line connecting a sub-transmission asset to either other distribution lines that are not subtransmission lines, or to distribution assets that are not sub-transmission assets
Any part of the power system which operates to deliver electricity from the transmission system to the
distribution network and which may form part of the distribution network, including zone substations
Consists of 132kV, 66 kV and 33 kV assets
A volt is the unit of potential or electrical pressure
A measurement of the power present when a current of one ampere flows under a potential of one
volt

Distribution Annual Planning Report

Transcription

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