Annual Planning Report 2015/16 © 2016 Electricity Networks Corporation, trading as Western Power ABN 18 540 492 861 Contact details: T 13 10 87 TTY 1800 13 13 51 TIS 13 14 50 F (08) 9225 2660 E [email protected] W westernpower.com.au CONTENTS
1 INTRODUCTION 2 6.4 North Country load area 40 1.1 Western Power’s role 2 6.5 Eastern Goldfields load area 44 1.2 About the Annual Planning Report 2 6.6 East Country load area 46 1.3 Interaction with the Electricity Statement of 6.7 Muja load area 48 Opportunities 2 6.8 Bunbury load area 51 1.4 Structure of the 2015/16 APR 2 6.9 Mandurah load area 54 1.5 Invitation to provide feedback 2 6.10 Kwinana load area 56 2 PLANNING CONSIDERATIONS 4 6.11 Southern terminal load area 58 2.1 Electricity regulation in Western Australia 4 6.12 South Fremantle load area 60 2.2 Western Power’s funding process 6 6.13 Cannington load area 62 2.3 Western Power’s planning processes 7 6.14 East Perth and CBD load area 64 2.4 Customer contributions and 6.15 Western Terminal load area 66 connection issues 9 6.16 Guildford load area 68 2.5 Safety, health and environment 10 6.17 Neerabup Terminal load area 70 2.6 Stakeholder and community engagement 12 6.18 Northern Terminal load area 72 2.7 Current state of the network 13 6.19 Summary of opportunities 74 2.8 Future network strategy 13 6.20 Non-competing application thresholds 76 6.21 Competing Applications Groups 76 3 DEMAND FORECASTS 16 3.1 Forecasting in a changing environment 16 7 SUPPLY ISSUES 78 3.2 Demand changes in 2014/15 16 7.1 Metro planning region 78 3.3 Annual peak demand forecasts 18 7.2 Country distribution planning 104 3.4 Forecasting method 18 7.3 Under fault rated conductor 118 3.5 Annual peak demand forecast: 7.4 Constrained distribution transformers 120 2015/16 - 2024/25 20 APPENDIX A 3.6 Peak demand forecast validation 26 Glossary 122 4 GENERATION SCENARIO PLANNING 28 APPENDIX B 4.1 Generation connection arrangement 28 Cross-reference of 4.2 Use of scenarios in transmission planning 28 Western Power planning regions 124 4.3 Generation scenario development 31 APPENDIX C 5 COMPLETED PROJECTS 32 Estimated maximum short circuit levels 128
6 TRANSMISSION SYSTEM ISSUES 36 APPENDIX D Connection application process maps 138 6.1 Bulk transmission capacity and constraint 36 6.2 Local generation and demand APPENDIX E management opportunities 38 Peak forecast data 141 6.3 Committed works 38
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 1 1. INTRODUCTION
1.1 WESTERN POWER’S ROLE This report also articulates the guiding they jointly provide a valuable insight Western Power is a Western Australian principles of the processes through into current and future opportunities State Government-owned corporation which existing and potential network for new and existing generators, that connects more than one million users (including generators, major developers and consumers. customers with electricity in a way that loads, local councils and other is safe, reliable and affordable. organisations with planning and 1.4 STRUCTURE OF THE development interests) can engage 2015/16 APR We build, maintain and operate the Western Power on the development of The structure of the 2015/16 APR is electricity network in southern Western network access agreements. consistent with the previous year’s Australia, across an area bounded by release. Consultation with key internal Kalbarri, Albany and Kalgoorlie. The This report is a peak document that is and external stakeholders has Western Power Network forms the vast supported by a number of subordinate influenced the development of this majority of the South West internal documents containing detailed year’s release with the aim of Interconnected Network (SWIN), which planning information on issues such as improving the usefulness of the together with all of the electricity network capability, power reliability and document for interested parties. generators and consumers, comprises asset performance in discrete areas of the network. Among these are Network the South West Interconnected System 1.5 INVITATION TO PROVIDE (SWIS). Development Plans (NDPs), which articulate the medium- to long-term FEEDBACK Western Power is governed by an planning advice (2 to 50 year horizon) to Western Power welcomes feedback on independent Board and reports to the ensure the efficient development of this APR. Please direct comments on Western Australian Minister for Energy individual load areas. The NDPs provide this document to: as the owner’s representative. more detailed and specific information Head of Network Planning on potential network developments. 1.2 ABOUT THE ANNUAL and Standards PLANNING REPORT Due to the dynamic nature of Western Power customers’ requirements, the GPO Box L921 Western Power publishes the Annual information and plans do change from Perth WA 6842 Planning Report (APR) to provide year to year. We recognise the information to electricity market Telephone: (08) 9326 6789 importance of keeping the plans up to participants and interested members Facsimile: (08) 9218 5167 date. Existing and potential customers of the broader Western Australian are encouraged to contact Western Comments may also be submitted by community on the nature and location Power to receive specific advice as email to [email protected] of the emerging capacity constraints early as possible. and through Western Power’s website. on the Western Power Network. This APR is based on the most current The APR provides an open and 1.3 INTERACTION WITH THE information available at the time of transparent view into the factors ELECTRICITY STATEMENT OF writing with respect to generation and considered by Western Power in OPPORTUNITIES load development expectations. addressing network issues responsibly The APR complements the Western Power welcomes contact and efficiently, to produce timely Independent Market Operator’s (IMO) from parties considering investments network and non-network solutions to 2014 Electricity Statement of that, based on the information manage both emerging constraints 1 Opportunities, released in June 2015. provided here, would appear to either: and developing customer needs. The While the Statement of Opportunities APR aims to provide a strategic view of focuses on the overall adequacy of • delay requirements for network network development, illustrating the generation capacity, the APR’s focus is development options, or foundations for the planning and the identification of emerging capacity • accelerate requirements for network development of the Western Power issues and potential solutions for development options. Network into the future from a whole-of- Western Power’s transmission and network perspective. Additionally, there distribution networks. Relevant information will be is a focus on presenting emerging incorporated in Western Power’s capacity constraints for the benefit of Although these artefacts are prepared planning process and reflected in existing and potential network users. separately and from distinct forecasts, future editions of the APR.
1 http://wa.aemo.com.au/docs/default-source/Reserve-Capacity/2014-electricity-statement-of-opportunities76EBFFC3E047.pdf?sfvrsn=0
2 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 3 2. PLANNING CONSIDERATIONS
This section presents a high-level • Wholesale Electricity Market Rules 2.1.1 ENERGY MARKET REVIEW overview of the legislative and 2004 On 6 March 2014, the Minister for regulatory requirements that • Electricity Industry (Code of Energy launched the Electricity Market 3 inform Western Power’s planning Conduct) Regulations 2005 Review (EMR). This examines the processes, together with a structures of the electricity generation, description of these processes. • Environmental Protection Act 1986 wholesale and retail sectors within the • Planning and Development Act SWIS and the incentives for industry 2.1 ELECTRICITY REGULATION 2005. participants to make efficient IN WESTERN AUSTRALIA investments and minimise costs. In developing its investment plans, one Western Power is subject to a number of the most important pieces of The first phase of the Review identified of regulatory regimes that are legislation Western Power must the urgent need for industry and administered by the following consider is the Access Code, which is market reform in the electricity sector regulatory bodies: administered by the ERA. The ERA is to address high and increasing costs • Economic Regulation Authority (WA) an independent economic regulator, of electricity services. whose role is to help ensure Western • EnergySafety (WA) Phase 2 (announced by the Minister on Power provides a quality service at a 24 March 2015) focuses on the • Environmental Protection Agency reasonable price. The primary detailed design of reforms through four (Commonwealth) regulatory instrument is the Access primary work streams: Arrangement, which the ERA reviews • Department of Environment every five years (see Section 2.1.2). 1. Network Regulation Regulation (WA) During its ex-post Access Arrangement 2. Market Competition • Department of the Environment review, the ERA scrutinises the capital (Commonwealth) 3. Institutional Arrangements investment Western Power undertook • Department of Planning (WA) in the previous Access Arrangement 4. Wholesale Electricity Market (WEM) period to test whether it was efficient Improvements. • Independent Market Operator (WA)2 and eligible to be added to Western Decisions on the implementation of • Public Utlilities Office (WA) Power’s Regulated Asset Base (see specific reforms are expected Section 2.1.5). • Worksafe (WA). progressively throughout 2015/16 and The ERA also examines Western 2016/17. These bodies are responsible for Power’s forward plans to test whether ensuring that Western Power’s 2.1.2 ACCESS ARRANGEMENT they satisfy the Access Code objective activities are consistent with regulatory of: The Access Code requires Western requirements, with some having the Power to have an Access Arrangement authority to impose financial penalties “… promoting the economically approved by the ERA. The Access and legal action against Western efficient investment in, operation and Arrangement determines the regulated Power should it be found in breach of use of, networks and services of revenue Western Power may receive its obligations. networks in Western Australia in order (e.g. from network tariffs) for to promote competition in markets The main regulations and codes connecting customers with electricity, upstream and downstream of the governing Western Power’s activities together with the level of service networks.” include: customers can expect during its 4 It is essential that Western Power’s five-year duration. Access • Electricity Networks Access Code ongoing operations and investment arrangement provisions must be 2004 (“the Access Code”) activities consider this objective, the approved by the ERA, together with • Electricity Corporations Act 2005 conditions of its Access Arrangement any subsequent amendments. and the investment tests applied by • Code of Conduct for the Supply of the ERA to Western Power’s activities. Electricity to Small Use Customers 2014
2 The roles of independent energy market operator and independent power system operator in Western Australia were transferred to the Australian Energy Market Operator (AEMO) as part of the State Government’s Energy Market Review, (effective 30 November 2015). 3 https://www.finance.wa.gov.au/cms/Public_Utilities_Office/Electricity_Market_Review/Electricity_Market_Review.aspx 4 The two previous Access Arrangements were both three years in duration.
4 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 5 2. PLANNING CONSIDERATIONS
The Access Arrangement covers: • transmission: $35.5 million • earn additional revenue from that investment • regulated revenue Western Power • distribution: $11.8 million may earn • pay back past borrowings • combined transmission and • charges and conditions for distribution: $35.5 million. • operate as a sustainable commercial accessing the network, including a entity. The Regulatory Test requires Western standard access contract Power to demonstrate the following in To minimise the risk of inefficient • policies on customer contributions, relation to solutions it proposes to expenditure, Western Power assesses applications and queuing that address network issues: NFIT as part of all investment describe how charges are calculated justifications and seeks pre-approval of • all viable options have been for customers wishing to connect to the NFIT on selected capital projects considered, including non-network the network and the process and programs. options (e.g. contracted demand Western Power follows for management and generation To assist the ERA in its ex-post review, processing connection applications support) it is important that all investment • performance and reliability decisions and the considerations • the proposed approach maximises standards made when applying the NFIT are the net benefit to those who documented and can be provided to • performance incentives. generate, transport and consume the ERA on request. electricity. The term of the current Access Arrangement period (AA3) is 1 July Examples of benefits include improving 2.2 WESTERN POWER’S 2012 to 30 June 2017, but may be supply reliability, improving or FUNDING PROCESS extended to 30 June 2018 as a maintaining safety standards, reducing As Western Power’s forecast retained transitional outcome of the EMR. The electricity generation costs and cash flows are not sufficient to meet next Access Arrangement will be increasing the productivity of electricity capital expenditure requirements, debt under the jurisdiction of the Australian consumers through reduced electricity funding is required. These funds are Energy Regulator. prices. sourced from the Western Australian Treasury Corporation and therefore 2.1.3 TECHNICAL RULES The Access Code also obliges Western Power to conduct public have a direct impact on State net debt. The Technical Rules prescribe the consultation processes for major technical requirements for the design Western Power’s State Budget position augmentation projects. and operation of the network and determines the approved borrowing limits over the forward estimates connection to it, with which Western 2.1.5 NEW FACILITIES period. This is co-ordinated by the Power, generators and consumers INVESTMENT TEST must comply. These rules form part of Department of Treasury and is The New Facilities Investment Test the Access Code and provide the reviewed twice yearly as part of the (NFIT) is the formal methodology6 for technical basis for investment State Budget and Mid-Year Review assessing the efficiency of expenditure decisions and capital expenditure processes. The Minister for Energy is and whether Western Power can earn forecasts; they are not a formal required to endorse any adjustments a return on that investment. This is the element of Western Power’s Access to the State Budget position submitted test that the ERA applies in its ex-post Arrangement. by Western Power. review of capital expenditure. The approval of any adjustments to the 2.1.4 REGULATORY TEST Satisfying NFIT is essential for Western State Budget position over the forward Section 9 of the Access Code requires Power to recover a full commercial estimates period enables Western Western Power to conduct a return on investments. The ERA may Power to update the allocation of funds. Regulatory Test for major exclude from Western Power’s augmentation projects whose regulated asset base the cost of any estimated costs exceed the following investment not satisfying this test, thresholds:5 limiting Western Power’s ability to:
5 As at 26 June 2015. These thresholds are indexed annually by the ERA. 6 Defined in Section 6.52 of the Access Code.
6 Western Power may also submit historical trends and take into These inputs are considered within the funding requests for additional capital account projections of State network analysis to ensure that each expenditure through business cases, economic growth and customer and network element satisfies a number of as recommended to Western Power by generator connection enquiries technical criteria: the Economic and Expenditure Reform (discussed in detail in Section 3). • Ability to operate within design limits. Committee in November 2012. Western Power’s forecasts also This requires voltage and power make prudent assumptions about transfer for each asset to be 2.3 WESTERN POWER’S the development of generation assessed under a wide range of PLANNING PROCESSES projects (see Section 4) and potential conditions, including the consumer usage trends. 2.3.1 NETWORK DEVELOPMENT modelling of the effect of faults on PLANNING • Asset management plans. These the network. The failure to meet Western Power’s network development ensure that network assets can design specifications can result in planning applies prudent risk continue to provide a safe and malfunction or damage to customer management principles with the aim of reliable service. Condition equipment, while exceeding power optimising the balance between safety assessments drive asset replacement transfer limits creates potential considerations, costs, and the impact and maintenance activities. safety hazards and reliability issues arising from the overload and failure on customers of unreliable or • Western Power’s commercial of network equipment. insufficient supply. objectives, reflecting its legislated Network Development Plans (NDPs) obligation to act in a manner likely to • Ability to tolerate credible faults and are fundamental to this process, maximise the long-term profitability unplanned outage scenarios. A fault ensuring optimal investment decisions of the business. is considered credible if it has a reasonable probability of occurring and efficient project delivery to achieve • The State of the Infrastructure given the prevailing circumstances. the required outcomes. NDPs depend Report. This is an annual snapshot on a range of inputs, including: of the performance of the network. It • Ability to continue operating within • The Technical Rules (see Section is used by planners and asset design limits and at the required 2.1.3). managers to ensure that Network performance level in the event of a Management Plans (NMPs) and credible fault or unplanned outage.7 • Load and generation forecasts. NDPs address identified These are developed from observed performance risks.
7 The radial nature of the distribution network means that the loss of a network element will generally result in the loss of supply to a number of customers. Western Power attempts to minimise the impact of these events by installing reclosers, sectionalisers, fault indicators, load break switches and remote control pole-top switches.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 7 2. PLANNING CONSIDERATIONS
Key network planning considerations • articulate the network issue(s) and considered in the context of the include: driver(s) being addressed network’s envisaged future state.
• maintaining quality of supply8 to the • include a risk assessment of the To successfully plan for the long-term, appropriate standard network issue(s) against set it is necessary to monitor trends and deterministic criteria, including the changes in the external environment • catering adequately for future growth likelihood and consequences of and their potential impacts on Western to facilitate economic development, each risk to determine individual and Power and its customers. where it is economically prudent to overall risk ratings do so This involves active participation in • propose any mitigation measures various working groups, close • the responsible management of that may be required prior to engagement with stakeholders and environmental impacts through implementation of the final solution interaction with other electricity sector formal approval processes and participants, such as manufacturers adherence to internal and external • comprehensively evaluate available and national and international environmental management technical options organisations. requirements • conduct economic and financial Maintaining awareness of energy policy • stakeholder expectations. analysis on the options issues is achieved by contributing to The NDP (2 to 50 year outlook) aims to • recommend a solution based on an reviews of energy policy, the regulatory achieve sufficient capacity for optimal investment strategy that framework, the Wholesale Electricity transmitting power from generators to minimises net present cost Market (WEM), the Technical Rules and consumers as cost-effectively as the Access Code. • apply risk-based planning possible. This may involve alternative techniques to further quantify net By considering a range of scenarios, non-network solutions, such as benefits of transmission network Western Power explores the potential demand management (DM) or local augmentation and to define the impact of uncertain future demand and generation. optimal trigger year for investment9 generation requirements on the From the NDP, detailed plans are network. The scenarios cover a range • conceptually describe the project developed for the transmission of potential directions and explore the that delivers the solution and distribution networks. Detailed impact of government policy initiatives. system studies are undertaken for a • identify the benefits to be realised by These include emission reduction variety of load and generation the end of the project. policies, renewable generation policies scenarios, in conjunction with and targets and the development of The WPR forms the basis of a investigations to capture network smart grids and technology changes. business case and regulatory issues and associated drivers. submissions (where required) Effective long-term strategic planning For the transmission network (66 kV recommending a solution and seeking identifies and creates options for and above), a typical timeframe of up approval to proceed with it. short- to medium-term planning and to ten years is considered. Distribution projects, as well as maintaining their planning (below 66 kV) is limited to a 2.3.2 LONG-TERM STRATEGIC viability and minimising the risk of their five-year horizon due to lower visibility PLANNING becoming time-critical. This strategic of block loads beyond that interval and The long-term strategic planning positioning can occur in a variety of the inherently dynamic characteristics process guides short- and medium- ways, including: of planning needs. term planning activities by articulating • strategic land purchases for future strategic long-term views of the These activities lead to the preparation zone substations and terminal network’s evolution. With this view, of detailed Works Planning Reports stations options for addressing short- to (WPRs), which: medium-term issues can be
8 Quality of supply encompasses voltage, frequency and other power supply parameters. 9 The planning criteria in the Technical Rules (current version published 23 December 2011) is inherently deterministic and does not explicitly consider the application of risk-based (or “probabilistic”) planning techniques. However, if a decision on a risk-based planning investment conflicts with compliance obligations prescribed in the Technical Rules, Western Power will engage with the ERA to assess the risks associated with the cost of compliance (compared to non-compliance) to determine if an exemption is applicable. This approach is undertaken on a case-by-case basis to reconcile the outcomes of the two planning approaches.
8 • securing access corridors via the reduce their impact on the network 2.4 CUSTOMER CONTRIBUTIONS strategic statutory planning process during times of peak load. AND CONNECTION ISSUES (undertaken by the Department of NCS is treated as operating 2.4.1 CUSTOMER Planning) expenditure, in contrast with the CONTRIBUTIONS • adopting appropriate emerging capital expenditure treatment of Customers seeking to connect to technologies. network solutions (e.g. the Western Power’s network may be construction of a new transmission Long-term planning also requires required to make a financial line). The implementation of NCS leads regular environmental scans of the contribution (in addition to the payment to additional operating expenditure for technological landscape to ensure that of network tariffs) towards the cost of Western Power that results in the appropriate standards are in place for any network augmentation required to deferral of the capital expenditure the shorter term planning horizon. facilitate the connection. Contributions associated with the alternate network are required to the extent that 2.3.3 NETWORK CONTROL solution (i.e. where the annualised cost precludes cross subsidies from other SERVICES of the network solution is more than customers. the annual cost of NCS). Through the Regulatory Test and NFIT Customer contributions may be in the provisions, the Access Code requires If NCS does not appear to be viable, or form of up-front capital contributions, Western Power to demonstrate that it if its procurement tender process does periodic payments for non-network has efficiently minimised costs when not yield a satisfactory outcome, solutions (such as NCS), or a implementing a solution to remove a Western Power may proceed to combination of both. network constraint. In all cases, this implement the alternative network requires a comprehensive and robust solution. Customer contributions are assessment of all viable options, determined in accordance with the Where NCS is implemented to meet including Network Control Services10 published Contributions Policy,11 as general load growth, the costs will be (NCS) and other non-network approved by the ERA in Western recovered from all customers via solutions, where available and Power’s AA3 submission. In essence, network tariffs. In the event of a appropriate. Both the Access Code the required contribution can generally specific customer driving the need for and Wholesale Electricity Market Rules be calculated as follows: NCS, the costs will be recovered regard NCS as an option requiring directly from that customer to avoid Contribution = assessment. cross-subsidies from other customers. 1. forecast costs of augmentation (if NCS assists in managing network Western Power’s Contributions Policy any) of shared network assets flows to ensure secure and reliable has a facility to recover operating operation and can be provided through minus expenses. For NCS, this can be in the generation and demand management. form of both a fixed rate plus a rate 2. the value of this work that In generation, it may take the form of a per kWh to echo the payments made meets NFIT power station connected to the to the service provider for both plus transmission or distribution network (or capacity and energy. It is envisaged directly to a zone substation) that is that NCS providers would secure 3. full cost of new assets used only in operated for a short duration during capacity payments from the IMO via its the connection of the customer. peak load periods. Reserve Capacity Mechanism, so that A fact sheet discussing this in greater any capacity payment made by In demand management detail is available from the Western Western Power to a NCS provider 12 implementations, specific customers Power website. covers only additional capacity costs may agree to curtail load, run on-site incurred (if any). standby generation or disconnect from the network for short periods to
10 Section 6.19 details identified network limitations and NCS opportunities. 11 http://www.erawa.com.au/cproot/8270/2/20100119%20AA2%20Appendix%203%20-%20Contributions_Policy.pdf 12 http://www.westernpower.com.au/documents/business_cont_paym.pdf
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 9 2. PLANNING CONSIDERATIONS
2.4.2 APPLICATIONS AND The extent of reinforcement and the Public impact QUEUING POLICY characteristics of the connected Western Power designs and operates Western Power complies with the equipment can impact future its network to relevant Australian safety requirements of the Applications and connections, underscoring the standards and manages third-party Queuing Policy (AQP) in making offers importance of evaluating the work and development near its to connect customers to the Western connection’s performance and network to ensure that safety risks to Power Network. The AQP was network impact before processing the the community are managed. reviewed and approved by the ERA as next application in the queue. This can Western Power is improving its part of its review of Western Power’s extend the time needed to process mitigation of public impacts by Access Arrangement. applications. establishing new requirements and Details of the connection process and In addition to understanding the AQP, assurance activities within the Safety, requirements for large generators are potential generators and loads should Health and Environment Management available from Western Power’s be aware of their obligations under the System and updating its internal website.13 Appendix D presents Technical Rules governing connection Network Standards for the design of process maps for each type of to the Western Power Network. These the network. It is also improving its connection process for transmission obligations are outlined in the management of third-party 14 loads and large generators. Generator Grid Connection Guide. applications and referrals regarding works and proposed developments in The AQP was revised as part of the 2.5 SAFETY, HEALTH AND proximity to planned and/or existing AA3 review. One of the key changes of ENVIRONMENT operational network infrastructure. This this revision was to organise incorporates engagement with the competing connection applications 2.5.1 OBJECTIVES planning and development industry, into one or more Competing In planning, constructing and operating through forums and integration with Applications Groups (CAGs). This its network, Western Power considers the Western Australian town planning approach allows Western Power to safety, health and environmental (SHE) system (administered under the develop the most economically legislative requirements to manage Planning and Development Act 2005.) efficient network expansion for risks to its workforce, the community This engagement seeks to achieve connecting multiple customers, rather and the environment. safe design, controls and work than developing individual solutions. Western Power complies with relevant practises prior to the execution of any Connection offers are made once the SHE legislation by establishing third-party works near the network. expansion requirements and network requirements and assurance activities expansion costs have been determined. in its Safety, Health and Environment Workforce safety The revised AQP continues to allow Management System. By designing its network to relevant applicants to proceed on an individual Australian Standards, Western Power basis, if preferred. (See Section 6.19 2.5.1.1 Public impact and manages its duty of care to provide a for further information on the workforce safety work environment in which employees connection applications currently Western Power seeks to satisfy the and contracting partners are not, as far being processed within each requirements of the Occupational as is reasonably practicable, exposed Competing Applications Group.) Safety and Health Act 1984 and to danger. The communication of Regulations 1996 to comply with the health and safety requirements through For each application, technical studies relevant occupational health and safety the Safety, Health and Environment determine: Codes of Practice and Australian Management System and Work 1. the network impact of the Standards (administered by Worksafe Practices Manuals enables Western connection of the generator or load WA and EnergySafety). Power’s operational workforce and and contracting partners to take reasonable steps to care for their own 2. the level of reinforcement, if required. safety and health while operating and maintaining the network.
13 http://www.westernpower.com.au/electricity-retailers-generators-generator-and-transmission-connections.html 14 http://www.westernpower.com.au/documents/reportspublications/generator_grid_connection_guide.pdf
10 2.5.1.2 Environmental • quantifying the potential 2.5.1.4 Statutory approvals management environmental impacts of a Statutory approvals under relevant Environmental impact assessment in proposed project or activity legislation may be required prior to any Western Australia is regulated by • demonstrating that the risk of construction or maintenance network environmental legislation, including environmental impact has been activity works located: (but not limited to): reduced as far as is reasonably • on zoned land within a regional • Western Australian Environmental practicable planning scheme (development Protection Act 1986 (EP Act) • developing avoidance, management, approval required under the Planning and Development Act 2005) • Commonwealth Environment mitigation and offset strategies for Protection and Biodiversity the project. • within access roads controlled by Conservation Act 1999 (EPBC Act) Main Roads WA under the Main 2.5.1.3 Land access Roads Act 1930 • Wildlife Conservation Act 1950 Western Power endeavours to notify all • within a rail reserve typically • Biosecurity and Agriculture landowners and operators of property managed by the Public Transport Management Act 2007 containing its network infrastructure when access is required to construct Authority or Brookfield Rail under the • Contaminated Sites Act 2003 and/or maintain its infrastructure. All Rail Safety Act 2010 • Dangerous Goods Safety Act 2004 reasonable efforts are made to avoid • within the jurisdiction of the Swan damage to land and minimise River Trust. • Swan and Canning River disturbance to landowner activities Management Act 2006. while accessing land. This approach is Exemptions to the above may apply in certain circumstances. Western Power Before commencing any construction consistent with land access obligations may also be required to obtain approval and maintenance activities with under the Energy Operators (Powers) or consult with other utilities and asset environmental impact potential, Act 1979. owners (such as the Water Corporation Western Power must obtain all and Main Roads WA) if works occur in necessary approvals from relevant close proximity to their assets, or if the authorities and confirm compliance development itself will impact the with legislative obligations, by: future or operation of their asset.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 11 2. PLANNING CONSIDERATIONS
These statutory approvals are intended systems, processes and people that proven popular with a wide range of to address safety, land access, deliver them. user groups and surpassed usage and operational and/or community site visitor expectations. It is committed to early stakeholder requirements relevant to the engagement on major infrastructure The NCMT was developed by Western reservation areas. projects to inform decision-making and Power in collaboration with the 2.5.1.5 Heritage approvals infrastructure design processes. This Department of Planning and the also ensures that Western Power’s Western Australian Planning Western Power is conscious of its assessment of technical options Commission. The result of this obligations to preserve and protect considers the community’s current and collaborative effort was the first of its Western Australia’s heritage in anticipated needs. type in Australia, presenting conducting its network operations and infrastructure and planning information ensuring it meets the requirements of 2.6.2 OUTCOMES from multiple agencies through a the State’s heritage laws, including: Western Power’s community initiatives common geospatial view. • Aboriginal Heritage Act 1972 in 2015/16 include: It provides greater transparency of the • Native Title Act 1993 • Visits to State and Federal MPs to existing electricity network and understand the concerns of their network expansion plans and was • Heritage of Western Australia electorates. driven, in part, by stakeholder requests Act 1990. for more detailed network planning • Regular meetings with local Western Power minimises heritage information. government representatives across impacts by ensuring that the relevant the network to address their By displaying Western Power’s existing legislative requirements are satisfied concerns in a timely manner and network and proposed augmentations, and appropriate consultation is discuss Western Power’s strategic the NCMT highlights the interplay undertaken with relevant custodians. intent. between a range of factors, contributing to more informed 2.6 STAKEHOLDER AND • Identification of and participation in development plans. Users can create COMMUNITY ENGAGEMENT targeted public events to reach a the precise view for their needs by diverse range of community 2.6.1 APPROACH selecting “layers” corresponding to the members. Western Power takes a structured information of interest. • Regional forums to provide approach to its engagement with the Updated annually to maintain communities with information on local communities in which it operates, consistency with the current APR, the local works and an opportunity to its corporate values reflected in all of NCMT currently provides the following express their concerns directly to its community engagement activities. information about the Western Power Western Power. To align its performance with customer Network: • Education forums for community and community expectations, Western • forecast remaining capacity for each and industry on public safety around Power creates opportunities to both zone substation excluding upstream the network, vegetation improve its awareness of community supply constraints16 needs and foster a better stakeholder management, land access and understanding of its operating bushfire and storm preparedness. • locations of existing zone environment. substations, terminals and most 2.6.3 NETWORK CAPACITY power stations Western Power has adopted the core MAPPING TOOL • indicative location and likely year of values of the International Association The Network Capacity Mapping Tool commissioning for committed future for Public Participation to guide its (NCMT) presents detailed network zone substations and terminals community engagement activities. It planning information through a actively seeks community and geospatial map viewer. It is freely • reference details to the current APR stakeholder input on future project and accessible from the Western Power to obtain information about planning options, supported by the website.15 Introduced in 2011, it has approved network projects for each
15 http://www.westernpower.com.au/ldd/ncmtoverview.html (this page also contains a short introductory video on the NCMT). 16 This is shown as a coloured polygon representing the actual supply area of each zone substation, with data available for 20 forecast years.
12 existing and committed future 2.7 CURRENT STATE OF THE operability challenges, such as Western Power zone substation NETWORK planning network outages for operational activities (e.g. maintenance) • reference details to the current APR The Western Power Network supplied without interrupting supply to to obtain information about specific a record system peak demand of customers. supply issues for each zone 3,694 MW in the summer of 2011/12, substation’s supply area followed by three successive lower However, much of the existing ageing summer peaks (2012/13: 3,611 MW; asset base is either approaching its • high voltage overhead transmission 2013/14: 3,514 MW; 2014/15: design life or has already exceeded it. lines indicating operating voltage 3,605 MW).18 Western Power remains committed to • reference links to details associated Section 6 identifies a number of areas working collaboratively with with current Western Power of the Western Power Network that are Government, regulators and approved projects and scheduled currently constrained, in which all new stakeholders to apply a risk-based community engagement sessions loads and load increases exceeding investment program to ensure capital expenditure is targeted to manage • a snapshot of the overhead and nominated thresholds must agree to public safety and system reliability underground high voltage be curtailable or procure adequate optimally. distribution feeder reticulation, Network Control Services (NCS). including the number of phases These thresholds are subject to review to ensure they continue to provide 2.8 FUTURE NETWORK • potential connection points for appropriate curtailability triggers. STRATEGY generators to the Western Power Western Power has developed a To date, the development of the Network, shown for four capacity long-term view of the strategic Western Power Network has been bands. development of the network and the managed prudently to minimise the ongoing need to effectively manage Although some customer-specific requirement for the construction of assets to the full extent of their useful information is not displayed for new lines, terminals, substations and lives. Sections 6 and 7 discuss the confidentiality reasons, the NCMT circuits in order to reduce capital costs. presents ample detail for developers issues associated with the and investors at the early stages of One of the outcomes of this approach transmission and distribution networks decision-making. Updated periodically, is the high level of meshing between and describe potential strategies for the NCMT also provides the following the 330 kV and 132 kV networks, with optimising their utilisation. a heavy reliance on the 132 kV Department of Planning (DoP) The objective of network planning is to transmission lines to transfer power information: develop, over a reasonable period, a directly from generation, in parallel with highly efficient electricity network that • the Urban Land Development the 330 kV bulk system. In some presents the optimal balance between Outlook for the Perth metropolitan areas, this can result in: region and the Peel sub-region17 performance and cost. One of the key • overloading of the meshed 132 kV requirements to meeting this objective • local, district, sub-regional and network under contingency is improving load sharing among activity node Structure Plans conditions existing 330 kV and 132 kV assets to relieve congestion at 132 kV, • the three Parliament-approved • insufficient reactive support at particularly through the increased regional schemes (Metropolitan 132 kV levels under contingency utilisation of 330 kV infrastructure. Key Region Scheme, Peel Region conditions Scheme and Greater Bunbury considerations in planning the network Region Scheme). • increased 132 kV line losses and are listed below. high 132 kV fault levels. Power flow controllability There are also significant difficulties The current network is heavily meshed controlling 132 kV power flows to avoid with multiple parallel 330 kV and post-contingent overloading of some 132 kV paths. This creates limitations 132 kV circuits. This creates system in controlling power flow from an
17 This shows the location of intended future residential development and provides information on the type of development, expected dwelling yield and indicative timing. 18 The factors resulting in this reduction in peak load are discussed in Section 3.2.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 13 2. PLANNING CONSIDERATIONS
operational perspective, particularly New generation location Network support from local under peak demand conditions. Lead times associated with generators or demand Planning will consider options to transmission development can often management address this, such as opening key exceed those required for generation Load-constrained parts of the network points in the network. Proposed construction and commissioning. may benefit from network support that solutions will consider the need for Planning considers the likely can be provided by locating generation operational flexibility under post- connection and location of future capacity or demand management contingent conditions, including “black generation plant under a range of capacity in the “catchment area” start” requirements (the process of scenarios, to facilitate the timely (supply area) of the load constraint. returning a generator to operation connection of new entrants. Further when there is no network supply). information is provided in Section 4. Operational and market-related issues Ageing infrastructure Fault level considerations A clear understanding of other Some areas of the Western Power Numerous locations within the Western operational and market issues that Network contain assets that are more Power Network are now approaching relate to the development of the than 60 years old. For example, fault level limitations and in some network is important. Where Western Power’s planning considers cases, operational mitigations are applicable, solutions to these issues the need for staged replacement and already in place to avoid protection also feature in the Network upgrade of aged 66 kV assets to risks. These operational procedures Development Plan (NDP) cost/benefit 132 kV, to support load growth with can reduce network reliability or limit option analysis. minimal additional footprint. This also the maximum supportable demand by removes one transmission voltage level constraining generation, therefore Emerging technologies in the area, resulting in improved potentially affecting the least-cost Western Power acknowledges the backup supply options, fewer spares generation dispatch and unduly Western Australian electricity industry and increased flexibility for future influencing market operation. is facing a changing mix of generation, reinforcement, while avoiding the need storage and consumption. Western for 66 kV transformation costs. Connection of new large loads Power continues to keep abreast of Western Power seeks to plan and The transmission network should not changing technology, consumer make investment decisions that take impede State economic growth behaviour and environment, into account both short- and long-term through an inability to supply power to considering these in its network outcomes, based on evaluating the new large customer loads. Given the planning. whole of lifecycle cost of creating, lead times associated with These strategic considerations are owning, operating, maintaining and transmission development, Western used in developing the longer term disposing of assets. This principle Power regularly engages with plan as a means of guiding the applies to all drivers for investment, stakeholders regarding the potential selection of alternative projects to including asset replacement, commitment of new loads and their address a particular need. However, maintenance and growth. influence on planning of the simple alignment with these strategic transmission system. Western Power considerations is insufficient for balances the needs of existing and Western Power to commit to any new customers to prevent stranded particular project and does not replace investments due to the uncertainty of the detailed power system studies and new load connections. economic comparison of options that are performed within detailed business planning processes.
14 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 15 3. DEMAND FORECASTS
This section presents Western Load factor 3.2 DEMAND CHANGES IN Power’s latest forecast of annual The ratio of annual average demand to 2014/15 peak demand. The annual peak annual peak demand. This is a partial As shown in Tables 1 and 2, the 20 demand forecasts are an essential indicator of network utilisation. following changes in annual peak input for identifying emerging demand and annual average demand About the network hierarchy capacity issues on the Western were observed in 2014/15: Power Network and developing Western Power develops annual peak • The Western Power Network’s plans to address them.19 demand forecasts for the Western Power Network (i.e. that portion of the annual peak demand was 72 MW The following key terms are used in SWIS owned and operated by Western below the corresponding Central this discussion: Power). The Western Power forecasts 50% PoE forecast. Demand exclude: • Annual demand peaks on the The amount of electricity consumed at • transmission and distribution Western Power Network, distribution any given time. This is expressed in network losses network and SWIS exceeded units of power, usually megawatts 2013/14 levels. This was due (MW). • loads supplied from the SWIS but primarily to a single day of very high not connected to the Western Power temperatures21 across much of the Annual peak demand Network. south-western landmass on 5 The highest average electricity January 2015, with a maximum of consumption in any five minute interval 3.1 FORECASTING IN A 44.4°C recorded in Perth. The more during the course of one year, usually CHANGING ENVIRONMENT moderate temperatures throughout expressed in MW. The implementation of reforms arising the remainder of the summer had Annual average demand from the Energy Market Review will less influence on load demand Average electricity demand over the introduce new dynamics that are likely compared to the previous three course of one year, usually expressed to challenge Western Power’s current summers. in MW. In this discussion, annual forecasting methodology and Note: average demand refers to the annual processes. To identify underlying trend The 2014/15 annual peak demand average measured at five minute changes and respond to them as (for the Western Power Network, intervals. This is equivalent to the quickly as possible, Western Power distribution network and SWIS) was average annual volume of electricity continues to refine its methodologies concurrent with this high temperature consumed. and toolsets, as well as challenging event. Historical observations suggest traditional assumptions and models. Load that this event may have resulted in a Customers’ electrical power and higher peak had it occurred during a energy requirements. non-holiday period.
TABLE 1: CHANGE IN ANNUAL PEAK DEMAND - 2013/14 TO 2014/15 (MW)
SWIS Western Power Network Distribution Network 2014/15 Change 2014/15 Change 2014/15 Change 4,032 1.74% 3,605 2.59% 3,176 1.02%
TABLE 2: CHANGE IN ANNUAL AVERAGE DEMAND - 2013/14 TO 2014/15 (MW)22
SWIS Western Power Network Distribution Network 2014/15 Change 2014/15 Change 2014/15 Change 2,279 -1.19% 1,946 -1.87% 1,539 -1.53%
19 All weather data in this chapter is sourced from observations recorded at the Bureau of Meteorology’s Perth Airport weather station. 20 Load factor is not a precise measure and can vary across different areas of the network. A trend of decreasing load factor is generally consistent with lower network utilisation, assuming a constant relationship between network capacity and annual peak demand.
16 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 17 3. DEMAND FORECASTS
TABLE 3: SUMMARY OF TREND CHANGE IN PEAK DEMAND FOR THE a suburb, shire or regional level. In some WESTERN POWER NETWORK - 1998/99 TO 2014/15 cases, the non-coincidental annual peak demand (load) recorded on the 1998/99 2002/03 2006/07 2010/11 FYE substation is much higher than the load - 2002/03 - 2006/07 - 2010/11 - 2014/15 demand recorded on the substation at CAGR 5.4% 6.5% 2.8% 0.2% the time of the coincidental SWIS annual demand peak.
Since 1994/95, the coincidental peak • Annual demand averages on the 3.3 ANNUAL PEAK DEMAND demand load on the Western Power Western Power Network, distribution FORECASTS Network has occurred during summer, network and SWIS were below Western Power reviews its 25 year i.e. the annual summer peak demand 2013/14 levels. annual peak demand forecasts each load has consistently exceeded the The weather impact on demand is year to ensure: winter peak. A key contributor to this discussed in Section 3.5.1. • changes in trends are identified in a has been the increased use of air conditioners, which tend to increase The historical compound annual timely manner the magnitude of peak demand relative growth rate (CAGR) in annual peak • risks in year-to-year load variations to average demand. demand for the Western Power are assessed carefully Network from 1979/80 - 2014/15 3.4 FORECASTING METHOD (inclusive) was 3.7%. As shown in • efficient network expansion plans Table 3, the trend growth rate of the are developed. Up to and including the 2012/13 forecast year, Western Power relied last five years has slowed to zero Annual peak demand forecasts are primarily on an extrapolated historical following two successive four-year developed at a substation level and trend to forecast annual peak demand. periods of reasonably strong growth. then combined to form regional or This allowed the trend growth rate to Western Power Network forecasts. The slowed trend growth reflects a adjust incrementally as new annual This bottom-up approach ensures range of changes in structural factors, peak demand observations were there is sufficient geographic resolution such as: recorded, while recognising the inherent of the forecast annual peak demand year-to-year volatility in demand. • a 59% increase in scale (i.e. a given for network planning. Two peak increase in MW in 2014/15 demand forecasts are developed for Linear trend extrapolation is corresponds to a smaller percentage each substation: appropriate when trend growth increase than it would have in remains within a constant range. 1. non-coincidental with the SWIS 1999/2000) However, review of trend growth rates annual demand peak • changes in technology, which tend over the 15 years from 1998/99 to toward increasing energy 2. coincidental with the SWIS annual 2012/13 showed that this assumption conservation over time demand peak. is no longer valid. In particular, the trend rate of growth had tended to The non-coincidental substation • the continued take-up of self- decelerate over time and it was forecasts identify the maximum annual generation via solar PV appropriate to change the forecasting peak demand for each substation. The method. Changes implemented for the • changing consumer preferences, coincidental forecast is the demand at 2013/14 forecast year have yielded a particularly the continued take-up of each substation recorded at the time significant improvement in forecast self-generation via solar PV. of the SWIS annual peak demand. accuracy (discussed further in Section The non-coincidental substation peak 3.6). These changes are designed to: demand forecasts identify peak • more closely track the non-linear demand and growth at a detailed trajectory of peak demand growth geographical level, allowing both distribution and transmission planning • better separate the underlying trend to cater for expected developments at from year-to-year volatility
21 This was Perth’s third hottest January day on record and its sixth hottest day overall. 22 A review of the method used to calculate the Annual Average Demand indicated that the 2013/14 values published in the corresponding table in the 2014/15 APR were incorrect. The correct values are SWIS: 2,307 MW; Western Power Network: 1,983 MW; distribution network; 1,563 MW.
18 • break down the aggregate trend annual peak demand also needs to be The underlying growth trend at growth into components that can be quantified through the forecasting each substation attributed to specific indicators (e.g. process. The expected variability is This growth component reflects the population growth, changes in quantified by producing a range of consistent stable longer term trend economic activity, changes in annual peak demand forecasts with within a geographic area supplied by a consumer preferences, changes in different probabilities of exceedence substation. It is derived through the and the adoption of technology, and (PoE), typically 50% and 10%. On application of appropriate econometric changes in electricity prices and average, a “50% PoE” forecast should techniques and indicators such as energy efficiency). be exceeded one year in two; the “10% population growth, growth in State PoE” forecast allows for volatility and With trend growth for the Western economic activity, electricity price should, on average, be exceeded one Power Network having fallen to 0% changes, cooling and heating degree year in ten. An advantage of the annually, separating trend from volatile days, appliance and technology volatility of peak demand (+250 MW to movements in peak demand (due improvements resulting in reduced +304 MW) for the Western Power largely to extremes in temperature energy consumption and growing solar Network coincident forecast relates to variation) is becoming more PV penetration in the distribution the sum of the “10% PoE” amounts challenging. For example, annual network. determined for coincident annual peak growth in customers combined with a demand forecast for each Western The block loads at each substation high adoption rate of reverse cycle Power-owned substation. air-conditioning systems suggests that This is the increase in peak demand expected from block loads. For each demand response to temperature Treatment of block loads and substation, a degree of certainty for spikes is likely to grow over time. This transfers means that annual volatility is likely to the block load to occur is determined A block load is one that results in a dominate the trend. and its assumed timing is varied to load increase that exceeds the create three load growth scenarios: The 2015/16 central coincidental demonstrated underlying growth trend low, central and high. To ensure a forecast allows for a ±250 MW volatility calculated for each respective consistent and systematic treatment of range, which represents about 7% of substation. anticipated block loads, Western the 2014/15 Western Power Network A critical element in the new Power has developed a block load annual peak demand. This increases forecasting methodology is the correct framework to determine the certainty to ±304 MW in 2024/25, or about 8% 23 treatment of load transfers and block and timing of each block load. This of the 2014/15 Western Power Network loads to ensure they are reflected framework provides a clear and annual peak demand. accurately in underlying trends. This consistent method for determining and The change in forecasting method has considers historical and future load allocating new block loads across confirmed the historical evidence transfers between substations and the Western Power’s low, central and high (discussed earlier) and Western impact of past and future block loads. forecasts. Power’s view that the deceleration in These refinements ensure that the Variability in annual peak demand trend growth has stabilised. Should underlying trend forecast is not due to the effect of high trend growth begin to accelerate again, distorted by irregular step changes in temperature and other factors more advanced forecasting methods demand. Load transfers and block will permit earlier detection of this loads are then added back to the To cater for this effect, Western Power change than a simple linear forecast trend to produce the develops PoE forecasts by examining extrapolation method. composite forecasts. the volatility of peak demand. This approach captures probable variability The primary objective of Western 3.4.1 KEY DRIVERS OF ANNUAL due to a range of factors, including the Power’s annual peak demand forecast PEAK DEMAND GROWTH likely timing and peak demand impact is to determine the expected annual The following three key drivers of of extreme temperature events such as peak demand growth at each annual peak demand growth are heat waves. substation. The variability of both identified in Western Power’s current coincidental and non-coincidental forecasting process:
23 Section 4.2.1.1 of the 2012 APR presents a detailed description of Western Power’s block load framework: http://www.westernpower.com.au/ documents/apr_2012_web.pdf
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 19 3. DEMAND FORECASTS
3.4.2 REVIEW OF PREVIOUS review its annual peak demand growth in several substation zones. FORECASTS forecasting methods and outcomes to Key factors contributing to this Reviewing the performance of the ensure that good industry practice is increase include: applied consistently. previous year’s forecast is an integral • a number of expansion projects part of the annual forecast cycle. This expected to impact substations 3.5 ANNUAL PEAK DEMAND begins with a thorough assessment of supplying the Kwinana industrial FORECAST: 2015/16 TO 2024/25 the previous summer’s forecast to area over the next two years understand the key drivers of variations The 2014/15 central 50% PoE annual in peak demand and trends (see peak demand forecast for the Western • numerous urban development Sections 3.5.1, 3.5.2 and 3.6). Power Network predicts a compound projects expected to maintain the annual growth rate (CAGR) of 0.3% load growth observed on Following this assessment, Western over the period 2015/16 to 2024/25 substations supplying the coastal Power conducts a detailed review of (inclusive). This represents a region between Baldivis and block loads, comparing the actual load moderation in growth compared to the Margaret River - particularly the area demand of recently-connected block 3.7% growth between 1979/80 and around Mandurah and Meadow loads against forecast. Forecast block 2014/15 (inclusive) and identical to that Springs and the area between loads are also carefully reassessed in predicted by last year’s corresponding Bunbury and Busselton. consultation with stakeholders to identify forecast. changes to underlying assumptions. Compared to the 2014/15 forecast, the Any identified block load changes are The 2015/16 central 50% PoE peak central 10% PoE Western Power incorporated in the new forecasts. demand value for the Western Power Network forecast for 2015/16 has been Network is, however, forecast to be revised from 3,952 MW to 3,962 MW. 3.4.3 INDEPENDENT AUDIT AND about 3% higher than the The corresponding forecast for REVIEW corresponding actual recorded for 2024/25 has been revised from Western Power periodically 2014/15. This reflects expected new 4,101 MW to 4,105 MW, representing commissions independent auditors to block loads, as well as continued an increase of 0.1%.
TABLE 4: WESTERN POWER NETWORK ANNUAL PEAK DEMAND FORECAST - 2015/16 TO 2024/25 (MW)
2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25 2014/15 Central 50% PoE Distribution Load 3,260 3,255 3,254 3,248 3,269 3,275 3,283 3,304 3,326 3,349 Forecast Central 50% PoE Western Power Network Load 3,712 3,707 3,705 3,700 3,721 3,727 3,734 3,755 3,778 3,801 Forecast Central 10% PoE Western Power Network Load 3,962 3,962 3,965 3,965 3,992 4,003 4,018 4,045 4,074 4,105 Forecast Change from 2013/14 forecast Central 50% PoE Distribution Load 1 6 7 5 4 3 2 1 0 -2 Forecast Central 50% PoE Western Power Network Load -8 -3 -4 -5 -6 -7 -8 -10 -10 -11 Forecast Central 10% PoE Western Power Network Load 10 15 14 13 12 9 8 6 5 4 Forecast
20 3.5.1 HISTORICAL PEAK DEMAND SWIS peak demand growth rates in from 4 to 6 January 2015. The The SWIS annual peak demand 2013/14 and 2014/15 were below the maximum temperature of 44.2°C was comprises the total demand from: long-term growth rate of 3.7% from recorded at 4:00pm on 5 January 2015 1979/80 to 2014/15 (inclusive). These (the second day of the heatwave). • Western Power Network distribution years recorded peak demand growth Despite this exceptionally high customers of -0.18% and 1.74% respectively. A maximum temperature, this event’s • Western Power Network significant component of this average daily maximum of 38.9°C was transmission customers difference is attributable to the only the sixth highest of the 18 reduced impact of lower temperatures heatwaves since 2011/12. • customers consuming electricity on load demand (as was the case in Table 6 compares several key without using the Western Power the 2013/14 and 2014/15 summers), temperature-related parameters for the Network changing consumer behaviour previous four summers.25 • transmission and distribution losses. (including the impact of the Individual Reserve Capacity Requirement There was significantly less As shown in Table 5, the contribution mechanism, which is discussed in temperature impact on load demand in to the SWIS annual peak demand by Section 3.5.1.224) and increased the 2014/15 summer than in the three these different customer types has regional demand diversity. preceding summers. It is estimated varied over the last five years. For that the milder 2014/15 summer (cooler example, the contribution by Western 3.5.1.1 Peak demand impact than a 50% PoE summer) reduced the Power Network transmission loads has - weather factors 2014/15 Western Power Network steadily increased from 7.4% in The 2014/15 annual peak demand annual peak demand by approximately 2010/11 to 10.6% in 2014/15. occurred during a three day heatwave 100 MW.
TABLE 5: SWIS SYSTEM PEAK LOAD CONTRIBUTION
2010/11 2011/12 2012/13 2013/14 2014/15
Contribution to SWIS peak demand by Western Power MW 3,283 3,381 3,251 3,144 3,176 Network distribution loads % 82.0 83.4 81.9 79.3 78.8
Contribution to SWIS peak demand by Western Power MW 298 313 360 370 429 Network transmission loads % 7.4 7.7 9.1 9.3 10.6
Contribution to SWIS peak demand by non-Western MW 423 360 359 449 427 Power Network loads and losses % 10.6 8.9 9.0 11.3 10.6 MW 4,004 4,054 3,970 3,963 4,032 SWIS peak demand % 100 100 100 100 100
TABLE 6: SUMMER HEATWAVE FREQUENCY AND TOTAL DURATION - 2011/12 TO 2014/15
Heatwave Total heatwave Days exceeding Year Days > 35°C Days > 40°C periods days peak day max 2011/12 7 26 32 7 6 2012/13 4 18 34 6 1 2013/14 5 23 32 4 6 2014/15 2 8 28 2 0
24 The Individual Reserve Capacity Requirement mechanism allocates the cost of capacity credits acquired to market customers, thus encouraging customers to reduce their demand during peak periods. Further information on this mechanism appears in the 2014 Electricity Statement of Opportunities (Independent Market Operator - June 2015) (pp 28 - 29). 25 Summer refers to the period 1 December to 31 March (inclusive).
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 21 3. DEMAND FORECASTS
The following characteristics of the Furthermore, solar radiance data28 at times of system peak. A lower at-peak 2014/15 summer contributed to the the peak time indicated cloud cover consumption will reduce the capacity reduced impact of weather on load that did not impact the peak’s timing, costs allocated to them to fund the demand: but was sufficient to reduce solar PV capacity of the SWIS in the following output by 40% (76 MW) compared to capacity year. • lower temperatures overall the 184 MW that would be generated The IMO’s 2014 Electricity Statement • fewer heatwave days in total in clear-sky conditions. of Opportunities reported the demand • fewer days with a maximum of The overall impact of the above effects reduction impact (on both the SWIS 35°C27 or higher on both the 2014/15 SWIS and and the Western Power Network) of Western Power Network annual peak the 20 most responsive customer • fewer days with a maximum of 40°C demand resulted in a collective loads during January 2015, including or higher reduction estimate of approximately the 2014/15 demand peak. Figure 2 • fewer days with a maximum equal to 66 MW. As shown in Table 1, the summarises these responses, the peak day maximum or higher. 2014/15 annual peak demand highlighting the afternoons of the three recorded for the Western Power hottest days (based on mean daily Figure 1 ranks the maximum daily Network was 3,605 MW. Adjustment temperature) and the daily maximum summer temperatures from 2011/12 to for the collective reduction estimate temperatures of each. 2014/15. would increase the 2014/15 actual to A number of key insights from the IMO’s Electricity demand in the SWIS 3,671 MW, aligning closely with the report are of particular significance: correlates with air temperature, due corresponding 2013/14 forecast of mainly to the increased use of air 3,677 MW. • At the time of the 2014/15 annual conditioners. Past observations indicate peak demand, 20 market customers that their use increases on the third or 3.5.1.2 Peak demand impact reduced total load by 42 MW. (In fourth day of a heatwave period.27 - Individual Reserve Capacity 2013/14, 44 market customers Requirement mechanism reduced load by 49 MW.) With more residential customers at The Independent Market Operator home on the peak day (5 January • The IMO considers it likely that the established the Individual Reserve 2015) than usual on a regular work day, occurrence of the 2014/15 annual Capacity Requirement mechanism to the peak’s 4:00pm timing was 30 - 45 peak demand on 5 January was the provide market customers with an minutes earlier in the day than would main reason fewer market incentive to reduce consumption at normally be the case at that time of year. customers responded to the IRCR,
FIGURE 1: RANKING OF SUMMER PERIOD MAXIMUM DAILY TEMPERATURES - 2011/12 TO 2014/1526
45
40
35
30 Temperature (C°) Temperature
25
20 1 6 11 16 21 26 31 36 41 46 51 56 61 66 71 76 81 86 91 96 101 106 111 116 121
Ranking of summer period maximum daily temperatures
Summer 2011/12 Summer 2012/13 Summer 2013/14 Summer 2014/15
26 Number of days in the 2011/12 summer = 122. The 2012/13, 2013/14 and 2014/15 summers had 121 days. 27 The Bureau of Meteorology defines a heat wave as three or more consecutive days with maximum temperatures of 35°C or higher. 28 Western Power has installed a number of solar radiance measuring devices in strategic network locations.
22 as some had yet to return to normal peak, the average reduction per perspective on how the SWIS demand levels of activity following the customer was 2.1 MW, significantly peak is changing over time. In the Christmas and New Year break. exceeding the previous year’s context of network investment, it is per-customer average of 1.1 MW. important to emphasise that recent • This view is supported by changes in consumer behaviour have significantly greater demand • In the last three years, 91 unique had greater influence over the reduction on high load days customers have participated in this coincidental SWIS peak demand and occurring later in the summer: mechanism, with an average less influence on the totalised non- reduction of 1.4 MW. At this level, - 27 January 2015 - 88.3 MW coincidental substation peaks. For the concurrent participation of all - 28 January 2015 - 86 MW this reason, Western Power will historical customers would reduce continue to monitor each substation’s - 30 January 2015 - 47.2 MW demand by 120 MW. non-coincidental peak annually to - 3 February 2015 - 76.5 MW 3.5.1.3 Demand peak trend mitigate emerging issues at the • Though fewer customers responded substation level. The historical load duration curves30 at the time of the 2014/15 annual in Figure 3 present an alternative
FIGURE 2: IRCR IMPACT ON SWIS DEMAND PEAK - JANUARY 2015 (MW)29
70
60
50
40 MW 30 Consumption by interval 20 Average summer consumption 10 44oC 40oC 37oC
01/01/2015 06/01/2015 11/01/2015 16/01/2015 21/01/2015 26/01/2015 31/01/2015
FIGURE 3: SWIS LOAD DURATION CURVES
100 100 90 90 80 80 70 70 60 60 50 50
% Load 40 40 % Load Factor 30 30 20 20 10 10 0 % Year 10 20 30 40 50 60 70 80 90 100 2001/2002 Load 2011/2012 Load 2012/2013 Load 2013/2014 Load 2014/2015 Load 2001/2002 LF: 63.4 2011/2012 LF: 54.7 2012/2013 LF: 56.9 2013/2014 LF: 58.7 2014/2015 LF: 57.3
29 Source: 2014 Electricity Statement of Opportunities (Independent Market Operator - June 2015) (pp 28 - 29). 30 A load duration curve shows the percentage of the year that the demand supplied from the SWIS exceeded a given level.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 23 3. DEMAND FORECASTS
3.5.2 COMPARISON OF PEAK of PVs on both the SWIS and the Revised block loads DEMAND FORECASTS - 2011/12 Western Power Network. The As part of the annual forecasting TO 2014/15 expected upward impact of PVs varied process, Western Power consults with As shown in Figure 4, the central 50% between the 2011/12 and 2012/13 relevant stakeholders to determine the PoE Western Power Network annual forecasts, but were consistent in the most likely timing and load demand of peak demand forecasts have changed 2013/14 and 2014/15 forecasts, new projects connecting to the significantly from 2011/12 to 2013/14. reflecting Western Power’s increased Western Power Network. Following this However, the central 50% PoE understanding of this emerging year’s consultation, the block loads Western Power Network annual peak technology. incorporated into the 2014/15 forecast demand forecast developed for were adjusted. However, the overall Trending change 2014/15 is almost identical to the difference in load demand between the corresponding forecast developed in Figure 4 also highlights that there has block loads added to the 2013/14 and 2013/14. This confirms the increased been almost no growth in annual peak 2014/15 forecasts was negligible. accuracy resulting from refinements of demand on the Western Power Western Power’s forecasting Network over the last six years. The Probability of Exceedance change methodology (see Table 4). introduction of econometric forecasting With additional historical data for methods has resulted in a significant 2014/15, the 10% PoE adjustment was The following factors contributed to the downwards shift in the forecast recalculated to reflect the level of minor variation between the two outlook, with all substation forecasts confidence in the underlying growth forecasts: revised with varying but predominantly trend. The recalculated 10% PoE downwards results. The 2013/14 and PV impact adjustment applied to the 2014/15 2014/15 peak demand forecasts share forecast has increased slightly, Since 2010/11, Western Power has almost identical outlooks. indicating increased uncertainty (see adjusted the annual peak demand Table 4). forecast to reflect the expected impact
FIGURE 4: COMPARISON OF WESTERN POWER NETWORK CENTRAL CASE ANNUAL PEAK DEMAND FORECASTS - 2011/12 TO 2014/1531
5,500
5,000
4,500
4,000
3,500
3,000
2,500
Western Power Network load at system peak (MW) 2,000 1998/99 1999/00 2000/01 2001/02 2002/03 2003/04 2004/05 2005/06 2006/07 2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25
Historical WPN Peak Load 2014/15 Central PoE50 WPN 2013/14 Central PoE50 WPN 2012/13 Central PoE50 WPN 2011/12 Central PoE50 WPN
31 This data is presented in tabular form in Appendix E.
24 3.5.3 2014/15 PEAK DEMAND The two central 50% PoE forecasts period ranges from 146 MW to 323 MW, FORECASTS: DIFFERENCES diverge steadily over the forecast the IMO’s again exceeding Western BETWEEN WESTERN POWER period, with the IMO predicting a Power’s. Although the forecast range AND IMO slightly higher compound annual of difference slightly exceeds the The IMO produces annual central peak growth rate of 0.7%, compared to historical range of difference, they are demand forecasts (10% PoE, 50% PoE Western Power’s forecast of 0.3%. The sufficiently close to suggest that this and 90% PoE) for the SWIS. These central 10% PoE forecasts show a close correspondence will continue. similar relationship. represent the peak or maximum In conjunction with improved forecast sent-out electricity entering the SWIS In reconciling the difference in performance (discussed in Section network, which includes all SWIS compound annual growth rates, it 3.6), this increases Western Power’s customers and all losses. They are should be noted that the IMO has confidence in the accuracy of its two therefore higher than the corresponding reduced its trend outlook significantly previous forecasts and the central Western Power Network from last year (2.1%), while Western methodology that generated them. forecasts, but suitable for comparison Power’s is unchanged. Both In this context, Western Power predicts and validation purposes. Figure 5 organisations now have similar trend slightly lower growth than the IMO, compares the two sets of forecasts. outlooks, predicting future growth rate towards the lower end of the likely ranges below historic levels. The difference between the 10% PoE range. Should actual peak demand be and 50% PoE forecasts published by Comparing both organisations’ closer to the IMO’s forecast, Western the IMO differs marginally from the unadjusted historical data from Power will re-evaluate its approach. corresponding difference between 2000/01 to 2014/15 yields differences There is adequate network capacity to Western Power’s forecasts. This is ranging between 121 MW and 257 MW, support either organisation’s peak partly due to the treatment of the last the IMO’s being the greater of the two. demand forecast. nine years of actuals, which have been The difference between the two central 32 weather-adjusted by the IMO. 50% PoE forecasts over the forecast
FIGURE 5: COMPARISON OF 2014/15 CENTRAL CASE PEAK LOAD FORECASTS - WESTERN POWER NETWORK AND IMO33
5,500
5,000
4,500
4,000
3,500
3,000 Peak load (MW)
2,500
2,000
1,500 2000/01 2001/02 2002/03 2003/04 2004/05 2005/06 2006/07 2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25
WP Peak Load Demand (History) WP Central PoE50 (2014/15) WP Central PoE10 (2014/15) IMO Electricity Hist. (raw) Entering SWIS IMO 10% PoE Adj. Hist. Peak Demand IMO Expected Case PoE50 (2014/15) IMO Expected Case PoE10 (2014/15)
32 Source: 2014 Electricity Statement of Opportunities (Independent Market Operator - June 2015) (p96). 33 This data is presented in tabular form in Appendix E.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 25 3. DEMAND FORECASTS
3.6 PEAK DEMAND FORECAST The 2014/15 actual peak demand To ensure that the internal verification VALIDATION measured for the majority of was not distorted by an extraordinarily In addition to commissioning substations was within ±3 MW hot or cold day, Western Power 34 independent reviews and audits of its (78.5% ) of corresponding 2013/14 reviewed the temperature and related forecasts, Western Power reviews forecast values. This is a substantial data for all SWIS peak days from forecasting accuracy for each improvement over last year’s forecast 1998/99 to 2014/15 (inclusive), as 35 substation annually. accuracy, which indicated that 63.5% summarised in Table 7. (The impact of of substations were within ±3 MW of weather factors on 2014/15 annual Figure 6 shows the close the corresponding 2012/13 forecast peak demand is discussed in previous correspondence between Western value. Most of the exceptions resulted detail in Section 3.5.1.1.) Power’s 2013/14 central 50% PoE from the substation forecast being too substation peak demand forecasts and high rather than too low. The average corresponding actual substation peak forecast error (i.e. actual < forecast) demand in 2014/15. per Western Power-owned substation was -1.27 MW.36
FIGURE 6: CENTRAL 50% POE SUBSTATION VARIANCE - 2013/14 FORECAST AND 2014/15 ACTUAL
30 28
25 22
20 Actual < Forecast Actual > Forecast 15 15 13
9 10 8 Mean: -1.27 MW 5 Median: -0.73 MW 5 4 4 4 3 3 Mode: 0 MW 1 1 1 -3 < 0 < +3: 78.5% Count of substations per MW difference 0 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16
Actual minus Forecast (MW)
34 Equates to 95/121 Western Power-owned substations within ±3 MW. 35 Equates to 76/120 Western Power-owned substations within ±3 MW. 36 The 2014/15 APR erroneously reported the average variance for the 2012/13 forecast against 2013/14 actual as +2.4 MW; the correct value was -2.4 MW.
26 TABLE 7: PEAK DAY TEMPERATURE DATA - 1998/99 TO 2014/15
Western Power Max daily Min o/night Ave daily Number of Network peak Date Day of week temp (°C) temp (°C) temp (°C) hotter days demand (MW) 2,019 8/2/1999 38.1 23.9 31.0 3 Monday 2,263 8/3/2000 37.6 25.4 31.5 4 Wednesday 2,299 6/3/2001 37.8 21.2 29.5 5 Tuesday 2,216 31/1/2002 36.1 22.3 29.2 4 Thursday 2,491 10/3/2003 40.1 23.9 32.0 3 Monday 2,760 17/2/2004 40.1 27.3 33.7 3 Tuesday 2,834 15/2/2005 41.1 22.8 32.0 0 Tuesday 2,856 7/3/2006 36.4 20.2 28.3 6 Tuesday 3,201 7/3/2007 41.7 21.6 31.7 0 Wednesday 3,238 11/2/2008 37.1 23.9 30.5 9 Monday 3,341 11/2/2009 38.4 24.9 31.7 3 Wednesday 3,607 25/2/2010 40.8 24.5 32.7 3 Thursday 3,581 25/2/2011 38.7 24.6 31.7 6 Friday 3,694 25/1/2012 40.0 24.8 32.4 6 Wednesday 3,611 12/2/2013 41.1 26.6 33.9 1 Tuesday 3,514 20/1/2014 38.7 20.6 29.7 6 Monday 3,605 5/1/2015 44.2 21.5 32.9 0 Monday
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 27 4. GENERATION SCENARIO PLANNING
Connection of generation to the to loads. The National Electricity Western Power periodically refreshes Western Power Network generally Market (NEM) is based on a published generation development occurs on an unconstrained basis. constrained access model. scenarios in the Annual Planning Report. This informs customers about This means the network is planned Western Power currently plans for the assumptions underlying its projections to ensure that all generators can connection of generation to the of emerging limitations on the export energy up to their declared network through the network access 37 transmission network. Developing sent-out capacities regardless of process. Western Power conducts generation scenarios can be a what other generators are studies on the proposed generation complex process. It relies on a number exporting, under all credible connections to determine whether any of assumptions about the location of contingencies prescribed by the network augmentations are required. new generation, based on an Technical Rules. The objective of The progression of a generator network understanding of likely new generation constrained access is to provide access application is also considered sites, expansion plans of incumbent efficient solutions for the in the development of generation generators and the planning directions connection of new entrant scenarios used for network planning. of government policy. generation. Western Power has proposed the Under different operating conditions connection of new generation on a 4.1 GENERATION CONNECTION and different generation development constrained basis through the ARRANGEMENT and dispatch scenarios, network Competing Applications Group demand may vary from that assumed The adoption of a constrained model solutions detailed in Section 6. for planning purposes. A robust plan is under consideration as part of Constrained access reduces the level positions the network to accommodate the State Government’s Energy of network reinforcement and a range of uncertain futures with Market Review. subsequent capital cost investment optimised investment. To optimise the economic return on required to facilitate the connection of investments made in both the new generation. Project timing and scope may change electricity network and generation as a result of network conditions assets, Western Power sees merit 4.2 USE OF SCENARIOS IN arising that render future plans in a well-planned, systematic and TRANSMISSION PLANNING obsolete. To address this, actual gradual transition from the present Western Power’s transmission planning network expansion is only triggered access model. responds to expected growth in once there is sufficient certainty to maximum demand and the expected justify the projects. Some generation If adopted, this change will have a connection of new generation. proposals are not impacted by significant impact on the planning connecting to the network on a process for the connection of future The long lead times required to obtain constrained access basis and require generation, since network project funding and approvals little or no network development. reinforcement would no longer be (environmental, regulatory and driven by the need for all generators to development) for new transmission The generator connection process is be able to export up to their declared lines often allow generation projects to governed by the Applications and sent-out capacity under defined develop more rapidly than transmission Queuing Policy. Under revisions to this contingencies. In a constrained access line projects. policy introduced in Western Power’s model, the network development is third Access Arrangement, connection Therefore, Western Power must plan typically planned only to ensure applications are aggregated into transmission development on the basis sufficient generation can be Competing Applications Groups, with of a rigorous assessment of the most dispatched to meet load requirements connection solutions developed for likely generation development at any time. In some cases, however, each group. scenarios, since waiting for generation augmenting the network may offer net proponents to commit to plans creates market benefits, such as relieving the risk of extended delays in their certain network constraints or connection. reducing the cost of supplying energy
37 The declared sent-out capacity is the maximum amount of power that the generator has contracted with Western Power to export to the network.
28 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 29 4. GENERATION SCENARIO PLANNING
TABLE 8: SUMMARY OF NETWORK OUTLOOKS
Central Network High-Growth Network Rapid Change Network Outlook Outlook Outlook Engaged consumers and strong centralised action contribute to significant changes to the electricity Return to demand growth, market. Outlook Central network outlook based on including entry of electric The longer term return of carbon description Western Power's view. vehicles. pricing, combined with state-based Climate policy remains static. schemes, result in WA building its pro-rata share of RET generation. Aging capacity is retired. Based on the central scenario load Based on the expected case load Assumed lower load forecast due to Peak demand forecast in 2014-15Western forecast in IMO’s 2014 Statement improved energy efficiency. Power's Annual Planning Report. of Opportunities. High growth in EVs from 2020. Moderate growth in EVs from 2020. Engaged consumers charge Engaged consumers charge vehicles Electric vehicles Few EVs. vehicles predominantly overnight predominantly overnight and during (EV) and during midday solar peaks, midday solar peaks, limiting impact on limiting impact on peak demand. peak demand. Higher PV penetration, but contribution Rooftop PV As per demand forecast. As for demand forecast. is limited to peak demand reduction. No significant large scale or Battery storage As for Central Network Outlook. As for Central Network Outlook. domestic battery storage. Demand management Existing DM providers. As for Central Network Outlook. Additional 50 MW of DM by 2020. (DM) Thermal generation Retirement of Kwinana C units. As for Central Network Outlook. Moderate retirement of units. retirements Based on AEMO's modelling of Lower than Central Network Gas price As per Central Network Outlook. international gas price. Outlook. 33000 GWh by 2020. No state-based WA schemes or Higher share of renewables in WA, RET and incentives for renewable driven by state based incentives. renewable As for Central Network Outlook. generation. WA builds pro-rata share of RET development WA builds less than pro-rata share generation, based on regional energy. of RET generation No carbon price. Emissions No state-based WA emissions Carbon price returns in 2020 at $30 per reduction reduction schemes. As for Central Network Outlook. tonne CO e. ambition No mandated retirement of thermal 2 capacity. Derived from Australian Energy Technology Assessment38 and Lower capital costs for renewable Technology cost As for Central Network Outlook. 2014 National Transmission technologies. Network Development Plan39 data.
38 http://www.industry.gov.au/Office-of-the-Chief-Economist/Publications/Pages/Australian-energy-technology-assessments.aspx 39 http://www.aemo.com.au/Electricity/Planning/Archive-of-previous-Planning-reports/~/media/Files/Electricity/Planning/Reports/NTNDP/2014/ NTNDP%202014%20%20main%20document.ashx
30 4.3 GENERATION SCENARIO the bulk of development under the RET participants will respond to external DEVELOPMENT will occur prior to 2020. market, economic and regulatory drivers. Therefore, multiple generation The current Wholesale Electricity To analyse current electricity market planting schedules may be developed Market features an oversupply of conditions, Western Power engaged for each network outlook. The two generation and stagnant demand independent consultants to assist with most likely generation scenarios based growth forecasts. In present the development of several network on Western Power’s view of the conditions, Western Power has not outlooks capturing a range of possible network outlooks are shown in Table 9. identified a need for new generation future scenarios with potential to affect These generation planting scenarios capacity beyond that required to meet transmission network development. are used to identify existing and the Renewable Energy Target (RET) in These are summarised in Table 8. the short- to medium-term. As current emerging limitations in the legislation requires the RET trajectory Even within a particular network transmission system. to be maintained at its present level outlook, there is uncertainty regarding from 2020 to 2030, it is expected that the way that investors and market
TABLE 9 : GENERATION PLANTING FOR THE TWO MOST LIKELY SCENARIOS
Year Generation Planting Schedule A Generation Planting Schedule B 2014/15 None None Biomass South 40 MW 2015/16 Retired Metro 361 MW Retired Metro 361 MW 2016/17 None None Wind North 130 MW Solar North 30 MW Wind North 130 MW Wind South 40 MW 2017/18 Solar North 30 MW Solar Metro 30 MW Biomass Metro 30 MW Biomass South 40 MW Diesel South 60 MW Wind North 50 MW 2018/19 None Wind South 50 MW 2019/20 Solar Metro 30 MW None 2020/21 None None 2021/22 None None 2022/23 None None 2023/24 None None
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 31 5. COMPLETED PROJECTS
This section describes existing capacity limitations and In addition to the projects listed in this augmentations completed in the forecast constraints on the section, Western Power delivered a period between the publication of transmission and distribution networks. range of network investments to the 2014/15 APR and 30 June 2015. These projects respond mainly to the address drivers of its Network drivers of load growth and new Investment Strategy. The tables in this section list projects connections. The key benefit delivered completed to 30 June 2015 to address by each project is also listed.
TABLE 10: COMMISSIONED PROJECTS - ZONE SUBSTATION AUGMENTATIONS
Project Benefit/s Accommodate increasing demand in the area. Create additional feeder Establish a new Medical Centre (132)66/11 kV capacity to allow for load growth, additional distribution transfer substation capacity, and connection of new large customers. Replacement of two 132/66 kV transformers at Address assets in degraded condition and accommodate increasing Merredin substation with two existing transformers demand in the area. from Cannington terminal Replacement of three 66/22 kV transformers at Address assets in degraded condition and accommodate increasing Narrogin substation with a 33 MVA unit demand in the area. Accommodate increasing demand in the area. Create additional Installation of a fourth 132/22 kV transformer and feeder capacity to allow for load growth and additional distribution switchboard at Midland Junction substation transfer capacity. Accommodate increasing demand in the area. Create additional Installation of a third 132/22 kV transformer at feeder capacity to allow for load growth and additional distribution Mason Road substation transfer capacity. Morley Switchboard Replacement Address assets in degraded condition. Collier Switchboard Replacement Address assets in degraded condition.
TABLE 11: COMMISSIONED PROJECTS - EXISTING SUPPLY POINT AUGMENTATIONS
Project Benefit/s Accommodate increasing demand in the North Country area, in Mid West Energy Project (Southern Section particular mining loads east of Three Springs. Facilitates future staging Stage 1) of a 330 kV network north of Three Springs. Installation of an inter-trip scheme on the Neerabup Address thermal and voltage constraints in Neerabup and North terminal to Three Springs terminal 330 kV circuit Country load areas. New line from Kemerton terminal to Picton, Pinjarra Reduce the out of merit dispatch of 132 kV generation in Muja area and and Busselton 132 kV line support increasing demand in the area. Relocation of Merredin terminal 220/132 kV Reduce the out of merit dispatch of 132 kV generation and increase transformer to Muja terminal to replace failed Muja security of supply in Muja area. BTT2 unit on an interim basis Replacement of failed 330/132 kV bus tie Address failed asset and accommodate increasing demand in transformer BTT1 at Muja terminal with a similar unit the area. Accommodate increasing demand and address thermal constraints in Rockingham to Waikiki 132 kV line uprate the area as a result of transformer failures at Muja terminal. Joondalup to Wanneroo 132 kV line uprate Mitigate thermal constraints on the line. Reinforce poles on 132 kV Kojonup to Increase maximum supportable demand to Albany and Mt Barker Albany circuit substations.
32 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 33 5. COMPLETED PROJECTS
TABLE 12: COMMISSIONED PROJECTS - DISTRIBUTION FEEDER NETWORK AUGMENTATIONS
Project Benefit/s Mitigate safety risk and risk of outages due to under fault rated Albany - Mitigate under fault rated conductor conductor; ensure compliance with the Technical Rules in relation to fault level requirements. Utilise the current opportunity to install spare conduits along Prince Lane whilst the trench is already open by the MRA. These conduits will be CBD - Price Lane install conduits used to provide a route for cables from the CBD into Northbridge to supply new load growth. Collier- reinforce distribution network - 2 Reduce feeder peak loading; improved distribution transfer capacity; feeders reduced risk of long duration outages in the area. Cook street - Distribution network Reduce feeder peak loading; improve distribution transfer capacity; reinforcement reduce the risk of long duration outages in the area. Compliance issue - address protection reach and improve the feeder Eneabba - Install Isolation Transformer imbalance and the spur capacity. Hadfields and Beechboro - Upgrade cable Reduce feeder peak loading; improve distribution transfer capacity; and install new interconnection reduce the risk of long duration outages in the area. Reduce feeder peak loading; Maintain the reliability of supply to Hay St/Milligan St - Balance load on customers, provide necessary DTC and comply with the requirements of feeder pairs the Technical Rules and Distribution Network Planning Guidelines; reduce the risk of long duration outages in the area. Midland Junction - feeder reinforcement Improve capacity constrained feeders. Morley - install new feeders and upgrade Reduce feeder peak loading; improve distribution transfer capacity; conductors (Stage 2) reduce the risk of long duration outages in the area. Mullaloo- Mitigate Under fault rated conductor Reduce safety risk of under fault rated conductor. Mitigate safety risk and ensure adequate protection sensitivity for Narrogin Wickepin Fdr protection reach Network faults; resolution of protection reach for the NGN 511 feeder. Northam - Install Isolation Transformer Compliance issue - address protection reach and improve the feeder Batch 5 imbalance and the spur capacity. Increase distribution capacity and distribution transfer capacity to enable Osborne Park substation - Reconfigure the reliability of supply to new and existing loads in the event of a network network fault; reduce safety and supply risks from asset failures due to overloaded feeders. Resolution of outstanding compliance issues and optimisation of voltage Ravensthorpe resolution of compliance and control device settings including regulator settings and the installation of settings optimisation an isolation transformer to balance load and voltage. South Country Installation of Isolation Compliance issue - address protection reach and improve the feeder transformers Priority 1 imbalance and the spur capacity. Increase distribution capacity to enable the supply of new loads; provided sufficient distribution transfer capacity to allow customers connected to Southern River - Install new feeder all G and SNR distribution feeders to be resupplied in the event of a fault; reduce safety and supply risks from asset failures resulting from feeder overloading. ; upgrade the identified UFRC due to a high safety risk. Reduce feeder peak loading; improved distribution transfer capacity; Wangara - Install new feeders reduce risk of long duration outages in the area. Reduced feeder peak loading; improved distribution transfer capacity; Wanneroo: Reinforce distribution network reduce risk of long duration outages in the area.
34 TABLE 13: INSTALLATION OF CAPACITOR COMPENSATION AND MITIGATION OF VOLTAGE CONSTRAINTS ON THE DISTRIBUTION NETWORK
Project Benefit/s Increased capacity and improved power quality by addressing load Isolation transformers (Batch 4) imbalance issues in the Dongara and Narngulu West areas. Assist in maintaining compliance with the Technical Rules by minimising South Country - install isolation transformer load unbalance and potential for damage to customer equipment and priority 1 mal-operation of protective devices; some capacity is also created. Improved power quality by addressing load imbalance and voltage Kondinin - install voltage regulator issues. Increased capacity and improved power quality by addressing load Isolation Transformers (Batch 4) imbalance issues in the Northam, York, Goomalling, Beverly, Toodyay, Cunderdin, Tammin, Meckering areas. Yanchep - Install Capbank on YP517 Address low voltage issues on the YP517 Wanneroo Rd North feeder.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 35 6. TRANSMISSION SYSTEM ISSUES
The Western Power Network 6.1 BULK TRANSMISSION Western Power recently completed the extends from Kalbarri in the north CAPACITY AND CONSTRAINT Mid West Energy Project (MWEP) to Albany in the south and from Since the early stages of the Southern Section transmission line to the West Coast to Kalgoorlie in the development of the State’s modern increase the power transfer capacity to east. This area covers five major electricity infrastructure, base load Three Springs. The project included a regions that are divided into 15 generation development has been new 330 kV terminal at Three Springs load areas for transmission concentrated in the south west of the and a double circuit 330 kV planning purposes, as shown in system, within close proximity to major transmission structure from Pinjar to Figure 7. coal resources. Three Springs terminal. One of the Pinjar to Three Springs terminal circuits Western Power routinely assesses the With comparatively little base load is currently energised at 330 kV to condition of its transmission assets generation elsewhere on the system, connect Neerabup terminal to Three and the ability of its transmission power supplies are typically transferred Springs terminal and the other circuit is network to supply existing and future from the south of the system to the energised at 132 kV to connect Pinjar demand growth in accordance with major load centres to the north. to Three Springs via Eneabba. This the relevant criteria of the Technical A 330 kV transmission system circuit, together with the existing Rules. This specifies the level of supply provides a backbone for the bulk Northern terminal to Pinjar 330 kV reliability and system security that transfer of electricity to strategic points circuit (which is also currently must be maintained. Western Power’s in the network, including supply to energised at 132 kV) provides an routine assessments identify existing areas north of the metropolitan region. opportunity to further increase transfer and future transmission constraints, There is currently considerable spare capability between the northern which are typically associated with: capacity for increased power transfer metropolitan area and Three Springs • insufficient thermal rating of on the 330 kV network from major through future operation at 330 kV. transmission lines generation centres in the south (around This uplift from 132 kV to 330 kV is Muja and Kemerton) to the Kwinana planned to occur as part of the Mid • fault levels approaching maximum region and further north to Southern, West Energy Project Southern Section equipment specifications Cannington (via Kenwick Link), Stage 2. The timing of this project is • a lack of voltage support in areas of Guildford, Northern and Neerabup dependent on new entrant generation the network terminals. and large loads connecting in the North Country area. • assets in degraded condition. There is considerable flexibility for future expansion of the 330 kV The bulk transmission system north of This section describes the current network to support generation reserve Three Springs terminal operates at supply arrangements on the sharing between the north and south 132 kV and is considered relatively transmission network, the existing of the Western Power Network from weak. Constraints on power transfers constraints and those forecast to the Collie area to the Neerabup area. currently apply under condition of high emerge over the next five years. This is due to: generation north of Three Springs and Conceptual transmission there are considerable ageing assets in augmentations that are being • the Northern terminal to Pinjar the area. Western Power continues to considered to address transmission 330 kV circuit and one of the investigate expansion of the bulk limitations are also presented. Guildford to Northern terminal transmission system north of Three 330 kV circuits currently being Springs as part of the MWEP Northern energised at 132 kV Section. This project would provide • the Southern terminal to Guildford significant bidirectional increase in 330 kV double circuit (currently transfer capability north of Three strung on one side).40 Springs and is likely to be constructed at 330 kV, but potentially be operated at 132 kV for some time. Studies are underway to identify the optimised growth and asset condition timing,
40 This is a double circuit structure for the majority of the distance, with some single circuit structures near the Guildford and Southern terminal ends. A number of additional structures are required to support a double circuit.
36 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 37 6. TRANSMISSION SYSTEM ISSUES
which is dependent on new entrant mitigation equipment. This would result 6.2 LOCAL GENERATION AND generation or large loads connecting in continued underutilisation of the DEMAND MANAGEMENT north of Three Springs (see Section 6.4 330 kV transmission system and OPPORTUNITIES for further information). higher overall network development As part of its usual assessment of costs in the longer term. For many years, the 330 kV alternative solutions, Western Power transmission network has been The power transfer capacity of the may seek expressions of interest for planned and operated in parallel with network is dependent on a number of NCS. However, local generator and the underlying 132 kV network. factors, including the potential for demand management proponents may Augmentations at 132 kV have resulted thermal overload of conductors, fault equally wish to proactively anticipate in a heavily meshed arrangement in levels being in excess of equipment load areas where connection and many areas, particularly around the specifications and voltage or other dispatch of energy services capacity is inner metro areas. While this was a dynamic stability related issues. likely to provide network support and prudent strategy at the time, it has led Network augmentations are necessary therefore have the potential to be to a heavy utilisation of the 132 kV to ensure all Western Power plant facilitated by Western Power. system and lower utilisation of the continues to operate within its This section provides a summary of 330 kV bulk transmission network. capability and the power system emerging limitations in the Under maximum demand conditions, remains reliable and secure in transmission network that arise over some areas of the 132 kV network are accordance with the Technical Rules. the five year outlook. Western Power now operating at capacity, due partly The Western Australian Wholesale anticipates that in some cases local to the 132 kV network being used for Electricity Market (WEM) is generation and/or demand response bulk power transfer between major administered and operated by the capacity could potentially provide terminal sites. IMO.41 The WEM provides the trading useful support to the network and The meshed nature of the network also environment for generation and defer more costly network increases fault levels at various generation developers and demand- investments. Present and aspiring locations, some of which are expected side proponents to make investment market participants with local to exceed equipment specifications in decisions taking into account forecast generation or demand management the near future. The connection of revenue available from the market capacity capable of providing network new generation to the Western Power arrangements. support to alleviate any of the Network will also drive increasing emerging limitations are invited to As Western Power does not direct the fault levels. contact Western Power. location for new generation, it must Western Power has identified benefits make prudent assumptions when 6.3 COMMITTED WORKS associated with de-meshing the modelling long-term generation This section describes transmission 330 kV and 132 kV transmission scenarios in its network planning augmentation projects that have been systems at strategic points in the process. Generation planting scenarios approved and will be completed over network. This would improve the are developed to gain an the next five years. utilisation of the 330 kV transmission understanding of the likely location of network for bulk power transfer, while emerging constraints in the future, Table 14 lists the committed offloading the underlying 132 kV which in turn informs the need for transmission augmentation projects as network and reducing fault levels. It is investment in different parts of the at 30 June 2015. To be considered as anticipated that de-meshing the network. Using probabilistic generation committed, transmission networks may affect reliability of supply scenario based planning techniques augmentations must satisfy all of the and operational flexibility to manage coupled with information regarding following criteria: incidents and will result in a need for new entrant enquires provides • Ministerial approval (if required) additional works to meet mandated guidance on the most likely areas obligations. The alternative to this where network development is • Board commitment has been strategy would be ongoing required. achieved (if required) development of the 132 kV meshed • funding approval network and installation of fault level
41 The roles of independent energy market operator and independent power system operator in Western Australia were transferred to the Australian Energy Market Operator (AEMO) as part of the State Government’s Energy Market Review, (effective 30 November 2015).
38 FIGURE 7: WESTERN POWER NETWORK - TRANSMISSION LOAD AREAS
Karara
Geraldton Mungarra NORTH Three Springs COUNTRY
Three Springs Terminal
Eneabba
Cataby Moora
Regans
Pinjar Muchea NEERABUP
Neerabup Terminal EASTERN GOLDFIELDS Wanneroo Merredin
Mullaloo Northern GUILDFORD Terminal TERMINAL Northam North Merredin Terminal West Kalgoorlie Terminal Midland Beach NORTHERN Junction TERMINAL Osborne Mount Lawley Park Guildford Terminal Darlington
Forrestfield WESTERN TERMINAL Kalamunda East Perth Cook Street Terminal Western Terminal Belmont EAST Kenwick PERTH Cannington Link Terminal Terminal EAST COUNTRY CANNINGTON TERMINAL SOUTH Riverton FREMANTLE Amherst Southern Southern River Terminal Gosnells South Fremantle Terminal
SOUTHERN TERMINAL Bibra Lake Cockburn Cement
Byford Kondinin Kwinana EXISTING TRANSMISSION LINE Terminal 33 kV KWINANA 66 kV 132 kV Pinjarra 220 kV Mandurah Wagerup Boddington
Oakley Terminal Wells Terminal Narrogin South 330 kV Terminal Decommissioned
MANDURAH
Landwehr Terminal FUTURE TRANSMISSION LINE
MUJA 33 kV 66 kV Worsley 132 kV Shotts Terminal Wagin 220 kV Kemerton Terminal 330 kV
Muja Terminal Picton Terminal TERMINAL/SUBSTATION Bunbury Harbour Kojonup Katanning Existing 33kV terminal/substation BUNBURY Existing 66 kV terminal/substation Existing 132 kV terminal/substation Busselton Manjimup Existing 220 kV terminal/substation
Albany Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 39 6. TRANSMISSION SYSTEM ISSUES
• the project has satisfied the • construction has either commenced 6.4 NORTH COUNTRY Regulatory Test (if required) or a firm commencement date set. LOAD AREA • for augmentations required to Any that do not meet all of these The North Country load area extends connect a customer, that a customer criteria are classified as “proposed from Pinjar and Muchea at the has unconditionally signed an network projects”. northern edge of the Neerabup Interconnection Works Contract terminal load area to Kalbarri at the Projects marked with an asterisk (IWC) with Western Power (if required) northern extremity of the Western increase zone substation thermal Power Network. The load area extends capacity. inland approximately 150 km to service the northern Wheatbelt.
TABLE 14: COMMITTED WORKS AS AT 30 JUNE 2015
Project Benefit/s By when Final stage of 66 kV to 132 kV conversion of Joel Accommodate increasing demand in the area; Summer Terrace substation* address ageing assets. 2015/16 Accommodate increasing demand in the area; Summer Establish a new Shenton Park 132/11 kV substation* create additional feeder capacity to allow for load 2015/16 growth and additional distribution transfer capacity. Decommissioning of the old Medical centre substation Summer following establishment of the new Medical Centre Address degraded asset condition. 2015/16 substation Decommissioning of the existing Shenton Park Summer substation following establishment of the new Address degraded asset condition. 2017/18 Shenton Park substation Decommissioning of University substation following Summer Address degraded asset condition. establishment of the new Medical Centre substation 2017/18 Decommissioning of Herdsman substation following Summer Address degraded asset condition. establishment of the new Shenton Park substation 2018/19 Address non-compliance issues on Moora Summer Address compliance issues substation’s transformer 2015/16 Summer Refurbish switchboard at Mason Road substation Address degraded asset condition. 2015/16 Resupply British Petroleum substation from Mason Summer Address degraded asset condition. Road substation 2015/16 Replace indoor switchboard at West Kalgoorlie Summer Address degraded asset condition. substation 2015/16 Replace degraded transformers at Margaret River Summer Address degraded asset condition. substation* 2016/17 Partial conversion of Busselton 66 kV substation Address degraded asset condition; accommodate Winter to 132 kV* increasing demand in the area. 2017 Replacement of under fault rated equipment at North Summer Fremantle, Collier, Milligan Street, Summer Street, Mitigate fault level constraints. 2015/16 Wembley Downs and Western Terminal substation
40 The network is approximately 450 km The MWEP Southern Section Stage 2 Substation capacity long and is largely comprised of two involves: Load forecasts indicate that the single circuit 132 kV lines north of • energising the second side of the capacity of all substations in the North Eneabba and four 132 kV circuits to double circuit 330 kV line Country load area is sufficient for the the south of Eneabba. A number of (constructed as part of Stage 1) to five year outlook. generators inject at various locations 330 kV within the North Country network. The One of the transformers at Moora network has evolved over time, • reinforcement works at Three substation failed catastrophically in primarily supplying relatively small Springs terminal February 2015 and a strategic spare loads distributed over a large transformer was immediately deployed • resupply of Regans substation geographical area. To ensure Western to replace the failed transformer. The Power can continue to provide • 132 kV reinforcements in the emergency transformer deployment reliability of supply to customers and Neerabup load area. had deficiencies in the transformer’s facilitate future generation bund and protection. These The MWEP Northern Section will connections, it is anticipated that the deficiencies are expected to be increase the transfer capacity between North Country load area will be subject addressed by summer 2015/16. Three Springs and Geraldton. This to considerable network development supports potential connection of new Durlacher substation and its over the coming decade. entrant generators and load north of associated transmission line The MWEP Southern Section (Stage 1) Three Springs. infrastructure have been assessed as was recently completed in early 2015. being in degraded condition and have The timings for these projects are This development has been primarily limited capacity to support new mainly dependent on foundation driven by a foundation customer customers. To mitigate these issues, customers. However, strong asset although the development increases Western Power proposes to condition related drivers exist for the power transfer capacity to Three decommission Durlacher substation certain stages of the MWEP. The Springs and facilitates future stages and transfer all loads to the condition of numerous wood pole of work. neighbouring Rangeway substation. In assets between Muchea and order to accommodate the additional Given the availability of renewable Geraldton will require extensive loads at Rangeway substation, a third energy and fuel resources, there has reinforcement and replacement over transformer at the substation is been strong attraction for new entrant the short and medium term, for proposed. generation to be located in the area, example. Investigations are currently with Western Power continuing to underway to establish the optimal Fault levels receive considerable interest in new timing of certain stages of the project There are no significant fault level developments. Given the volume of with consideration to revised load and limitations in the North Country load connection enquiries, it is anticipated generation projections, as well as area at present. There are, however, that over the medium to longer term, long-term wood pole management numerous generation connection the North Country load area is likely to costs. enquiries and fault levels are expected serve the purpose of a generation hub to increase with commissioning of new 6.4.1 EMERGING TRANSMISSION and also service a growing number of generation. Depending on the location NETWORK LIMITATIONS WITHIN A larger mining load developments. and type of future generation, fault FIVE YEAR PERIOD To facilitate the connection of potential levels may become problematic in new entrant generation and block Competing Applications Groups some areas. loads, Western Power is also The North Country load area currently Thermal limits proposing to expand the MWEP as the contains a number of CAGs (see need arises. This staged proposal Section 6.21.1 for additional The following thermal overloads exist currently includes building a 330 kV information). today or emerge over a five year terminal at Eneabba, followed by the horizon, some of which are dependent MWEP Southern Section (Stage 2) and on the dispatch profile of generation in the MWEP Northern Section. the north:
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 41 6. TRANSMISSION SYSTEM ISSUES
• 132 kV circuits between Three With existing generation, the incidence 6.4.2 NORTH COUNTRY LOAD Springs and Mungarra for loss of of a Three Springs busbar overload is AREA TRANSMISSION SYSTEM either parallel circuit unlikely and would be managed DEVELOPMENT operationally through generation • 132 kV Three Springs substation Figure 8 shows a transmission network re-dispatch, rather than reinforcement. busbar. strategy for the North Country load The amount of new entrant generation area, reflecting the impact of the Overloads on the Three Springs to north of Three Springs anticipated MWEP Northern Section (see Section Mungarra 132 kV corridor can occur within the five year outlook will 6.19 for further information). Table 15 under conditions of high generation significantly increase the likelihood of lists the expected benefits of the north of Three Springs in the event of this event and the need for planned works. loss of one circuit. These constraints augmentation works. are managed by generation runback schemes. At present, the majority of Voltage limits the generation capacity connected Following the completion of the MWEP north of Three Springs is wind turbines, Southern Section (Stage 1), power apart from the 112 MW Mungarra gas transfer capacity within the North turbine power station and the 10 MW Country load area has been increased. Greenough River solar farm. As a result, no voltage instability issues are forecast in the area over the next five years.
TABLE 15: NORTH COUNTRY LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Address non-compliance issues on Moora Address compliance issues. Summer 2015/16 substation’s transformer Accommodate increasing demand in the area; Installation of a third 132/11 kV transformer at create additional feeder capacity to allow for load Summer 2017/18 Rangeway substation* growth and additional distribution transfer capacity. Decommissioning of Durlacher substation Address degraded asset condition. Summer 2018/19 Dependent on Three Springs busbar reinforcement Relieve bus bar thermal overload. foundation customers Dependent on Accommodate new entrant generation connections Establish Eneabba 330 kV terminal foundation in the North Country area. customers Accommodate increasing demand and new Dependent on Mid West Energy Project (Southern Section entrant generation connections in the North foundation Stage 2) Country area; facilitate future staging of a 330 kV customers network north of Three Springs. Accommodate increasing demand in the Geraldton Dependent on Mid West Energy Project (Northern Section) area, as well as new entrant generation north of foundation Three Springs. customers
42 FIGURE 8: NORTH COUNTRY LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
Kalbarri Chapman Geraldton Reinforce network north of Three Springs in MWEP Northern Section Golden Grove (dependent on foundation customer) Rangeway Mungarra
Install 3rd transformer Durlacher Walkaway Wind (2017/18) Farm
Karara Mine Mumbida Wind Farm
Decommission Durlacher substation, transfer Three Springs load to Rangeway substation (2018/19)
Three Springs Terminal
Busbar reinforcement (dependent on foundation customers)
Establish future 330 kV Eneabba Eneabba Terminal (dependent on foundation customers)
Emu Downs Address non-compliance issues (2015/16)
Moora Cataby
Convert NT-TST 132 kV network to 330 kV in MWEP Regans Southern Section Stage 2 (dependent on foundation customer)
Muchea Pinjar Kerr McGee Muchea
To Neerabup Terminal To Neerabup Load Area
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 43 6. TRANSMISSION SYSTEM ISSUES
6.5 EASTERN GOLDFIELDS system stability, as well as allow • the power output of local generators LOAD AREA considerable amounts of the Eastern in the area Goldfields load area to continue to The Eastern Goldfields load area is • total power import into the Eastern have supply following separation from centred around the City of Kalgoorlie- Goldfields load area. Boulder. The load area extends west of the rest of the Western Power Kalgoorlie-Boulder to Merredin and Network. These limitations are driven, in part, by south to Kambalda. the relatively low inertia of generating 6.5.1 EMERGING TRANSMISSION units and insufficient reactive reserve. The network in the area supplies NETWORK LIMITATIONS WITHIN A These limitations are currently managed residential and mining loads and FIVE YEAR PERIOD through special control schemes and a provides a transmission link to the rest Competing Applications Groups Dispatch Support Contract operated of the Western Power Network. The by System Management. bulk of supply to the area comes from The Eastern Goldfields load area a long 220 kV single circuit to the currently contains a number of CAGs Saturated reactors at Merredin and Merredin terminal in the adjacent East (see Section 6.21.2 for additional West Kalgoorlie terminals provide Country load area. There is also a information). dynamic reactive support in the area, significant amount of local gas-fired in addition to local generating units. Substation capacity generation installed at Kalgoorlie- Condition assessment of these Boulder, the bulk of which is The capacity of the West Kalgoorlie saturated reactors shows that both are independent power producers 220/132 kV terminal has been deteriorating and reaching the end of supporting in-house mining loads. exceeded. This capacity shortfall is their lives. Western Power is currently currently managed through the dispatch investigating other technologies to Because of its single connection to the of local generators in the area. The replace the ageing saturated reactors, rest of the Western Power Network, West Kalgoorlie terminal has no whilst increasing the power transfer the Eastern Goldfields load area capacity to connect any new customer limit to Eastern Goldfields. 220 kV network is operated to an N-0 connections on a reference service. standard, which presents a reduced Oscillatory stability issues (small signal) level of security. A project to replace one of the failed have also been identified between switchboards at West Kalgoorlie machines in the area and other SWIS A complicating factor in the planning of terminal is underway and expected to generating units. Western Power network augmentation needs in the be complete by summer 2015/16. installed a dynamic power system area is the nature of the surrounding monitoring tool (Psymetrix) to allow loads. These are typically block loads Fault levels better identification of oscillatory required to meet mining needs, which No fault level issues are forecast in the stability-related issues in the area to makes them difficult to forecast due to Eastern Goldfields load area over the improve system security. their inherent volatility in response to next five years. market economics. Considerable 6.5.2 EASTERN GOLDFIELDS uncertainty in demand forecasts in turn Thermal limits LOAD AREA TRANSMISSION creates difficulties when evaluating the Thermal limitations are not expected to SYSTEM DEVELOPMENT need to commit to transmission present any issues over the next five Western Power is currently system reinforcements. NCS years. At present, there are voltage investigating a number of options to opportunities may therefore present and stability limitations which alleviate the voltage and transient alternatives to network solutions, determine the power transfer capability stability limitations in the Eastern especially given the high costs to the Eastern Goldfields load area. Goldfields load area. The expected associated with augmenting a long Should these voltage and stability replacement of the ageing saturated transmission system. limits be relieved in the future, thermal reactors at West Kalgoorlie or Merredin 42 Given its length, the transmission limitations may then become the terminals with new technology are system to the Eastern Goldfields dominant constraint. likely to offer an increase in transfer presents considerable operational limits by 2018/19. Voltage limits challenges, particularly in relation to The preferred transmission network There are voltage and transient stability system stability. A number of special strategy for the Eastern Goldfields load limitations in the Eastern Goldfields control schemes are in place to control area is shown in Figure 9. load area, which are influenced by:
42 The proposed replacement of the SVC at Merredin Terminal is beyond the five year APR horizon, however, a contingency plan is in development.
44 TABLE 16: EASTERN GOLDFIELDS LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replace indoor switchboard at West Kalgoorlie Address degraded asset condition. Summer 2015/16 terminal Installation of additional special protection schemes Relieve rotor angle stability issues in the Summer 2016/17 on Eastern Goldfields’ transmission network area. Mitigate operational and maintenance Streamline Eastern Goldfields special protection issues associated with the large number of Summer 2018/19 schemes special protection schemes in the area. Address degraded asset condition and Replacement of SVC at West Kalgoorlie terminal Summer 2018/19 increase demand in the area. Installation of a third 220/132 kV transformer at Accommodate increasing demand in Dependent on West Kalgoorlie terminal the area. foundation customers
FIGURE 9: EASTERN GOLDFIELDS LOAD AREA - Black Flag PREFERRED TRANSMISSION SOLUTIONS
Replace indoor switchboard (2015/16) SVC Replacement (2018/19) Install third 220/132 kV transformer (dependent on foundation EXISTING TRANSMISSIONcustomers LINE ) Piccadilly 33 kV Parkeston Install additional special protection schemes on Eastern 66 kV Goldfields transmission network 132 kV West Kalgoorlie Terminal (2016/17) 220 kV Boulder Streamline Eastern Goldfields special protection schemes 330 kV (2018/19) Decommissioned
FUTURE TRANSMISSION LINE Western Mining Smelter 33 kV 66 kV 132 kV 220 kV To East Country Load Area 330 kV
EXISTING TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV Existing 33kV terminal/substation 66 kV Existing 66 kV terminal/substation 132 kV Existing 132 kV terminal/substation Western Mining Kambalda 220 kV Existing 220 kV terminal/substation 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point FUTURE TRANSMISSION LINE Future 132 kV terminal/substation 33 kV Future 330 kV terminal/substation 66 kV Normally-open switching point 132 kV 220 kV 330 kV Jan
TERMINAL/SUBSTATION Existing 33kV terminal/substation Existing 66 kV terminal/substation WESTERN POWER ANNUAL PLANNING REPORT 2015/16 45 Existing 132 kV terminal/substation Existing 220 kV terminal/substation Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point 6. TRANSMISSION SYSTEM ISSUES
6.6 EAST COUNTRY LOAD AREA Substation capacity generation in the load area. As part of The East Country load area covers the Asset condition assessments have the connection requirements, Collgar Wheatbelt district of the south west identified that a number of Wind Farm and Merredin Power and is bound by Sawyers Valley and transformers in degraded condition at Station operate under a runback the outer metropolitan area in the west, the following substations: scheme to assist with management of Southern Cross in the east, the Muja this constraint. • Cunderdin substation load area to the south and the North The 132 kV transmission line between Country load area to the north. • Kellerberrin substation Merredin terminal and Merredin The purpose of the network in the area • Mundaring Weir substation. substation can exceed its N-0 limit of is to support local load, as well as to 20 MVA. This is currently managed by A number of asset replacement plans provide a link through to the a load curtailment scheme with an are in place to address these asset neighbouring Eastern Goldfields load existing customer in the area. condition issues, including substation area from the Muja and Guildford load decommissioning, load transfers to Voltage limits areas. adjacent sites and replacement Due to the network security issue in The East Country transmission transformers. the Muja and Bunbury load areas network is connected via 132 kV lines The 66 kV transmission lines supplying following the transformer failures at to the Northern terminal and Guildford Mundaring Weir substation and the Muja terminal, one of the 220/132 kV load areas, as well as 220 kV lines to 66 kV transmission line connecting transformers at Merredin terminal was the Muja and Eastern Goldfields load Merredin, Carrabin and Yerbillon are relocated to Muja terminal on an areas and a 66 kV line to the ageing and in degraded condition. interim basis (see Section 6.7.1). This Cannington load area. The 132 kV Future propsals to address these asset reduces the network security in the networks are normally operated in issues will be aligned with the 66kV East Country load area. In particular, parallel with the 220 kV long term strategy. voltage stability may become interconnection. problematic in both 66 kV and 132 kV Western Power has recently relocated Large generation installations, such as networks west of Merredin under low two 132/66 kV ex-Cannington terminal Collgar Wind Farm and Merredin local generation. Voltage issues are transformers to Merredin substation Power Station, are connected to the also evident around Southern Cross relieving the thermal capacity limitation East Country’s transmission network. substation. In the short term, the use in the area. Under some operating conditions, East of different network configurations in this area (by moving normally-open Country load area can be a net Fault levels generation exporter. points) is expected to be sufficient to No fault level issues are forecast in the manage these issues. In the medium There is an expectation that with the East Country load area over the next term, options under investigation increased penetration of local five years. include returning the 220/132 kV generation, particularly from wind transformer to Merredin terminal. farms, the power flow of the local Thermal limits network may become volatile with the Under peak demand conditions and Merredin substation has two 132/66 kV fluctuations in their output. This could following an outage of a 220 kV line transformers supplying a local 66 kV present some difficulties with operation between Muja and Merredin terminals, sub-transmission network that extends of the transmission network and system thermal limitations on the 132 kV line to Northam. This network has the dispatch may become more difficult. between Northam and Merredin may capacity to be operated in parallel with arise due to the loads in Eastern the 132 kV network between Merredin 6.6.1 EMERGING TRANSMISSION Goldfields. This limitation is currently and Northam, however this is rare. NETWORK LIMITATIONS WITHIN A managed by a protection scheme that Under normal system conditions, the FIVE YEAR PERIOD will island Eastern Goldfields. 66 kV line between Cunderdin and Kellerberrin is out of service to prevent Competing Applications Groups Thermal limitations may also arise as a thermal and voltage issues. The East Country load area currently result of power exports from the East contains a number of CAGs (see Country load area under lighter load Section 6.21.2 for additional conditions, particularly if these occur in information). conjunction with high output from
46 Asset condition assessments have TABLE 17: EAST COUNTRY LOAD AREA - PLANNED WORKS AND also identified that the SVC at Merredin EXPECTED BENEFITS terminal is in degraded condition (see Section 6.5) and is scheduled for Project Benefit/s By when replacement within 10 years. Relocation of ex-Merredin terminal Address potential Summer 220/132 kV transformer from Muja voltage constraints in 2018/19 6.6.2 EAST COUNTRY LOAD AREA terminal back to Merredin terminal the area. TRANSMISSION SYSTEM DEVELOPMENT Decommissioning of Mundaring Weir Address degraded Summer substation asset condition. 2018/19 The preferred transmission network strategy is shown in Figure 10; Table Replacement of 66/22 kV transformers Address degraded Summer 17 lists the expected benefits of the at Kellerberrin substation* asset condition. 2019/20 planned works. Replacement of 66/22 kV transformers Address degraded Summer at Cunderdin substation* asset condition. 2019/20
FIGURE 10: EAST COUNTRY LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
Southern Cross
Yerbillion Carrabin To West Kalgoorlie Terminal Replace 66/22 kV transformers (2019/20) Merredin Replace 66/22 kV transformers Yilgarn (2019/20) Baandee
Merredin Cunderdin Kellerberrin Northam Terminal Collgar Terminal
Wundowie Merredin Power Station Relocate 220/132 kV transformer from Muja To Northern Terminal back to Merredin Terminal (2018/19) Terminal
To Guildford Sawyers Valley Load Area Decommission Mundaring Weir substation, transfer load to Sawyers Valley substation To Cannington Mundaring Weir (2018/19) Terminal
Bounty
Kondinin Narrogin
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 47 6. TRANSMISSION SYSTEM ISSUES
6.7 MUJA LOAD AREA supplying load connected via 132 kV Fault levels The Muja load area extends from Muja and 66 kV transmission lines. A No fault level issues are forecast in the Power Station to Manjimup and significant portion of the 66 kV Muja load area over the next five years. Beenup in the south west, Albany to transmission network was built at There are however numerous the south-east, Boddington to the 132 kV and the long term development generation connection enquiries and north and Narrogin in the north-east. strategy for the 66 kV network is to fault levels are expected to increase The load area includes the agricultural convert it to 132 kV to ensure sufficient with commissioning of new generation. areas of Wagin, Katanning, Kojonup, network capacity will be available to Depending on the location and type of Mount Barker, Denmark and Albany. meet forecast load growth and new future generation, fault levels may customers. become problematic in some areas. Due to the large geographical extent of the load area, its substations supply 6.7.1 EMERGING TRANSMISSION Thermal limits peak loads at various points across the NETWORK LIMITATIONS WITHIN A In 2014, Muja terminal was operating in period of a year. Substations supplying FIVE YEAR PERIOD a reduced security state. Two of the mostly residential loads have a winter Competing Applications Groups three high capacity bus tie peak pattern with substations supplying transformers installed at Muja terminal predominantly agricultural loads having The Muja load area currently contains (Muja BTT1 and BTT2) were out of a summer peak pattern. As a whole, one CAG (see Section 6.21.3 for service following two separate however, the Muja load area is additional information). catastrophic failures over the past two winter-peaking due to heating load. Substation capacity years. To mitigate the issues, Western The Muja load area is connected to the No substation capacity shortfalls are Power completed the following works: Perth metropolitan area and Bunbury forecast in the Muja load area over the • New 132 kV line from Kemerton load area via a strong 330 kV next five years. Terminal to Picton, Pinjarra and transmission network. There is also a Busselton. single 220 kV transmission line from A number of transformers at Wagin Muja terminal that supplies Narrogin and Katanning substations are • Relocation of Merredin terminal South terminal and then continues to expected to be replaced by summer 220/132 kV transformer to Muja the Eastern Goldfields, as well as 2018/19 and summer 2019/20 terminal to replace the failed Muja several 132 kV sub-transmission respectively due to asset condition. In BTT2 transformer on an interim systems connecting to the Bunbury order to align with the long term basis. load area. development strategy of the area, the replacement transformers are • Replacement of the failed Muja BTT1 Given the availability of fuel resources, proposed to be reconfigurable HV, transformer with a new similar unit. particularly coal, the area is home to 66 kV and 132 kV, transformers. Whilst • Rockingham to Waikiki 132 kV line the bulk of base load generating there are no capacity constraints at uprate. capacity on the Western Power these sites, the transformer Network. There is also considerable replacement ensures capacity is Muja terminal now has all three interest in wind generation projects in available for the foreseeable future. transformers restored to service, the area principally on the coast given although Muja BTT2 transformer is of a proximity to wind resources, but also Collie substation and associated 66 kV smaller capacity. As a consequence, inland adjacent to transmission transmission line infrastructure have the power transfer capacity to Eastern infrastructure proposed for mining been assessed as being in degraded Goldfields is reduced for an N-1 developments where wind resources condition. Western Power is currently contingency of Muja BTT3 transformer. are also favourable. managing the maintenance of these This constraint is currently managed assets to extend their lives, whilst through the dispatch of Eastern The security and reliability of the investigating options to address the Goldfields generation and special network in the Muja load area is asset condition issues. These options protection schemes. paramount because of the reliance of include a rebuild and resupply of the neighbouring load areas on the site from 132 kV, or potential The Kojonup to Wagin 66 kV circuit is generation capacity connected to it. decommissioning and transfer of load also overloaded following the loss of The area itself is divided into a number to a neighbouring substation. the Kojonup Katanning 66 kV circuit of independent sub-networks under peak demand. Western Power is
48 investigating the use of different Voltage instability is also experienced investigating options to address the configurations in the 66 kV network by in the 66 kV network around asset condition issues whilst moving or closing normally-open points Katanning, Wagin and Narrogin for a optimising the reactive power to manage thermal overloads between number of contingencies. To alleviate requirements in the area. Kojonup to Wagin. This has proven this issue and the thermal limitations effective in managing thermal loading identified above, Western Power is 6.7.2 MUJA LOAD AREA on the Muja to Kojonup 132 kV circuits. investigating the use of reactive TRANSMISSION SYSTEM compensation and different DEVELOPMENT Voltage limits configurations in the 66 kV network by The preferred transmission network Previously, voltage stability issues were moving or closing normally-open strategy is shown in Figure 11; Table 18 forecast to emerge within the five year points. lists the expected benefits of the outlook in the Albany area due to load planned works. Two reactors connected to the tertiary growth. The majority of the issues have of Muja BTT2 transformer have been now been deferred due to significant assessed to be in degraded condition. reduction in the load forecast. Western Power is currently
TABLE 18: MUJA LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replacement of failed 220/132 kV bus tie transformer Replace a failed asset. Summer 2017/18 BTT2 at Muja terminal with a new unit Relocation of ex-Merredin terminal 220/132 kV Address potential voltage constraints in transformer from Muja terminal back to Merredin Summer 2018/19 the area. terminal Protection upgrades to enable parallel operation of the Mitigate some thermal and voltage Muja 66 kV network between Narrogin and Kojonup Summer 2018/19 constraints in the Muja 66 kV network. and installation of reactive support in the area Address degraded asset condition; Replacement of two reactors connected to Muja optimise reactive power requirements in Summer 2018/19 BTT2 transformer’s tertiary the area. Address degraded asset condition; Replacement of 66/22 kV transformers at Wagin accommodate increasing demand in Summer 2018/19 substation with voltage reconfigurable units* the area. Address degraded asset condition; Replacement of 66/22 kV transformers at Katanning accommodate increasing demand in Summer 2019/20 substation with voltage reconfigurable units* the area.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 49 6. TRANSMISSION SYSTEM ISSUES
FIGURE 11: MUJA LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Southern Terminal To Guildford Load Area Load Area To Bunbury and Southern Terminal Load Area To East Country Wells Terminal Load Area To Northern Boddington Terminal To Oakley and Narrogin South Southern Terminal Alcoa Wagerup Terminal Narrogin Landwehr Wagerup Terminal
To Bunbury Shotts Collie Power Station Load Area Operate Muja 66 kV network closed (2018/19) Bluewaters Worsley Western Collieries Wagin To Bunbury Load Area
Muja Terminal Replace 66/22 kV transformers (2018/19) Replace failed Muja BTT2 (2017/18) Relocate ex Merredin terminal Tx back to Collie Merredin terminal (2018/19) Replace two reactors connected to Muja Katanning BTT2 tertiary (2018/19)
Bridgetown Kojonup Replace 66/22 kV transformers (2019/20)
Beenup Manjimup
Mount Barker
Albany
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
50 6.8 BUNBURY LOAD AREA Substation capacity 132/22 kV transformer in good The Bunbury load area covers the Load forecasts indicate the capacity of condition. Capacity shortfall is forecast south west corner of the Western the following substations in the to occur within the five year outlook. To Power Network stretching from Alcoa Bunbury load area will be exceeded address these issues and align with Pinjarra in the north to Augusta in the within the five year outlook: the long term strategy, which is to south and just west of Wagerup and decommission the 66 kV infrastructure • Busselton substation Worsley. and upgrade to 132 kV, an additional • Capel substation 132/22 kV transformer is proposed to The network in the Bunbury load area be installed by summer 2016/17. serves, in the main, to supply customer • Bunbury Harbour substation. Subsequently, reliance on supply from demand south of Kemerton. The bulk Asset condition assessments have the degraded condition 66/22 kV of supply to support demand in the identified a number of transformers in transformers will be reduced. area comes from the Muja load area degraded condition at Busselton, and from Kemerton terminal via a Fault levels Margaret River, Picton and Capel number of 132 kV transmission lines. substations. No fault level issues are forecast for Power is transferred to Kemerton the transmission network in the terminal at 330 kV from Muja terminal, A number of substation reinforcement Bunbury load area over the next five as well as from other 330 kV terminals. plans are in place to address both years. Local generation at Kemerton also capacity shortfall and asset condition supports demand. issues, including new transformer Thermal limits capacity and replacement of ageing Customer demand south of Picton, The load sharing on various 132 kV transformers with larger capacity units. including demand at Busselton, Capel circuits to the Picton area from Muja and Margaret River represents a The two transformers at Margaret and Kemerton terminals is heavily considerable portion of the total River substations are expected to be influenced by generation dispatch demand in the load area. This is replaced with a larger and conditions. Depending on dispatch supplied by a single 132 kV circuit reconfigurable HV (66 kV and 132 kV) conditions, a number of other from Picton to Busselton and the transformer by summer 2016/17, due overloads emerge across a five year ageing 66 kV transmission network to degraded condition. While there are horizon: that extends from Picton as far south no capacity constraints at these sites, • Southern River to Alcoa Pinjarra / as Margaret River. The transmission the transformer replacement will Wagerup 132 kV circuit following the network south of Picton is already at ensure capacity is available for the loss of the Alcoa Pinjarra to Pinjarra its capacity limit and network foreseeable future. 132 kV circuit reconfiguration is required to ensure Capel substation has two 66/22 kV demand can be met under peak • Alcoa Pinjarra to Pinjarra 132 kV transformers in degraded condition demand. To ensure sufficient long term circuit following a number of and capacity shortfall is forecast to 43 network capacity, Western Power is contingencies. occur within the five year outlook. To investigating options to rebuild the address the these issues and align A generation runback scheme at Alcoa ageing 66 kV transmission network at with the long term development Pinjarra is currently used to control 132 kV. strategy of the area, Western Power power flows on the Southern River to Alcoa Pinjarra / Wagerup 132 kV line. 6.8.1 EMERGING TRANSMISSION proposes to replace the ageing To manage overloads on the Alcoa NETWORK LIMITATIONS WITHIN A transformer with larger capacity and Pinjarra to Pinjarra 132 kV circuit, FIVE YEAR PERIOD reconfigurable HV (66 kV and 132 kV) transformers by 2018/19. Western Power is investigating options Competing Applications Groups such as demand management, Busselton substation has two The Bunbury load area currently generation runback schemes, dynamic switchyards operating at different contains one CAG (see Section 6.21.3 line rating and Distributed Flexible AC voltages. The 66 kV yard has three for additional information). Transmission technology, including 66/22 kV transformers in degraded distributed series reactors. condition and the 132 kV yard has one
43 Depending on the demand in the area and the generation dispatch at Alcoa Pinjarra and other generation in the Muja load area, the Alcoa Pinjarra to Pinjarra 132 kV circuit is forecast to be overloaded pre-contingent within the five year outlook.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 51 6. TRANSMISSION SYSTEM ISSUES
The transmission line between The recent installation of capacitor 6.8.2 BUNBURY LOAD AREA Bunbury Harbour and Muja is banks at Marriott Road and Busselton TRANSMISSION SYSTEM approaching the end of its useful life. and the conversion to double circuit of DEVELOPMENT As part of its longer term network the Kemerton to Marriott Road 132 kV The preferred transmission network development plans, Western Power is provide some relief for the voltage strategy is shown in Figure 12; Table 19 investigating a number of options, limitations, although they are lists the expected benefits of the including line rebuild, and removal of insufficient to ensure adequate supply planned works. this line and resupply of the broader reliability to the area. It is anticipated Picton area via Kemerton terminal. that the conversion of an existing 66 kV Picton to Busselton line to 132 kV will Voltage limits be completed within the five year A number of unacceptable low voltage outlook unless alternative non-network conditions emerge across a five year options are more viable, and will offer horizon. These include low voltage an increase in maximum supportable conditions at Busselton 132 kV and demand for the foreseeable future. 66 kV buses and Margaret River 66 kV buses following the loss of the Picton to Busselton/Pinjarra 132 kV circuit.
TABLE 19: BUNBURY LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replacement of two 66/22 kV transformers at Address degraded asset condition; Margaret River substation with a larger 33 MVA and accommodate increasing demand in the Summer 2016/17 132/66 kV voltage reconfigurable unit* area. Address degraded asset condition; Partial conversion of Busselton 66 kV substation to accommodate increasing demand in the Winter 2017 132 kV* area. Mitigate post-contingent thermal Installation of Alcoa Pinjarra to Pinjarra 132 kV special constraints on the Alcoa Pinjarra to Summer 2017/18 protection scheme Pinjarra 132 kV circuit. Replacement of 66/22 kV transformers at Capel Address degraded asset condition; substation with larger capacity and voltage accommodate increasing demand in the Summer 2018/19 reconfigurable units* area. Replacement of a 66/22 kV transformer at Picton Address degraded asset condition. Summer 2018/19 substation with a voltage reconfigurable unit* Installation of a fourth 132/22 kV transformer at Accommodate increasing demand in the Summer 2019/20 Bunbury Harbour* area. Mitigate voltage constraints in the area; Conversion of one of the Picton to Busselton 66 kV increased maximum supportable demand Summer 2019/20 circuits to 132 kV in the area south of Picton. Mitigate pre-contingent thermal Installation of dynamic line rating and line reactors on constraints on the Alcoa Pinjarra to Summer 2019/20 Alcoa Pinjarra to Pinjarra 132 kV circuit Pinjarra 132 kV circuit.
52 FIGURE 12: BUNBURY LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Southern Terminal, Kwinana, Mandurah, and Muja Load Areas
Install special protection scheme (2017/18) Install dynamic line rating and line reactors (2019/20) Oakley Terminal
Alcoa Pinjarra To Muja Load Area Coolup
Landwehr Terminal
To Muja Load Area Kemerton Power Station
Kemerton Terminal
Marriott Rd To Muja Barrack Silicon Bunbury Load Area Harbour Install fourth transformer (2019/20) Picton Replace 66/22 kV transformer To Muja Load Area (2018/19)
Westralian Sands Replace 66/22 kV transformers (2018/19) Capel Convert PIC to BSN 66 kV network to 132 kV (2019/20)
Busselton
Partial conversion of Busselton 66 kV substation to 132 kV (Winter 2017)
Replace 66/22 kV transformers Margaret River (2016/17)
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 53 6. TRANSMISSION SYSTEM ISSUES
6.9 MANDURAH LOAD AREA Meadow Springs substation and Limitations also arise on the 132 kV The Mandurah load area includes the transferring load from Mandurah to Alcoa Pinjarra to Pinjarra 132 kV southern metropolitan coastal strip Meadow Springs by 2016/17. Full transmission line that connects the bound by Safety Bay Road in the north compliance is expected to be restored Mandurah load area with the Bunbury (including Waikiki substation), in 2019/20 by extending Mandurah load area (see Section 6.8.2 for further Mandurah and Harvey Estuary in the substation and installing additional information). transformer capacity. The proposed south and extends east to encompass Demand management, network project timing for Mandurah substation the Pinjarra substation. control service, dynamic line rating and is largely dependent on the realisation line reactor opportunities are being Supply to the Mandurah load area of the forecast peak demand and explored to address these limitations in comes from 132 kV transmission lines investigations are currently underway the short term. Considering the ageing in the north via Rockingham substation to establish viable opportunities for transmission network in the area, and from the east via Pinjarra alternative network solutions. substation. The neighbouring Kwinana investigations into the rebuild of the and Bunbury load areas supply the Western Power submitted an Mandurah to Pinjarra 132 kV circuit to area with the bulk of its power. application to the ERA for a temporary double circuit construction are also exemption from compliance with under way. The new line rebuild is The bulk of load in the area is along the certain requirements of the Technical expected to be in service in the next southern metropolitan coastal strip Rules in relation to the capacity five to ten years. and served by the existing Meadow requirements at Meadow Springs The 132 kV transmission lines Springs and Mandurah substations, substation. In July 2015, the ERA supplying the Mandurah load area may both of which are experiencing rapid determined that the disadvantages of also become constrainted in the future growth. Waikiki substation is further requiring compliance with the if the forecast load growth materialises. north, at the boundary of the Kwinana Technical Rules were likely to exceed Western Power is currently load area, and is also experiencing the advantages, and therefore investigating a number of options for rapid development. The three approved Western Power’s application the long-term supply to the Mandurah substations are connected via a single for an exemption. 132 kV tee line along the coast. load area, including the establishment Fault levels of a new 330 kV terminal near Pinjarra 6.9.1 EMERGING TRANSMISSION substation. No fault level issues are forecast for the NETWORK LIMITATIONS WITHIN A transmission network in the Mandurah FIVE YEAR PERIOD Voltage limits load area over the next five years. No voltage instability issues are Substation capacity Thermal limits forecast in the Mandurah load area Load forecasts indicate the capacity of over the next five years. the following substations in the Several thermal overloads emerge Mandurah load area will be exceeded over a five year horizon. These include 6.9.2 MANDURAH LOAD AREA within the five year outlook: overloads on the: TRANSMISSION SYSTEM DEVELOPMENT • Mandurah substation • Mandurah to Pinjarra 132 kV circuit following a number of contingencies The preferred transmission network • Meadow Springs substation strategy is shown in Figure 13; Table • Pinjarra to Meadow Springs / 20 lists the expected benefits of the A two-staged investment strategy is in Cannington terminal 132 kV circuit planned works. place to address these emerging following the loss of the Mandurah to capacity constraints. Partial capacity Pinjarra 132 kV circuit. constraints will be resolved by installing additional transformer capacity at
54 TABLE 20: MANDURAH LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Installation of a third 132/22 kV transformer at Accommodate increasing demand in Winter 2017 Meadow Springs the area. Mitigate thermal constraints on the Mandurah Installation of dynamic line rating and line reactors on to Pinjarra and Pinjarra to Meadow Springs / Summer 2018/19 132 kV transmission lines in Mandurah load area Cannington terminal 132 kV circuits. Installation of 2x 66 MVA 132/22 kV transformers Accommodate increasing demand in Summer 2019/20 at Mandurah the area.
To Cannington Load Area FIGURE 13: MANDURAH LOAD AREA - To Kwinana and Southern Terminal Load Areas PREFERRED TRANSMISSION SOLUTIONS
EXISTING TRANSMISSION LINE To Kwinana Load Area 33 kV 66 kV To Northern Terminal Load Area 132 kV Waikiki 220 kV 330 kV Decommissioned
FUTURE TRANSMISSION LINE 33 kV 66 kV 132 kV 220 kV 330 kV
TERMINAL/SUBSTATION Existing 33kV terminal/substation Install third transformer Existing 66 kV terminal/substation (Winter 2017) Existing 132 kV terminal/substation Existing 220 kV terminal/substation Meadow Springs Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation
Future 330 kV terminal/substation Install special protection Normally-open switching point scheme (2017/18) Install dynamic line rating and Mandurah line reactors (2019/20)
Install additional 132/22 kV Alcoa To Southern Terminal Load transformer (2018/19) Pinjarra Pinjarra 132 kV Area, Muja Load Area Install dynamic line rating and line reactors (2018/19)
Alcoa Pinjarra 330 kV
Oakley Terminal
To Bunbury, Muja Load Area
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 55 6. TRANSMISSION SYSTEM ISSUES
6.10 KWINANA LOAD AREA Complex. Furthermore, there is the area is operational and the single The Kwinana load area lies along the considerable residential development 330/132 kV transformer at Kwinana southern metropolitan coastal strip, east of Thomson Lake. terminal must be out of service to bound by Beeliar Drive in the north and manage this issue. This practice has 6.10.1 EMERGING TRANSMISSION extending to Safety Bay Road in the been adequate for a number of years NETWORK LIMITATIONS WITHIN A south. although fault levels in the area are FIVE YEAR PERIOD now approaching limits again, despite The transmission network in this load Competing Applications Groups having the transformer out of service. area is centred on the Kwinana terminal, which is connected to other The Kwinana load area currently In order to relieve fault levels in the major terminals (Southern terminal, contains one CAG (see Section 6.21.3 area, particularly around Kwinana and South Fremantle, Northern terminal, for additional information). Southern terminals, a minor network Kemerton and Oakley) via 330 kV and reconfiguration is proposed offering a Substation capacity 132 kV transmission circuits. Due to partial de-meshing of the Kwinana and the availability of fuel resources, No substation capacity shortfalls are Southern terminal 132 kV networks. particularly gas, there has been a forecast in the Kwinana load area over This project converts the Kwinana strong attraction for generation to be the next five years. terminal to Southern terminal 132 kV circuit into a Kwinana terminal to South sited in the area and Western Power Western Power has recently installed a Fremantle terminal 132 kV circuit, continues to receive considerable third transformer at Mason Road bypassing Southern terminal, as well interest for new entrant generation substation allowing for future load as reinforcing the 132 kV Kwinana to developments. growth, new customer connections Medina and Cockburn Cement tee and the decommissioning of British A number of load areas rely heavily on line. This project is anticipated to be in Petroleum substation. British supply via Kwinana terminal, both service by summer 2016/17. The Petroleum substation has been through the 330 kV and 132 kV project is part of a staged series of identified to be in degraded condition transmission systems. Kwinana work planned for the Kwinana area in and it is anticipated that the substation terminal is therefore a key node on the response to new entrant load and load will be transferred to Mason Road Western Power Network 330 kV generator connections. . backbone system and represents an substation by summer 2015/16. important site for system reliability and Additionally, a project to replace one of Thermal limits the failed switchboards at Mason Road security purposes. A thermal overload on the 132 kV substation is well underway and network from Kwinana terminal to A 132 kV sub-transmission system expected to be complete by 2015/16. extends south from Kwinana terminal Cockburn Cement and Medina may to Rockingham where it abuts the Investigations into the occur following a number of Mandurah load area. A number of decommissioning of British Petroleum contingencies. This thermal overload 132 kV lines also extend north of substation and an alternative supply will be addressed by the planned Kwinana terminal, connecting to arrangement for Broken Hill Kwinana works to partially de-mesh the Cockburn Cement substation, Bibra substation are also underway. This Kwinana and Southern terminals by Lake substation, South Fremantle would permit the retirement of the summer 2016/17. terminal and Southern terminal. remainder of the degraded condition Voltage limits The main role of this 132 kV sub- 66 kV transmission network in the area transmission network is to transfer and reductions in network losses Previous studies have identified power from the generating plant in the through removal of the 132/66 kV potential transient voltage recovery Kwinana load area to nearby industrial transformers at Kwinana terminal. issues on some circuit breakers at loads and to neighbouring load areas. Kwinana terminal. However, recent risk Fault levels assessment has shown that these There are a number of potential large Due to the meshed nature of the issues present negligible risks to public new load developments that may network at Kwinana and Southern safety, workforce safety and network affect the Kwinana area over the terminals, coupled with high levels of reliability. medium- to long- term, including the generation, fault level issues can be Cockburn Coast Development, problematic. During typical peak Latitude 32 and the Australian Marine demand conditions, most generation in
56 6.10.2 KWINANA LOAD AREA TABLE 21: KWINANA LOAD AREA - PLANNED WORKS AND TRANSMISSION SYSTEM EXPECTED BENEFITS DEVELOPMENT Project Benefit/s By when The preferred transmission network strategy is shown in Figure 14; Table Refurbish switchboard at Mason Road Address degraded Summer 21 lists the expected benefits of the substation asset condition. 2015/16 planned works. Resupply British Petroleum substation Address degraded Summer from Mason Road substation asset condition. 2015/16 Reduce fault levels; Kwinana to Southern terminal partial Summer relieve thermal de-mesh 2016/17 limitations.
FIGURE 14: KWINANA LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To South Fremantle To Southern Terminal Load Area
Cockburn Cement Limited Kwinana to Southern Terminal partial demesh (2016/17) Cockburn Cement
EXISTING TRANSMISSION LINE 33 kV To Southern Terminal Load Area 66 kV 132 kV 220 kV 330 kV Decommissioned
To SouthernTerminal FUTURE TRANSMISSION LINE Kwinana Terminal 33 kV Kwinana Power Station 66 kV Kwinana Desalination Plant 132 kV To Northern Terminal 220 kV Broken Hill Kwinana
330 kV Hismelt To Bunbury Load Area Kwinana Donaldson
TERMINAL/SUBSTATION BP Refinery / Kwinana Power Partnership British Medina Petroleum Existing 33kV terminal/substation Kerr McGee Kwinana Mason Rd Existing 66 kV terminal/substation Tiwest Pigment Plant Existing 132 kV terminal/substation Transfer load to Mason Road substation Refurbish switchboard (2015/16) CSBP Existing 220 kV terminal/substation (2015/16) Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Western Mining Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point Australian Fused Materials
Rockingham
To Mandurah Load Area
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 57 6. TRANSMISSION SYSTEM ISSUES
6.11 SOUTHERN TERMINAL Perth terminal and Kwinana terminal. from the 132 kV direct connection LOAD AREA These connections provide a significant between Kwinana terminal and Southern terminal load area covers the power supply to the South Fremantle, Southern terminal, which raises fault region bound by Riverton and Canning East Perth and CBD demand. levels considerably at both sites. Current operational practice is to Vale in the north, Cockburn in the west The meshed nature of the 132 kV remove the Kwinana 330/132 kV bulk and Byford in the south-east. circuits between Cannington and transformer from service under periods Southern terminal presents challenges The network in the area is of high local generation. Even with this for its longer term development. characterised by strong 330 kV ties transformer out of service, fault levels Existing infrastructure has been with generation centres in the south of are again now at equipment limits. established over time, largely as the SWIS (Muja and Bunbury areas), as Current plans involve a partial de-mesh multiple single circuit connections well as 330 kV connections with of the Kwinana and Southern terminal between various substations in the Kwinana, Cannington (via Kenwick load areas to address these limitations Southern and Cannington terminals, Link) and Guildford terminal. A number (see Section 6.10.1 for further rather than as double circuit of load areas rely heavily on Southern information). terminal through the 330 kV and 132 kV transmission networks from each of transmission systems, including South the terminals connected to more Thermal limits radialised substation loads. While the Fremantle (and further north to Power system studies have identified existing practice attempts to optimise Western terminal) and East Perth. very few thermal limitations in the utilisation of existing 132 kV assets, it Southern Terminal load area over the Multiple 132 kV sub-transmission presents issues with operational next five years. Under conditions with circuits extend from Southern terminal, control over power transfers and very high southerly generation, where they form a meshed challenges for longer term network overloads on the 132 kV network from arrangement supplying substations as development in the area. This Southern terminal to East Perth far south as Byford and north towards configuration also has a tendency to terminal are evident following the loss Cannington terminal. Both Southern increase fault levels and reduce of a parallel circuit. A special protection terminal and Cannington terminal utilisation of the 330 kV network. This scheme was initially planned to provide support these substations within the is because the multiple meshed 132 kV an automated response to address this mesh, depending on operating circuits provide a lower impedance limitation although following conditions. From Southern River a path than the 330 kV routes, negotiations with Network Operations, 132 kV circuit extends south to Alcoa particularly between Southern terminal manual intervention was deemed Pinjarra in the Bunbury load area. and Cannington load area. sufficient at this stage. Current There is no notable generation in the 6.11.1 EMERGING TRANSMISSION operational practice is to close the Southern Terminal load area and most NETWORK LIMITATIONS WITHIN A normally-open circuit breaker at supply comes from the 330 kV FIVE YEAR PERIOD Belmont substation in response to the transmission system via three critical contingency. This connects 490 MVA 330/132 kV transformers Competing Applications Groups Belmont substation with Northern connected to Southern terminal. A The Southern Terminal load area terminal and East Perth, providing number of other 132 kV circuits currently contains one CAG (see another path for supply to the CBD, connected to neighbouring load areas Section 6.21.3 for additional therefore lowering flows on the also support the demand. information). remaining Southern terminal to East Southern terminal is an important site Perth circuit. Substation capacity for the interconnection of circuits on Voltage limits the bulk transmission network. It is a No substation capacity shortfall is focal point for supply from the 330 kV forecast in the Southern Terminal load Previous studies have identified system and subsequent supply to area over the next five years. potential transient voltage recovery numerous 132 kV sub-transmission issues on a number of circuit breakers Fault levels systems supporting the broader south at Southern terminal. However, recent metropolitan load. The 132 transmission Due to the heavily meshed 330 kV and risk assessment has shown that the lines directly connect Southern 132 kV network at Southern terminal, issues present negligible risks to public terminal to South Fremantle, East the fault levels are high. A significant safety, workforce safety and network contribution to the fault level comes reliability.
58 6.11.2 SOUTHERN TERMINAL TABLE 22: SOUTHERN TERMINAL LOAD AREA - PLANNED WORKS AND LOAD AREA TRANSMISSION EXPECTED BENEFITS SYSTEM DEVELOPMENT Project Benefit/s By when The preferred transmission network Reduce fault levels; strategy is shown in Figure 15; Table Kwinana to Southern terminal partial Summer relieve thermal 22 lists the expected benefits of the de-mesh 2016/17 planned works. limitations.
FIGURE 15: SOUTHERN TERMINAL LOAD AREA - To East Perth and CBD Load Areas PREFERRED TRANSMISSION SOLUTIONS To Cannington Load Area Bentley
To Cannington Load Area
Maddington Riverton Canning Vale
To Guildford Load Area
Gosnells Murdoch Willetton To South Fremantle Load Area Glen Iris
Southern Terminal Kwinana to Southern Terminal partial demesh (2016/17) Southern River
To Kwinana Load Area
Byford
To Bunbury Load Area To Kwinana Load Area
Meadow Springs / Pinjarra Alcoa Pinjarra / Wagerup
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 59 6. TRANSMISSION SYSTEM ISSUES
6.12 SOUTH FREMANTLE ongoing reliability of supply to the area. Fault levels LOAD AREA Should the terminal be relocated, The fault level at North Fremantle The South Fremantle load area benefits associated with bringing 66 kV substation is projected to extends from Beeliar Drive in the forward the potential 66 kV to 132 kV exceed equipment specifications on south, to the Swan River at its northern voltage upgrade described above will some plant within a five year outlook. boundary and from the coast to the be assessed. One of the difficulties Western Power plans to address the Myaree area in the east. associated with large-scale fault level limitations through developments like the Cockburn Coast replacement of under fault rated The network in the area serves Development is that the load take-up equipment. The planned partial primarily to supply local substation can be difficult to predict accurately. de-mesh of Kwinana and Southern loads, the bulk of which are connected As a result, optimising the timing for terminals at 132 kV by summer to South Fremantle terminal via a 66 kV both new substations in the area to 2016/17 is also expected to offer some sub-transmission network. Supply to supply projected load and offloading benefit (see Section 6.10.1 for further South Fremantle terminal comes from existing sites can be challenging. information). Southern terminal via a 132 kV circuit, Negotiations for appropriate sites and as well as from Kwinana terminal via line corridors in this area are likely to Thermal limits two 132 kV circuits, one of which be protracted. There are no thermal issues forecast in supplies Bibra Lake substation the South Fremantle load area over the en-route. The South Fremantle load 6.12.1 EMERGING TRANSMISSION next five years. area is also connected to the Western NETWORK LIMITATIONS WITHIN A Terminal load area via a 132 kV circuit FIVE YEAR PERIOD Voltage limits between Amherst and Cottesloe Substation capacity There are no voltage stability issues substations, as well as a 66 kV circuit forecast in the South Fremantle load connecting North Fremantle substation No substation capacity shortfall is area over the next five years. with the Western terminal 66 kV forecast in the South Fremantle load area over the next five years. network. This 66 kV circuit is normally 6.12.2 SOUTH FREMANTLE LOAD operated out of service and is typically The 66/22 kV transformers at AREA TRANSMISSION SYSTEM used only to increase reliability of Australian Paper Mills and O’Connor DEVELOPMENT supply to substations at either end substations are proposed to be The preferred transmission network under outage conditions. replaced by 2019/20 due to degraded strategy is shown in Figure 16; Table An ageing 66 kV network supports the asset condition. In order to align with 23 lists the expected benefits of the bulk of the existing substations in the the long term development strategy of planned works. area. Due to its capacity and age, the the area, the replacement transformers 66 kV network is expected to require are proposed to be reconfigurable HV, substantial reinforcement over the next 66 kV and 132 kV, transformers. 20 years, including a potential voltage The 66/11 kV transformers at North upgrade from 66 kV to 132 kV. Fremantle substation and the two Upgrades of this nature can be difficult 66 kV fluid-filled cable sections to stage and are typically delivered supplying the substation (from Edmund over a number of years. Street substation) have been assessed As part of the Cockburn Coast to be in degraded condition. To Development, Western Power has address these asset issues, Western received a request to investigate the Power proposes to resupply North impact of the relocation of the South Fremantle’s load from Cottesloe and Fremantle terminal. Due to the Edmund Street substations and complexity involved with such a decommission the two fluid-filled cable relocation project, considerable sections by 2019/20. planning is required to ensure the
60 TABLE 23: SOUTH FREMANTLE LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replacement of under fault rated equipment at North Summer Mitigate fault level constraints. Fremantle 66 kV substation 2015/16 Replacement of 66/22 kV transformers at Australian Address degraded asset condition; Summer Paper Mills substation with voltage reconfigurable units* accommodate increasing demand in the area. 2019/20 Replacement of 66/22 kV transformers at O’Connor Address degraded asset condition; Summer substation with voltage reconfigurable units* accommodate increasing demand in the area. 2019/20 Resupply North Fremantle substation from adjacent Summer substations and decommission two fluid-filled cable Address degraded asset condition. 2019/20 sections between North Fremantle and Edmund Street
FIGURE 16: SOUTH FREMANTLE LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Western Terminal Load Area
Normally-open switching point
North Myaree Fremantle Replace 66/22 kV transformers (2019/20)
EXISTING TRANSMISSION LINE Replace under fault rated equipment 33 kV (2015/16) 66 kV 132 kV Edmund St Amherst O’Connor 220 kV 330 kV Resupply North Fremantle and decommission cables Decommissioned (2019/20)
FUTURE TRANSMISSION LINE 33 kV 66 kV 132 kV 220 kV To Southern Terminal 330 kV South Fremantle Terminal
TERMINAL/SUBSTATION Australian Paper Mills Existing 33kV terminal/substation Existing 66 kV terminal/substation
Existing 132 kV terminal/substation Replace 66/22 kV Existing 220 kV terminal/substation transformers (2019/20) Bibra Lake Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation
Future 330 kV terminal/substation To Kwinana Load Area Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 61 6. TRANSMISSION SYSTEM ISSUES
6.13 CANNINGTON LOAD AREA The meshed nature of the 132 kV and A number of assets at Tate Street, The Cannington load area is situated in 330 kV circuits between Cannington Clarence Street and Collier Street the south eastern corridor of the and Southern terminal provides substations are showing signs of asset metropolitan area and is bordered by challenges for its longer term deterioration and options for the Swan and Canning Rivers and development. Existing infrastructure decommissioning these sites in the extends east from the CBD to has largely been established over time long term are under investigation. Mundaring. as multiple single circuit connections between various substations in Fault levels The network within the Cannington Southern and Cannington terminals, The fault level at Collier Street 66 kV load area serves the primary purpose rather than a double circuit substation is projected to exceed of supplying substations connected in transmission network from each of the equipment specifications on some the 132 kV and 66 kV sub-transmission terminals connected to more radialised plant within the next five years. networks extending from Cannington substation loads. While the existing terminal. practice attempts to optimise utilisation Thermal limits Cannington terminal is the focal point of existing 132 kV assets, it presents There are no thermal issues forecast in of the load area, with transmission challenges with operational control the Cannington load area over the next connections to Southern terminal, over power transfers and longer term five years. including 132 kV circuits and a 330 kV network development in the area. This Voltage limits circuit via Kenwick Link, providing the configuration also has a tendency to majority of the areas power increase fault levels and reduce There are no voltage stability issues requirements. A 132 kV sub- utilisation of the 330 kV network. This forecast in the Cannington load area transmission system extends north is because the multiple meshed 132 kV over the next five years. from Cannington terminal to connect circuits provide a lower impedance 6.13.2 CANNINGTON LOAD AREA Welshpool, Rivervale, Belmont and path over 330 kV routes, particularly TRANSMISSION SYSTEM Kewdale substations. between Southern and Cannington terminals. DEVELOPMENT Cannington terminal also supports a The preferred transmission network 66 kV network to the west that 6.13.1 EMERGING TRANSMISSION strategy is shown in Figure 17; Table 24 connects Clarence Street, Collier NETWORK LIMITATIONS WITHIN A lists the expected benefits of the Street, Tate Street, Victoria Park and FIVE YEAR PERIOD planned works. one customer-owned substation. Substation capacity Another 66 kV transmission line extends east to connect Mundaring No substation capacity shortfall is Weir, which is in the East Country forecast in the Cannington load area load area. over the next five years.
TABLE 24: CANNINGTON LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replacement of under fault rated equipment at Mitigate fault level constraints. Summer 2015/16 Collier 66 kV substation
62 FIGURE 17: CANNINGTON LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Northern Terminal Load Area
Normally-open switching point Belmont Rivervale
Kewdale Clarance St
Victoria Park
Thomlinson
Welshpool Collier Tate St
To East Country Load Area
CanningtonTerminal Beckenham Replace under fault rated equipment (2015/16)
Kenwick Link Terminal
To Southern Terminal Load Area
To Southern To Southern Terminal Load Area Terminal Load Area To Mandurah Load Area
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 63 6. TRANSMISSION SYSTEM ISSUES
6.14 EAST PERTH AND CBD operates the network in this manner. substation. Although this project was LOAD AREA Two 132 kV circuits from Northern driven primarily by degraded asset The East Perth and CBD load area terminal also support a significant condition, it defers capacity limitations encompasses the Perth CBD, the City portion of CBD substation load at beyond the foreseeable future. Milligan Street substation via Mount of Subiaco and the City of Vincent. Asset conditions assessments have Lawley. The purpose of the network in this area also identified 11 kV switchboards at is primarily to support the densely Construction of new transmission lines Milligan Street and Hay Street populated regions of West Perth, East in the load area is likely to be difficult substations are in degraded condition. Perth and the CBD. Given the due to limited access points across the These switchboards are proposed to centralised high density nature of load, Swan River, service congestion and be replaced by 2017/18 and 2019/20 the area has a heavy reliance on scarcity of available land. This respectively. supply from neighbouring load areas translates to significant challenges in Fault levels including Southern Terminal, Northern planning new injection points and new Terminal, Cannington and Western substation connections. The fault level at the following sites is projected to exceed equipment Terminal. The construction of new transmission specifications on some plant within a lines and zone substations in the area The East Perth and CBD load area is five year outlook: centred on the East Perth terminal, will face challenges in gaining which delivers power to substations environmental and community • Milligan Street substation approvals, incurring significant within the Perth inner metropolitan • Summer Street substation. region, including the CBD. It acts expenditure associated with almost entirely as a load terminal and construction and planning. As such, Western Power is currently planning to supplies seven zone substations via reinforcements in the load area replace the under fault rated 132 kV and 66 kV sub-transmission inherently incur higher project costs. equipment by summer 2015/16. network. Given the load density, in The transmission lines in this load area Thermal limits most operating conditions there are no are generally designed to meet the N-1 Under conditions with very high through-flows from the south of the capacity criterion with the exception of southerly generation, overloads on the load area to the north. Power transfer supply capacity into Hay Street and 132 kV network from Southern terminal can, however, go from East Perth Milligan Street, which is designed to to East Perth terminal are evident terminal to Northern terminal under the CBD N-2 criterion to cater for the following the loss of a parallel circuit. lightly loaded conditions, particularly increase security of supply This limitation is managed through with minimal generation operating in the requirements. north of the Western Power Network. manual network reconfiguration by 6.14.1 EMERGING TRANSMISSION Network Operations (see Section 6.11.1 Supply into the load area comes from NETWORK LIMITATIONS WITHIN A for further information). two 132 kV cables that cross the Swan FIVE YEAR PERIOD River via the Graham Farmer Freeway, Voltage limits which connects Southern terminal and Substation capacity There are no voltage stability East Perth load areas. There is also An N-2 capacity shortfall44 between limitations identified in the CBD and one 132 kV transmission line/cable Hay Street and Milligan Street East Perth load area across a five between Western terminal and Cook substations currently exists during year outlook. Street substation. periods of peak demand. To address 6.14.2 EAST PERTH AND CBD A transmission line from Belmont the N-2 shortfall, a new 132 kV cable LOAD AREA TRANSMISSION substation in the Cannington load area between Hay Street and Milligan Street SYSTEM DEVELOPMENT forms a tee line with a 132 kV circuit substations is proposed for completion The preferred transmission network connecting East Perth to Northern by summer 2018/19. strategy is shown in Figure 18; Table terminal. Western Power has identified Western Power has now committed to 25 lists the expected benefits of the advantages having the Belmont end of the remaining stages of the 132 kV planned works. this tee line normally open and now conversion of the Joel Terrace 66 kV
44 This capacity shortfall is marginal and the risk exposure period is defined by the occurrence of two credible contingency events during a 1 in 10 year summer peak
64 TABLE 25: EAST PERTH AND CBD LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Final stage of 66 kV to 132 kV conversion of Joel Accommodate increasing demand in the area; Summer 2015/16 Terrace substation* address assets at the end of their service lives. Replacement of under fault rated equipment at Mitigate fault level constraints. Summer 2015/16 Milligan Street and Summer Street substations Replacement of 11 kV switchboards at Milligan Address degraded asset condition. Summer 2017/18 Street substation Installation of a 132 kV cable between Hay Street Increase maximum supportable demand in Summer 2018/19 substation and Milligan Street substation the CBD under N-2 conditions. Replacement of 11 kV switchboards at Hay Street Address degraded asset condition. Summer 2019/20 substation
FIGURE 18: EAST PERTH AND CBD LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Northern Terminal Load Area
To Northern Terminal
North Perth
To Cannington Load Area
Joel Tce 66 kV Convert 66 kV substation to 132 kV as part of Joel Terrace second Joel Tce 132 kV transformer (2015/16)
Summer St East Perth Terminal Replace under fault rated To Western Terminal equipment (2015/16)
Cook St
Replace switchboards Milligan St (2017/18) To Southern Terminal Load Area Wellington St Hay St
Forrest Ave Replace switchboards (2019/20) Install 132 kV cable (2018/19)
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 65 6. TRANSMISSION SYSTEM ISSUES
6.15 WESTERN TERMINAL The majority of substations in the Nedlands substation assets are also in LOAD AREA Western Terminal load area have degraded condition and Western The Western Terminal load area exhausted their transformers’ capacity, Power is currently investigating options supplies the area bordered by the with multiple sites already operating at to resupply the substation load to Perth CBD to the east, the Swan River capacity or expected to reach limits adjacent substations. This work is to the south, the west coast and over the five year outlook. Many of planned to be completed by 2018/19. Wembley Downs to the north. these sites are also approaching the Future plans will result in retiring the end of their service lives, with the high voltage equipment and ultimately The primary purpose of the network in majority of substations and decommissioning the substation. this area is to support load in the transmission lines in this load area now western suburbs. There are three exceeding 40 years of age and Fault levels 132 kV transmission circuits connected requiring significant replacement The fault level at the following sites is to Western terminal that provide its works. projected to exceed equipment supply. The majority of power is specifications on some plant within a delivered into the load area from an 6.15.1 EMERGING TRANSMISSION five year outlook: overhead line originating from Northern NETWORK LIMITATIONS WITHIN A terminal and South Fremantle terminal. FIVE YEAR PERIOD • Western terminal 132 kV The transmission line from South Substation capacity • Wembley Downs substation 66 kV. Fremantle terminal crosses the Swan River and travels north through the Western Power recently completed the The under fault rated equipment at suburbs of Cottesloe and Nedlands, new Medical Centre substation Western terminal and Wembley Downs supplying Cottesloe and Amherst addressing the capacity shortfall and substation is proposed to be replaced substations that are located in the degraded asset condition issues at by summer 2015/16. South Fremantle load area. The other Medical Centre substation. The new Thermal limits 132 kV circuit connects Western substation will also permit the terminal with Cook Street substation. decommissioning of University No thermal issues are forecast in the substation, which has capacity Western Terminal load area over the Supply to substations in the area is shortfall and multiple assets in next five years. currently achieved through a 66 kV degraded conditions, by 2017/18. sub-transmission network, which forms Voltage limits Similarly, Western Power has also two distinct rings. A northerly 66 kV No voltage instability issues are committed to establishing a new ring supplies the Wembley Downs, forecast in the Western Terminal load substation at Shenton Park by Herdsman Parade and Shenton Park area over the next five years. substations; the southerly ring supplies 2015/16. This will permit the the Medical Centre, University and decommissioning of Shenton Park and 6.15.2 WESTERN TERMINAL LOAD Nedlands substations. The 66 kV Herdsman Parade substations due to AREA TRANSMISSION SYSTEM network is nearing the end of its useful degraded asset condition by 2017/18 DEVELOPMENT and 2018/19 respectively. life. This, coupled with the need to The preferred transmission network support future load growth in the area, strategy is shown in Figure 19; Table is driving a conversion from 66 kV to 26 lists the expected benefits of the 132 kV assets over time. planned works.
66 TABLE 26: WESTERN TERMINAL LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Accommodate increasing demand in the Summer Establish a new Shenton Park 132/11 kV substation area; cater for retirement of existing Shenton 2015/16 Park 66 kV substation. Replacement of under fault rated equipment at Wembley Summer Mitigate fault level constraints. Downs substation and Western terminal 2015/16 Decommissioning of University substation following Summer Address degraded asset condition. establishment of the new Medical Centre substation 2017/18 Decommissioning of the existing Shenton Park substation Summer Address degraded asset condition following establishment of the new Shenton Park substation 2017/18 Decommissioning of Herdsman substation following Summer Address degraded asset condition. establishment of the new Shenton Park substation 2018/19 Summer Resupply Nedlands substation from adjacent substations Address degraded asset condition. 2018/19 Build new 132 kV double circuit lines from Western terminal Address degraded asset condition; Summer to new Shenton Park and Medical Centre substations accommodate increasing demand in the area. 2019/20
FIGURE 19: WESTERN TERMINAL LOAD AREA - To Northern Terminal
PREFERRED TRANSMISSION SOLUTIONS Decommission Herdsman substation, transfer load to Shenton Park substation (2018/19)
Replace under fault rated Herdsman WembleyDowns equipment (2015/16) Parade
Establish future 132 kV Shenton Park substation (2015/16) EXISTING TRANSMISSION LINE 33 kV 66 kV To East Perth and Shenton Park CBD Load Area 132 kV Western Terminal Build new 132 kV 220 kV double circuit lines 330 kV (2019/20) Decommissioned Medical Centre (New) Decommission Shenton Park FUTURE TRANSMISSION LINE substation (2017/18) 33 kV 66 kV Nedlands University 132 kV 220 kV Cottesloe Decommission University substation, 330 kV transfer load to Medical Centre (2017/18) Transfer loads to adjacent substations (2018/19) TERMINAL/SUBSTATION Existing 33kV terminal/substation Existing 66 kV terminal/substation Existing 132 kV terminal/substation Existing 220 kV terminal/substation Existing 330 kV terminal/substation Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation
Future 330 kV terminal/substation To South To North Fremantle Fremantle Normally-open switching point Load Area
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 67 6. TRANSMISSION SYSTEM ISSUES
6.16 GUILDFORD LOAD AREA and Northern terminal, which is Fault levels The Guildford load area is bound by currently operated at 132 kV on one No fault level issues are forecast to 45 Perth Airport in the west, the Midland circuit . Operation at 132 kV defers emerge for the transmission network in area to the north and Kalamunda to the need for further 330/132 kV the Guildford load area within the next the south. The area is a likely transformation capacity at Northern five years. development precinct, given the large terminal by providing an additional amount of undeveloped land and its 132 kV supply to Northern terminal, as Thermal limits proximity to the CBD. well as providing support for multiple Western Power has received a number contingency conditions at both sites. of enquiries regarding new customer The transmission network in this area While these benefits are clear, connections and load increases for is focused around Guildford terminal, operation at 132 kV increases loading existing customers in the Guildford and which is connected to other major on the Guildford terminal 330/132 kV Eastern Goldfields load areas. Should terminals including Northern terminal transformer and reduces utilisation at these materialise, the Guildford to by 330 kV and 132 kV transmission the 330 kV level between Northern and Forrestfield 132 kV circuit will be circuits, as well as Southern terminal Guildford terminals, along with thermally overloaded following loss of by a 330 kV circuit. There are also increasing overall line loss. Western Darlington to Midland Junction 132 kV 132 kV circuits connecting the Power considers these trade-offs circuit. To mitigate the issues, Western Guildford load area to the Muja and carefully when assessing Power is investigating a number of East Country load areas. The network reinforcement needs at both terminals. options including load transfers, line within Guildford load area serves the It is not anticipated that reinforcement reconfiguration and special protection primary purpose of supplying will be required in the medium-term. schemes. substations connected in the 132 kV sub-transmission systems extending 6.16.1 EMERGING TRANSMISSION Voltage limits from Guildford terminal. NETWORK LIMITATIONS WITHIN A No voltage stability issues are forecast FIVE YEAR PERIOD The 330 kV and 132 kV bus sections to emerge within the next five years. within Guildford terminal are connected Substation capacity 6.16.2 GUILDFORD LOAD AREA via a single 490 MVA transformer that No substation capacity shortfall is TRANSMISSION SYSTEM supports the majority of demand in the forecast to emerge within the next DEVELOPMENT area. Following an outage of this five years. transformer, Guildford load area relies The current transmission network in on support from Northern terminal and Western Power recently installed an the Guildford load area is sufficient other 132 kV injections from additional transformer at Midland over the next five years (see Figure 20). neighbouring load areas. Junction substation allowing for future load growth and new customer At present there is a double circuit connections. 330 kV line between Guildford terminal
45 This is a double circuit structure for the majority of its length, with some single circuit structures near the Guildford and Southern terminal ends. A number of additional structures are required to support a double circuit.
68 FIGURE 20: GUILDFORD LOAD AREA - CURRENT TRANSMISSION NETWORK
To Northern Terminal Load Area To Northern Terminal
Midland Junction
GuildfordTerminal
Hazelmere To East Country Load Area Darlington
Forrestfield Munday To Muja Load Area
Kalamunda
To Southern Terminal
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 69 6. TRANSMISSION SYSTEM ISSUES
6.17 NEERABUP TERMINAL with the need to address shorter term • Joondalup to Wanneroo 132 kV LOAD AREA transmission and supply related issues circuit following loss of a Northern The Neerabup load area covers the in the area is heavily dependent on terminal 132 kV bus section and northern most part of the Perth new entrant generation and large load Northern terminal to Pinjar 132 kV Metropolitan region, from Padbury and connections in the North Country circuit, although the overload is West Swan in the south to Yanchep in load area. significantly less after the line uprate. the north and Muchea in the east. The Neerabup terminal is a • Pinjar to Yanchep 132 kV circuit The network in the area is strategically important terminal for the following the loss of the Neerabup to characterised by 330 kV ties with future stages of the MWEP southern Wanneroo 132 kV circuit and generation centres in the south of the and northern sections. Neerabup to Pinjar 132 kV circuit. Western Power Network (Muja and 6.17.1 EMERGING TRANSMISSION • Clarkson to Yanchep 132 kV circuit Kwinana areas via Northern terminal), NETWORK LIMITATIONS WITHIN A following the loss of the Neerabup to 330 kV connection with load centres in FIVE YEAR PERIOD Wanneroo 132 kV circuit and the North Country load area, as well as Neerabup to Pinjar 132 kV circuit. numerous 132 kV sub-transmission Competing Applications Groups To address these limitations, Western connections with the Northern terminal The Neerabup Terminal load area Power is currently investigating options and North Country load areas. The currently contains a number of CAGs to install dynamic line rating and line network has evolved over time largely (see Section 6.21.1 for additional reactors on the 132 kV transmission to support the continued high growth information). associated with urban development in lines in the area. the area. Substation capacity These line overloads are expected to Neerabup terminal is the focal point of No shortfall in substation capacity is be much worse when the anticipated the load area and is supplied by a forecast in the Neerabup load area new entrant generation in the North number of generation sources through over the next five years. Country load area is connected. 132 kV and 330 kV transmission lines, Should the customer connections Fault levels including a peaking generation plant materialise, the previous options will that is located near the Neerabup No fault level issues are forecast in not be sufficient. Western Power is terminal site. A single 490 MVA the Neerabup load area over the next also investigating the establishment of 330/132 kV transformer at Neerabup five years. a Pinjar to Wanneroo 132 kV circuit terminal provides bulk interconnection and Neerabup to Wangara and Thermal limits between the 330 kV and 132 kV Landsdale double circuits to relieve the Western Power has identified that networks. generation-driven limitations. The under peak demand conditions and Pinjar to Wanneroo 132 kV circuit The network within Neerabup load high northerly generation, operating would be created by: area is highly meshed with the the Neerabup terminal 330/132 kV 1. converting the existing Neerabup to Northern terminal and North Country transformer out of service can reduce Wanneroo 132 kV double circuit load areas. This mesh can create a number of post-contingent thermal bonded line to double circuit considerable challenges, as numerous overloads, without significantly contingencies within the areas can compromising network security. 2. stringing the second vacant side of generate power system security Network Operations now operates the the Neerabup to Pinjar 132 kV problems under some operating network in this manner in response to structures to create a Neerabup to conditions. In the past, development of potential overloading events. Pinjar 132 kV circuit the network within Neerabup and Under very high northerly generation, Northern terminal has generally 3. connecting the two newly-created several thermal overloads emerge over followed a philosophy of retaining a circuits (Neerabup to Wanneroo and the next five years. These overloads meshed network. While this has Neerabup to Pinjar) together, include: provided many benefits over time, bypassing Neerabup terminal. studies now indicate that splitting the • Mullaloo to Joondalup 132 kV circuit Voltage limits networks into two relatively isolated following loss of a Northern terminal No voltage stability issues are forecast areas offers significant advantages. 132 kV bus section and Northern to emerge within the next five years. Optimising the timing of this split, along terminal to Pinjar 132 kV circuit.
70 6.17.2 NEERABUP TERMINAL TABLE 27: SOUTHERN TERMINAL LOAD AREA - PLANNED WORKS AND LOAD AREA TRANSMISSION EXPECTED BENEFITS SYSTEM DEVELOPMENT Project Benefit/s By when The preferred transmission network Mitigate thermal strategy is shown in Figure 21; Table Installation of dynamic line rating and constraints on a Summer 27 lists the expected benefits of the line reactors on 132 kV transmission number of 132 kV 2019/20 planned works (see Section 6.21.1 for lines in Neerabup load area additional information). circuits in the area.
FIGURE 21: NEERABUP TERMINAL LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To North Country Load To North Country Load Area Area To North Country Load Area
Kerr McGee Muchea
Pinjar Muchea MWEP Southern Section Stage 2 (dependent on foundation customer)
Yanchep Newgen Neerabup
EXISTING TRANSMISSION LINE 33 kV Clarkson Neerabup To Northern 66 kV Terminal Terminal Load 132 kV Area 220 kV 330 kV Install dynamic line rating and line reactors (2019/20) Decommissioned
Wanneroo FUTURE TRANSMISSION LINE 33 kV To Northern 66 kV Joondalup Terminal 132 kV 220 kV 330 kV
Mullaloo Edgewater TERMINAL/SUBSTATION Existing 33kV terminal/substation Existing 66 kV terminal/substation Wangara Existing 132 kV terminal/substation Padbury Existing 220 kV terminal/substation Existing 330 kV terminal/substation Substation to be decommissioned/ Landsdale converted to switching point Future 132 kV terminal/substation To Northern Future 330 kV terminal/substation To Northern Terminal Load Terminal Area Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 71 6. TRANSMISSION SYSTEM ISSUES
6.18 NORTHERN TERMINAL also highly meshed with Neerabup connections. Under current network LOAD AREA load area. This mesh can create configurations, fault levels are The Northern Terminal load area considerable challenges as numerous becoming problematic, especially at covers the northern extent of the Perth contingencies within the Northern the 132 kV level. Western Power has metropolitan area extending from the Terminal and Neerabup load areas can addressed these limitations by coast to Osborne Park and Morley in generate power system security operating the Northern terminal and the south, North Beach in the north challenges under some operating Mount Lawley substation 132 kV and to West Swan in the east. conditions. These load areas rely on buses split under some operating one another in different ways, conditions. This is intended to be an The network in the area is depending on operating conditions. interim measure until the Neerabup characterised by strong 330 kV ties and Northern Terminal load areas with generation centres in the south of 6.18.1 EMERGING TRANSMISSION are decoupled at the 132 kV level in the Western Power Network (Muja and NETWORK LIMITATIONS WITHIN A future years. Kwinana areas) and north in the FIVE YEAR PERIOD Neerabup load area, as well as 330 kV Thermal limits Substation capacity connections with large load areas No thermal issues are forecast in the No substation capacity shortfall is supported by Southern terminal and Northern Terminal load area over the forecast in the Northern Terminal load Guildford terminal. Sub-transmission next five years. networks extend from Northern area over the next five years. terminal at 132 kV and provide supply Asset conditions assessments have Voltage limits to numerous substations in the north identified 11 kV switchboards at No voltage stability issues are forecast metropolitan area, as well as links to Manning Street, Osborne Park and in the Northern Terminal load area over neighbouring load areas including Yokine46 substations in degraded the next five years. Western terminal, Guildford, East Perth condition. These switchboards are and the CBD. proposed to be replaced by 2018/19, 6.18.2 NORTHERN TERMINAL LOAD AREA TRANSMISSION The bulk of supply to the area comes 2019/20 and 2020/21 respectively. SYSTEM DEVELOPMENT from the 330 kV system via two Fault levels 490 MVA transformers at Northern The preferred transmission network terminal, as well as via the 132 kV links Northern terminal is a particularly strategy is shown in Figure 22; Table to Guildford terminal. The network congested site with numerous 330 kV 28 lists the expected benefits of the within Northern Terminal load area is and 132 kV transmission line planned works.
TABLE 28: NORTHERN TERMINAL LOAD AREA - PLANNED WORKS AND EXPECTED BENEFITS
Project Benefit/s By when Replacement of 11 kV switchboards at Manning Address degraded asset condition. Summer 2018/19 Street substation Replacement of 11 kV switchboards at Osborne Park Address degraded asset condition. Summer 2019/20 substation
46 The proposed switchboard replacement at Yokine is beyond the five year outlook of the APR.
72 FIGURE 22: NORTHERN TERMINAL LOAD AREA - PREFERRED TRANSMISSION SOLUTIONS
To Neerabup Load Area Henley Brook
To Neerabup Load To Neerabup Load Area Area To East Country Load Area
To Guildford, Muja Northern and Kwinana Load Terminal North Balcatta Areas Beach Arkana Replace switchboards Beechboro (2018/19)
To Guildford Load Area
Manning Osborne Park Yokine Morley Hadfields
Replace switchboards Mt Lawley (2019/20)
To Western Terminal To East Perth and CBD Load Areas To Cannington Load Area
EXISTING TRANSMISSION LINE FUTURE TRANSMISSION LINE TERMINAL/SUBSTATION 33 kV 33 kV Existing 33kV terminal/substation 66 kV 66 kV Existing 66 kV terminal/substation 132 kV 132 kV Existing 132 kV terminal/substation 220 kV 220 kV Existing 220 kV terminal/substation 330 kV 330 kV Existing 330 kV terminal/substation Decommissioned Substation to be decommissioned/ converted to switching point Future 132 kV terminal/substation Future 330 kV terminal/substation Normally-open switching point
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 73 6. TRANSMISSION SYSTEM ISSUES
6.19 SUMMARY OF limitations and estimated eventual shortfall at the end of the five years. OPPORTUNITIES capacity shortfalls for these parts of Annual peak demand growth rates are Over the next five years, a number of the network within the next five years. also listed in Table 29. The proposed transmission network areas in the network are expected to These network demand limitations solutions are discussed in Sections 6.4 require transmission and distribution requiring a capacity solution tend to to 6.18 and proposed distribution capacity augmentations or alternative typically occur during the annual peak network solutions in Sections 7.1 options (e.g. NCS or demand demand hours on the hottest or coldest a n d 7.2. management) to provide network days of the year, or when a contingency support capacity. Proponents who have Generally, NCS or alternative solutions occurs - e.g. when a line or transformer (or are planning) generation capacity are potentially viable compared to trips. These situations are typically and/or demand management capacity network solutions when they are used infrequent throughout the year. solutions capable of providing network to defer or avoid high-cost network Figure 23 illustrates the potential support are invited to contact Western solutions for a given demand locations where demand management Power to discuss the network requirement. Deferring the high-cost or NCS may alleviate transmission load requirements and opportunities for network solution for one or more years constraints. provision of network support capacity. may be an option in some cases, Queries should be directed to the Head subject to by arranging alternative of Network Planning and Standards. solutions that at least meet the annual Table 29 lists the key existing and peak demand growth each year, rather emerging transmission network than the eventual total capacity
FIGURE 23: MAP OF KEY TRANSMISSION LOAD CONSTRAINTS (0 TO 5 YEARS)
74 TABLE 29: NCS AND DEMAND MANAGEMENT OPPORTUNITIES
Peak Area of Demand Occurrence Proposed Capacity Network Issues Growth of Capacity Network Comment Shortfall Limitation Rate Shortfall Solution (MVA pa) The limitation is affected by a Thermal Mandurah, Summer peak number of substations in overload on < 20 MW Meadow period Refer to Mandurah and Kwinana load areas Mandurah to (within 5 8.75 Springs and between 2pm Section 6.9 but loads at Mandurah, Meadow Pinjarra 132 kV years) Waikiki and 7pm Springs and Waikiki substations circuit have the largest contributions. The limitation takes into account Summer peak the proposed load transfers from Transformer < 10 MW Mandurah period Refer to Mandurah to Meadow Springs capacity (within 5 2.26 substation between 2pm Section 6.9 following additional transformer shortfall years) and 7pm capacity at Meadow Springs by w inte r 2017. Summer / The limitation is affected by a Voltage < 30 MW winter peak number of substations in South of South of Refer to stability issues (within 5 2.56 period Picton but Busselton and Margaret Picton Section 6.8 in the area years) between 2pm River substations have the largest and 9pm contributions. Thermal overload on Summer / The limitation is affected by a Kojonup to Katanning < 20 MW winter peak number of substations in Muja Wagin 66 kV Refer to and (within 5 0.00 period 66 kV network but Katanning and circuit and Section 6.7 Narrogin years) between 12 Narrogin substations have the voltage stability noon and 8pm largest contributions. issues in the area Summer / Transformer < 15 MW winter peak Bunbury Refer to capacity (within 5 1.89 period - Harbour Section 6.8 shortfall years) between 12 noon and 8pm An Expression of Interest was Subject to released in 2014/15. Modelling and Eastern Power transfer Subject to Refer to customer - assessment of network options Goldfields limitations assessment Section 6.5 demand against the submitted responses continues.
Generator proponents should note that times, such additional generation may, management solution will be viable in although additional local generation at other times, exacerbate a generation each of the nominated network areas. output in these load-constrained parts network constraint that may exist for Queries should be directed to the Head of the network at the times of highest the area. of Network Planning and Standards. load demand could be useful in In providing the above general supporting the network constraints information, Western Power does not (thermal, voltage or capacity) at those imply that a generation or demand
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 75 6. TRANSMISSION SYSTEM ISSUES
6.20 NON-COMPETING 6.21 COMPETING APPLICATIONS - 132 kV network capacity between APPLICATION THRESHOLDS GROUPS Three Springs and Pinjar for Thresholds are used by Western As part of the AA3 regulatory generation connected south of Power to help determine ‘competing’ framework, all new connections to the Three Springs load applications as part of the AQP. Western Power Network are subject to - 132 kV network capacity between Thresholds are currently defined by the AQP that came into effect on 1 Three Springs substation and demand values for a given load area or February 2013. This policy contains a Three Springs terminal. network region. construct based on CAGs that group applicants behind common network Generation connection Following a review of the threshold constraints to assess and tailor joint At present, there is very limited levels in June 2014, Western Power network access solutions. capacity to connect substantial new revised its ‘Non-Competing Application generation as a reference service. Thresholds’ test and now only This approach provides the opportunity considers new load applications which for competing applicants to share costs Western Power is currently progressing meet the following two criteria to be for solutions to remove (or reduce) the with a proposed CAG solution that will non-competing for the purpose of the impeding network constraints. The AQP accommodate approximately 358 MW AQ P. also allows applicants to proceed on an of generation applying to be in the individual basis via Applicant-Specific North Country load area between • The total load must not exceed Solutions, if preferred. (see Section 20.3 Mungarra and Pinjar. It is intended that 1.5 MVA for its National Metering of the AQP for additional information). participants be offered a non-reference Identifier (NMI) service, which will require generation This section describes the CAG • The load application must be eligible be constrained at times to maintain solutions currently under development for network tariffs RT1-RT6. system security, mitigating the need for and those proposed to be offered by costly network upgrades. It is Customers on network tariffs RT1 - Western Power. expected that CAG participants would RT6 best represent customers that are migrate to a solution resulting from the considered part of “natural load 6.21.1 NORTHERN REGION EMR. growth”. COMPETING APPLICATIONS GROUPS Western Power issued Preliminary The revised ‘Non-Competing The network transfer capability in the Access Offers to participants in August Application Thresholds’ test applies North Country load area for power flow 2015. across the South West Interconnected in the: Network (SWIN) from September 2014 6.21.2 EASTERN REGION and replaces all previous thresholds • south to north direction is limited by COMPETING APPLICATIONS identified in Western Power’s 2014/15 132 kV network capacity (see GROUPS Annual Planning Report. This Section 6.4.1) The network transfer capability to the amendment ensures thresholds are • north to south direction is limited by: Eastern Goldfields (EGF) is dependent consistent across the SWIN. - 132 kV network capacity in the on a number of critical factors, All load applications deemed to satisfy adjacent Neerabup load area (see including the operation of local the test criteria will be granted firm Section 6.17.1) generation and the availability of critical access to the SWIN. All other load network elements (as described in - 132 kV network capacity between applications will be subject to further Section 6.5). Mungarra and Three Springs, assessment to determine if they are including the Three Springs bus behind network constraints. These bar for generation connected may be subject to inclusion in a CAG, north of Three Springs or processed as part of an Applicant- Specific Solution process.
76 Load connection 6.21.3 SOUTHERN REGION There is no capacity for new block load COMPETING APPLICATIONS connections (in excess of 1.5 MVA) as GROUP a reference service. The Southern Region encompasses a number of load areas, from Kwinana Western Power is currently and Southern Terminal which are investigating CAG solutions that are nearer to the metropolitan area, to expected to accommodate Muja and Bunbury in the far south. approximately 45 MW of new load. The proposal is in the final stages of review The 2014/15 Annual Planning Report to identify options for providing identified a number of limitations, additional supply capacity to the EGF. including under fault rated plant, Network upgrades may be required, thermal overloads and reactive reserve including additional transformation limitations in the metropolitan area. capacity, as well as static and dynamic Following recent reductions in load voltage control at West Kalgoorlie forecasts, reactive reserve limitation terminal. Beyond a certain transfer solutions in the metropolitan area have level, and depending on customer eased. Plans to reconfigure the requirements, the need for large scale network in the south metropolitan area network upgrades or NCS solutions are at an advanced stage (see Section may be required to address the 6.10.1) and will relieve fault level limitations, in particular synchronous limitations, as well as some thermal stability limitations. constraints.
Generation connection Western Power is currently progressing Existing generation in the Eastern a proposed CAG solution to Goldfields and adjacent East Country accommodate approximately 110 MW load areas is limited by thermal of new generation, on the same constraints between the Northam and constrained basis as that described in Merredin terminal substations, as well Section 6.21.1. It is expected that CAG as voltage recovery and transient participants would migrate to a stability limitations. solution resulting from the EMR.
Western Power will commence the Western Power issued Preliminary Notice of Intention process for a Access Offers to participants in August generation CAG solution during 2016, 2015. subject to demand.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 77 7. SUPPLY ISSUES
This section describes emerging criteria specified in the Technical Western Power attempts to balance supply issues on Western Power’s Rules. The committed projects listed transformer loading through distribution network and details reflect their status as at 30 June 2015. distribution feeder optimisation to achieve ideal capacity levels, where it the committed and proposed The needs described in this section is economical to do so. emerging projects to address are primarily based on growth drivers. these issues for each planning Western Power has strategies and 7.1 METRO PLANNING REGION region. It considers the voltage programs of work underway to deal transformations that occur at the with other drivers, such as reliability, The Metro planning region extends as zone substation level, which can asset performance and safety, which far north as Guilderton, as far south as be from 132 kV or 66 kV, down to are not covered in this report. Dawesville and east to Chidlow. 33 kV, 22 kV, 11 kV or 6.6 kV. As part of its Annual Planning Cycle, The Metro planning region is divided The primary supply issues include: Western Power annually updates into four smaller planning sectors network development plans to address naturally defined by the Swan River • shortfall of zone substation power issues forecast to emerge over the and the Darling Escarpment. These are transformer capacity next five to 15 years. These involve a the Metro Central Business District • thermal constraints on distribution detailed assessment of options and (Metro CBD), Metro North, Metro East networks limiting the capability to project deliverability, culminating in a and Metro South. Figure 24 shows the supply loads or transfer loads prudent network investment plan to geographic boundaries of these between zone substations resolve the identified issues. planning sectors. The Metro CBD is defined as its own planning sector due • voltage regulation constraints on For planning purposes, this section to different load characteristics and long distribution feeders limiting the divides the Western Power Network planning requirements. ability to connect new loads into five planning regions. The Metropolitan region is further divided The Metro planning region consists of • voltage imbalance due to into four planning sectors, which are a mixture of overhead and disproportionate loading on the further divided into planning clusters. underground distribution networks. single phase distribution network The country regions are not divided Overhead distribution networks • under-fault-rated conductor in the into sectors, but are organised into dominate the outer fringes, but as network that poses a safety and planning clusters. subdivisions on the outskirts expand asset damage risk during a fault over time, the proportion of Dividing networks to the planning event underground network will continue to cluster level is a prudent methodology, increase. • overloading of distribution since load characteristics and transformers during the summer reinforcement options differ between The overhead networks on the outer peak. clusters. A planning cluster is defined fringes tend to be long feeders that as a group of zone substations with suffer from voltage constraints and As with the projects outlined in Section similar distribution voltages and a reliability issues. This is predominantly 6, Network Development Plans strong level of interconnection through in the north of the Metro planning underlying this report were based on the distribution network, which allows region and, to a lesser extent, in the the 2015 peak demand forecast, in the transfer of load between zone south of the Metro planning region, accordance with Western Power’s substations. where the mean feeder lengths are Annual Planning Cycle. The 2015 peak particularly long. demand forecasts will be used to refine At the planning cluster level, the proposed plans. catchment of the cluster is shown with Much of the underground and the location of the associated zone overhead network within the urban The committed projects have received substation. The respective local fringes experience thermal constraints Western Power formal commitment to government authority (LGAs) areas as they are pushed to accommodate proceed on the basis of the identified intersecting the clusters are also load growth and new developments. needs and detailed assessments of the indicated. This information is presented This is compounded by restrictions on most economic options for addressing for each cluster in maps and tables. feeders’ exit cable ratings caused by them. In identifying these needs, feeder congestion around the zone Western Power applies the planning substations.
78 WESTERN POWER ANNUAL PLANNING REPORT 2015/16 79 7. SUPPLY ISSUES
FIGURE 24: METRO PLANNING SECTORS 7.1.1 METRO CBD (11 KV) PLANNING SECTOR The outer boundaries of the Metro CBD planning sector are growing steadily mainly through residential infill, as developers realise the benefits of
Beermullah staying within close proximity to the CBD. These areas are supplied Seabird primarily from Joel Terrace in the east, Gingin Bindoon North Perth to the north and Cook Street to the west.
Chittering Two Rocks Towards the central region of the Metro
Yanchep CBD planning sector that is bound by Muchea the Swan River, the load is Pinjar characterised primarily by commercial Wanneroo developments, office space and an increase in high density residential Ellenbrook developments.
Sorrento Chidlow Hay Street and Milligan Street Midland substations supply Perth’s CBD with Perth Sawyers Valley interconnections to the surrounding N Cook Street, Wellington Street and Fremantle Forrest Avenue substations.
Roleystone The Technical Rules specify a higher security of supply standard for the CBD loads supplied from Hay Street
Rockingham LEGEND and Milligan Street substations, Major Towns WESTERN POWER NETWORK compared to other distribution Jarrahdale Metro North Port Kennedy networks in the Western Power Metro South Network. The relevant criterion Metro East requires spare capacity on the feeder Metro CBD Mandurah network so that in the event of a fault, load can be automatically restored via the interconnections with minimal customer outage, even during high load periods.
The feeders in the Metro CBD planning sector operate at 11 kV, are relatively short because of the high load density and suffer from thermal constraints, primarily caused by feeder congestion out of the zone substation. In addition, clustering of large loads throughout the Metro CBD planning sector makes it difficult to transfer load effectively. This forms part of the challenge for future planning and new large customer block load connections.
80 Strategic plans for this area include the This project was primarily driven by investigating opportunities to transfer installation of infrastructure such as pit degraded asset condition but it also load between zone substations to best and duct systems, as well as additional defers capacity limitations beyond the manage the reliability of supply until ducts where suitable opportunities foreseeable future. To address the N-2 the projects are in service. Non- arise (such as the Elizabeth Quay and issue, a new 132 kV cable between network solutions such as demand Perth City Link development projects). Hay Street and Milligan Street management techniques are also substations is proposed for completion being investigated to identify As discussed in Section 6.14.1, by summer 2018/19. opportunities to defer capital Western Power is now committed to investment, where it is economical to the remaining stage of the Joel Terrace Given the lead times associated with do so. 66 kV substation conversion to 132 kV. some projects, Western Power is
TABLE 30: METRO CBD - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions47 Milligan Street City of Perth Perth Metropolitan Hay Street City of Vincent Wellington Street City of Bayswater Forrest Avenue City of Stirling Joel Terrace Town of Cambridge Cook Street City of Subiaco North Perth
TABLE 31: METRO CBD - COMMITTED WORKS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Reduce feeder peak loading; improve Forrest Avenue: Distribution distribution transfer capacity; reduce the risk East Perth, Perth Summer 2015/16 network reinforcement of long duration outages in the area. Joel Terrace: Substation Mitigate safety and reliability risks associated Maylands, Mount reinforcement - conversion to with the failure of 66 kV and 11 kV assets Summer 2015/16 Lawley, Bayswater 132 kV that are in degraded condition. Temporary transfers of distribution feeders Joel Terrace : Transfer of between 11 kV switchboards at Joel Terrace Maylands, Mount Summer 2015/16 distribution feeders substation to enable work on conversion to Lawley, Bayswater 132 kV to be carried out in stages.
47 Department of Regional Development.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 81 7. SUPPLY ISSUES
FIGURE 25: METRO CBD 11 KV PLANNING SECTOR N
CITY OF STIRLING METRO PLANNING REGION
CITY OF VINCENT
North Perth CITY OF BAYSWATER
TOWN OF CAMBRIDGE
Joel Terrace
Cook Street
CITY OF PERTH
Milligan Street Wellington Street CITY OF SUBIACO Hay Street
Forrest Avenue
KINGS PARK
LEGEND
Zone Substations
LGA
11kV
7.1.2 METRO NORTH PLANNING • Metro North 22 kV (A) The residential areas are mature SECTOR from a load development perspective, • Metro North 22 kV (B). The Metro North planning sector is however new residential and bound by the Swan River and CBD The 22 kV network is divided into two commercial developments will create planning sector in the south, by the clusters, as there is a limitation to the additional load as part of the Claremont Vines development in the east, Gingin number of interconnections between Oval and Subiaco redevelopments. in the north and Guilderton in the west. zone substations in cluster (A) and Substantial additional load is also cluster (B). The primary reason behind expected as Queen Elizabeth II and The large Metro North planning sector this is the natural physical barrier of UWA’s student housing expand within covers a number of areas with different Whiteman Park. the next two to three years. characteristics. Metro North 6.6 kV planning cluster The distribution voltage in this cluster There are a number of different is 6.6 kV with a mixture of overhead The Metro North 6.6 kV cluster has a distribution voltages in the Metro North and underground distribution network. diverse array of loads that include planning sector. These are a legacy of The 6.6 kV feeder network is short and commercial developments around the network’s development over a is well interconnected among the zone Claremont, Graylands, King Edward number of decades. substations in the planning cluster. The Memorial, Queen Elizabeth II and 6.6 kV operating voltage means that This sector is divided into the following Hollywood hospitals, Irwin Barracks, each feeder is capable of supplying voltage planning clusters: the Subiaco Waste Water Treatment much less power than higher voltage Plant and a number of university • Metro North 6.6 kV (11 kV and 22 kV) feeders. campuses and associated research • Metro North 11 kV facilities.
82 Western Power recently completed the Western Power has committed to the is proposing to address this issue by new Medical Centre 132 kV substation, development of a new Shenton Park resupplying the substation from currently energised at 66 kV. This 132 kV substation by 2015/16. This will adjacent substations by 2018/19. facilitates the necessary load transfers cater for load growth in that area, as Given the lead times associated with from the old Medical Centre and well as accommodate the some projects, Western Power is University substations, as well as decommissioning of both the existing investigating other opportunities to permitting 132 kV transmission Shenton Park and Herdsman Parade transfer load between substations to network upgrades to be staged over a substations, both of which have best manage the reliability of supply number of years. The new substation degraded condition assets, by 2017/18 until the new substations are in service. is intended to cater for the and 2018/19 respectively. Non-network options such as demand decommissioning of the old Medical A number of assets in Nedlands management techniques were found Centre and University substations, substation have been assessed to be to be non-viable due to the asset both of which have assets in degraded in degraded condition. Western Power condition issues. condition.
FIGURE 26: METRO NORTH PLANNING SECTOR - VOLTAGE PLANNING CLUSTERS
Beermullah
Seabird
Gingin Bindoon
Chittering Two Rocks
Yanchep N Muchea
Pinjar
Wanneroo
Ellenbrook METRO PLANNING REGION
LEGEND
Major Towns Midland
6.6kV City Beach 11kV Subiaco 22kV (A)
22kV (B) Cottesloe
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 83 7. SUPPLY ISSUES
TABLE 32: METRO NORTH 6.6 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Herdsman Parade City of Stirling Perth Metropolitan Medical Centre Town of Cambridge Nedlands City of Subiaco Shenton Park City of Nedlands University Town of Claremont City of Perth
TABLE 33: METRO NORTH 6.6 KV - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Medical Centre & University: Sir Charles Gardiner Conversion of existing Medical Accommodate increasing demand and Medical Centre, Summer 2015/16 Centre and University assets at the end of their service lives. Nedlands distribution network to 11 kV Medical Centre: Sir Charles Gardiner Decommissioning of existing Address degraded asset condition. Medical Centre, Summer 2015/16 Medical Centre substation Nedlands Shenton Park: Construction of a Shenton Park, Daglish, new Shenton Park substation Accommodate increasing demand and Jolimont, Mount Summer 2015/16 and distribution network assets at the end of their service lives. Claremont, Karrakatta, conversion to 11 kV Claremont Shenton Park: Decommissioning of existing Shenton Park Address degraded asset condition. Shenton Park Summer 2017/18 substation University: Decommissioning of Address degraded asset condition. Crawley Summer 2017/18 University substation Herdsman: Decommissioning of Herdsman Parade Address degraded asset condition. Summer 2018/19 Herdsman Parade substation substation, Wembley
84 FIGURE 27: METRO NORTH 6.6 KV PLANNING CLUSTER
CITY OF STIRLING N
Herdsman Parade
METRO NORTH PLANNING SECTOR TOWN OF CAMBRIDGE
CITY OF SUBIACO
Shenton Park
KINGS PARK
Medical Centre CITY OF NEDLANDS
CITY OF PERTH
TOWN OF CLAREMONT University
Nedlands
LEGEND
Zone Substations
LGA
6.6kV
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 85 7. SUPPLY ISSUES
Metro North 11 kV planning cluster The distribution voltage in this cluster front of zone substations. There are The Metro North 11 kV cluster supplies is 11 kV, with a mixture of overhead also sections of lower rated cables and predominantly residential load with and underground distribution conductors throughout the network. small pockets of commercial networks. These limitations can reduce the amount of load transferrable between development and a concentrated Numerous interconnections exist substations during outages and industrial area at Osborne Park. The between the contiguous 11 kV maintenance. residential areas in some parts of the substations within this cluster. cluster are at a relatively mature stage However, there are some capacity Committed projects for reinforcement of development (particularly the constraints on the distribution network of distribution networks from Manning eastern areas), whereas areas closer to that limit the ability of these substation will provide additional the Perth city centre and within interconnections to transfer significant capacity in the area. proximity to the coastline are yet to portions of load between substations. mature with in-fill development. These Options to improve feeder congestion developments are showing an increase The capability of the distribution are being analysed for Osborne Park in residential density particularly in network is limited by thermal and Yokine substations, offering the areas close to employment and constraints on distribution exit cables. potential to present feeder transportation nodes. This is caused by cable congestion reinforcements that improve the due to restrictive cable exit routes in capacity of their associated networks.
TABLE 34: METRO NORTH 11 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Cottesloe City of Stirling Town of Cottesloe Perth Metropolitan Manning Street City of Vincent Shire of Peppermint Grove Morley Town of Cambridge Town of Mosman Park Osborne Park City of Bayswater City of Fremantle Wembley Downs City of Nedlands Yokine Town of Claremont
TABLE 35: METRO NORTH 11 KV - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Manning St: Network Reduce feeder overloading; improve Karrinyup, Doubleview, Reconfiguration and install new distribution transfer capacity; reduce the Summer 2015/16 Scarborough, Innaloo feeders risk of long duration outages in the area.
86 FIGURE 28: METRO NORTH 11 KV PLANNING SECTOR
CITY OF STIRLING
CITY OF BAYSWATER
Manning Street
Osborne Park Yokine Morley
Wembley Downs
CITY OF VINCENT
TOWN OF CAMBRIDGE
CITY OF NEDLANDS
TOWN OF CLAREMONT
TOWN OF LEGEND COTTESLOE Zone Substations SHIRE OF Cottesloe LGA PEPPERMINT GROVE N 11kV
TOWN OF MOSMAN PARK
CITY OF FREMANTLE
METRO NORTH PLANNING SECTOR
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 87 7. SUPPLY ISSUES
Metro North 22 kV (A) planning are occurring in these areas and there adjacent to the Morley distribution cluster is a strong expectation that network that operates at 11 kV (see The Metro North 22 kV (A) planning development will continue well into the Section 7.1.4). next couple of years. cluster covers a large portion of the Options to reduce feeder peak loading Metro North planning sector and has a This 22 kV cluster is separated from are being analysed for Beechboro and diverse array of loads. the Metro North 22 kV (B) planning Hadfields substations, potentially The eastern portion of the catchment cluster because of a reduction in the requiring reinforcements that improve captures the beginnings of the Swan number of useful interconnections to the capacity of their associated Valley, with high intensity agricultural transfer load between clusters. networks. Whiteman Park is also a natural barrier, loads. Significant industrial loads are On the overhead network, the thermal with relatively low load densities located at both Malaga and constraints are more prevalent due to reducing the need to create Bassendean, supplied from the Malaga lower rated sections of feeder interconnections between the two and Hadfields substations in the backbone. Options are being planning clusters. southern portion of the cluster investigated to balance the overall cost respectively. The Hadfields network to the south of with the benefits realised. the Metro North 22 kV (A) planning Remaining areas in the south-east and These include upgrading sections of cluster is partially bound to the east by north-east of the Metro North 22 kV (A) the overhead network with larger the Swan River, with a few limited planning cluster are predominantly conductors and undergrounding interconnections existing to the Metro residential loads. The north-east sections of the network. portion (the Ellenbrook area) and the East planning sector (see Section south-east portion (the Caversham 7.1.4). Additional interconnection There are currently no committed area) are currently experiencing rapid limitations exist on the west side of the capacity expansion projects in this residential growth. New developments Hadfields network, as this network is planning cluster.
TABLE 36: METRO NORTH 22 KV (A) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Beechboro City of Bayswater Perth Metropolitan Hadfields Town of Bassendean Henley Brook City of Swan Malaga City of Stirling City of Wanneroo
88 FIGURE 29: METRO NORTH 22 KV (A) PLANNING CLUSTER
N
METRO NORTH PLANNING SECTOR
Henley Brook
CITY OF WANNEROO
CITY OF SWAN
Malaga
Beechboro CITY OF BAYSWATER LEGEND
Zone Substations
LGA CITY OF STIRLING TOWN OF BASSENDEAN 22kV (A)
Hadfields
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 89 7. SUPPLY ISSUES
Metro North 22 kV (B) planning A project has been created to rectify slowly taking shape as a significant cluster the under-fault-rated conductors on future industrial hub in this cluster. Yanchep feeders to mitigate safety risk The Metro North 22 kV (B) planning Like the Metro North 22 kV (A) to the public. cluster covers most of the Metro North planning cluster, this cluster planning sector and supplies a diverse The remaining substations in this experiences thermal constraints in the range of loads. The outer fringes of this planning cluster supply a mixture of distribution network. The limitations cluster mainly comprise semi-rural residential, commercial or large exist on the feeder’s backbones, rather loads with a predominance of long industrial loads. Capacities of these than the less congested feeder exit overhead feeders that are typically networks are established by the cables. However, exit cable congestion voltage constrained. The zone thermal ratings of the power is evident at the older substations in substations that supply these areas transformer and feeders. this catchment, namely North Beach 48 are Muchea and Regans 22 kV. and Mullaloo. Yanchep substation has a single feeder The coastal areas and southern running north also supplying a similar portion of the planning cluster are The thermal constraints arise from lower type of load. mainly residential, with pockets of rated feeder backbone conductors that commercial development. The majority are a mix of overhead and underground These semi-rural feeders from of the residential developments closer cable. The mitigation of the feeder Yanchep, Muchea and Regans 22 kV to Perth City are reasonably mature. constraint depends on the forecast load substations are characterised by their New residential activity is forecast to growth. Upgrading the weak backbone extended length and the inclusion of increase demand on the coast north of is costly and generally achieves voltage regulators installed along the Quinns Rocks, with new subdivisions minimal capacity improvement, while feeder length to assist with maintaining developing between Yanchep and the installation of a new feeder is more acceptable voltage levels at the Two Rocks. effective in this regard. customer end. Pole-top capacitor banks are also common on these Significant industrial loads are located There are currently no committed types of feeder networks to provide at the Wangara/Gnangara Industrial capacity expansion projects in this voltage support. Area. The Neerabup industrial area is planning cluster.
TABLE 37: METRO NORTH 22 KV (B) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Arkana City of Stirling Perth Metropolitan Balcatta City of Stirling Whealtbelt Clarkson City of Joondalup Joondalup City of Wanneroo Landsdale City of Swan Muchea Shire of Chittering Mullaloo Shire of Toodyay North Beach Shire of Gingin Padbury Shire of Victoria Plains Regans 22 kV Wanneroo Yanchep Wangara
48 Regans substation also has a 33 kV distribution network, which is discussed in Section 7.1.4.
90 FIGURE 30: METRO NORTH 22 K (B) PLANNING CLUSTER
Regans
SHIRE OF VICTORIA PLAINS
SHIRE OF GINGIN
SHIRE OF CHITTERING
SHIRE OF TOODYAY
Muchea CITY OF WANNEROO
Yanchep
Clarkson CITY OF SWAN
Wanneroo N Joondalup Mullaloo LEGEND Wangara Padbury Future Zone Substations Landsdale CITY OF Zone Substations JOONDALUP Balcatta LGA North Beach Arkana 22kV (B) CITY OF STIRLING
METRO NORTH PLANNING SECTOR
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 91 7. SUPPLY ISSUES
7.1.3 METRO SOUTH PLANNING FIGURE 31: METRO SOUTH PLANNING SECTOR - SECTOR VOLTAGE PLANNING CLUSTERS The Metro South planning sector is bounded by the Swan River to the north, the Metro East planning sector to the east and the Country South planning region in the south.
There are a number of different distribution voltages in the Metro South planning sector, legacies of the Bentley network development over a number of decades. Fremantle
The Metro South planning sector is Jandakot Roleystone extensive, covering areas with diverse characteristics. For planning purposes, it is divided into the following voltage planning clusters, based on their ability to transfer load between zone substations: Rockingham • Metro South 11 kV (A)
• Metro South 11 kV (B) Jarrahdale
Port Kennedy • Metro South 22 kV (A)
• Metro South 22 kV (B)
• Metro South 22 kV (C).
The 11 kV network is divided into two LEGEND clusters, as there are no Mandurah Major Towns interconnections between their 6.6kV N substations. 11kV (A)
11kV (B)
The 22 kV network is also divided into 22kV (A) three clusters, as there is a limitation to 22kV (B) the number of interconnections 22kV (C) between their zone substations. The primary reason for this is the natural boundaries created by the Canning METRO PLANNING REGION River and areas of undeveloped land.
92 Metro South 11 kV (A) planning TABLE 38: METRO SOUTH 11 KV (A) - ZONE SUBSTATION, cluster LGA AND REGION The area is primarily residential, with Zone substations Local government authorities DRD regions older dwellings away from the Swan and Canning Rivers. High density Clarence Street City of South Perth Perth Metropolitan residential developments are occurring Collier Town of Victoria Park at transportation corridors and areas City of Canning with river views. There are some commercial loads in the area, with the majority in the South Perth precinct. FIGURE 32: METRO SOUTH 11 KV (A) PLANNING CLUSTER There are no projected substation capacity shortfalls in this cluster over the five year outlook.
The distribution voltage in this cluster is 11 kV, with a mixture of overhead and underground distribution networks. Restrictions on the distribution feeder network are caused by thermal constraints on the feeder exit cables and feeder backbones. Clarence Street
The longer term strategy for this cluster is currently being refreshed. One option may involve a staged upgrade TOWN OF VICTORIA PARK CITY OF SOUTH PERTH of the 11 kV feeder network to 22 kV. The benefit of this conversion will be improved interconnections that will aid reliability and the increase in the Collier overall capacity of the network. The upgrade will most likely involve converting the networks to 22 kV and transferring part of the load to Bentley substation, which is contiguous to Collier substation. CITY OF CANNING There are currently no committed capacity expansion projects in this LEGEND Zone Substations planning cluster. LGA N 11kV (A)
METRO SOUTH PLANNING SECTOR
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 93 7. SUPPLY ISSUES
Metro South 11 kV (B) planning The cluster contains a mixture of residential dwellings are being cluster residential loads on its outer fringes, developed where river and ocean The combined capacity of the zone industrial loads on North Quay and views are available. Victoria Quay and commercial activities substations in this cluster is adequate There are currently no committed around Fremantle City. to support the forecast growth beyond capacity expansion projects in this the next five years. Load growth is moderate in this planning cluster. The distribution voltage in this cluster cluster, as loads have matured and is 11 kV with a large proportion of the new developments are rare in the network underground. Fremantle city area. Higher density
TABLE 39: METRO SOUTH 11 KV (B) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Edmund Street City of Fremantle Perth Metropolitan North Fremantle Town of East Fremantle
FIGURE 33: METRO SOUTH 11 KV (B) PLANNING CLUSTER
TOWN OF MOSMAN PARK
CITY OF FREMANTLE
North Fremantle
TOWN OF EAST FREMANTLE
CITY OF FREMANTLE
Edmund Street
LEGEND
Zone Substations N
LGA
11kV (B)
METRO SOUTH PLANNING SECTOR
94 Metro South 22 kV (A) planning residential areas with new high density The recent installation of new feeder cluster residential developments south of from Southern River substation and The Metro South 22 kV (A) planning Fremantle City. new feeder at Bibra Lake substation has provided additional capacity on cluster covers a large portion of the In order to balance the transformer and their respective networks. Metro South planning sector and has a feeder load at Riverton area to allow diverse array of loads. more capacity, Western Power has A number of transformers at Australian The south-east outer fringes of this committed to a project to reinforce the Paper Mills and O’Connor substations cluster mainly comprise semi-rural existing distribution feeders. This will are proposed to be replaced by developments and consist also improve the distribution transfer 2019/20 due to degraded condition. predominantly of agricultural and capacity. Similarly, a number of assets at North Fremantle substation and its supply commercial loads near the town sites Significant industrial load exists in transmission cables are in degraded of Armadale and Byford. Pockets of Henderson and Canning Vale industrial condition. To address these asset these areas close to transportation areas. There is potential for significant condition issues, Western Power is corridors are being developed into expansion to the Henderson Industrial proposing to resupply the substation residential housing. The load density at Park and the Jandakot Airport area. from adjacent substations and Armadale and Byford is growing as Other large industrial parks in the decommission the cables by 2019/20. higher density residential is being cluster include industrial areas in developed in parallel with supporting O’Connor, Myaree, Maddington,49 There are currently no committed commercial activities. Forrestdale, Bibra Lake, Jandakot and capacity expansion projects in this Areas adjacent to the Swan and Cockburn Central. planning cluster. Canning Rivers are older, developed
TABLE 40: METRO SOUTH 22 KV (A) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Amherst City of Fremantle Perth Metropolitan Australian Paper Mills Town of East Fremantle Bibra Lake City of Melville Byford City of Canning Canning Vale City of Gosnells Cockburn Cement City of Armadale Gosnells City of Cockburn Maddington City of Kwinana Murdoch Shire of Serpentine-Jarrahdale Myaree Shire of Murray O’Connor Shire of Kalamunda Riverton City of Rockingham South Fremantle 22 kV Southern River Willetton
49 Half of the Maddington industrial area is supplied by the Metro South 22 kV (B) planning cluster.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 95 7. SUPPLY ISSUES
FIGURE 34: METRO SOUTH 22 KV (A) PLANNING CLUSTER
N
METRO SOUTH PLANNING SECTOR
TOWN OF EAST Myaree SHIRE OF KALAMUNDA FREMANTLE CITY OF Maddington CITY OF MELVILLERiverton CANNING Amherst Canning Vale O’Connor CITY OF GOSNELLS CITY OF FREMANTLE Murdoch Willeton Gosnells
South Fremantle Australian Paper Mills
Bibra Lake Southern River
CITY OF COCKBURN
Cockburn Cement CITY OF ARMADALE
Byford
TOWN OF KWINANA
CITY OF ROCKINGHAM SHIRE OF SERPENTINE-JARRAHDALE
LEGEND
Future Zone Substations
Zone Substations
LGA
22kV (A) SHIRE OF MURRAY
96 Metro South 22 kV (B) planning there are lower-rated conductors at the New developments tend to be higher cluster feeder ends where these density and within close proximity to The cluster is bordered by the Swan interconnections are located, reducing transportation corridors. The new River in the north, the Metro South 11 kV the ability to transfer significant residential developments are generally (A) planning cluster to the west, the portions of load. The Canning River infill developments. New subdivisions Perth International Airport and Metro also creates a natural boundary are rare in this cluster, as there is no East planning sector to the east and the between the two clusters, restricting large, vacant or semi-rural land, to Canning River and Metro South 22 kV the creation of additional develop. interconnections. (A) planning cluster to the south. Plans are currently being developed to There are some interconnections with The loads in this cluster are dominated resolve the feeder thermal constraints the Metro East planning sector. by the industrial loads at both by either replacing the lower-rated However, these cannot transfer Welshpool and Kewdale Industrial assets or by installing new feeders to significant portions of load, as there Areas, with newer industrial areas offload the heavily loaded feeders. This are spans of lower-rated conductor at being developed at Belmont and augmentation is likely to be performed the end of the feeder where the Maddington. in the near future to reinforce the feeder network at Tate Street and interconnections are located. The remaining load in this cluster is Kewdale substations. Similarly, there are some mostly residential, with pockets of interconnections with the Metro South commercial activity centres. The There are currently no committed 22 kV (A) planning cluster through the residential loads are mature, capacity expansion projects in this Maddington Industrial Area. However, particularly closer to the Perth CBD. planning cluster.
TABLE 41: METRO SOUTH 22 KV (B) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Belmont Town of Victoria Park Perth Metropolitan Bentley City of South Perth Kewdale City of Belmont Rivervale City of Canning Tate Street Shire of Kalamunda Welshpool City of Gosnells City of Bayswater City of Swan
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 97 7. SUPPLY ISSUES
FIGURE 35: METRO SOUTH 22 KV (B) PLANNING CLUSTER
N
CITY OF BAYSWATER METRO SOUTH PLANNING SECTOR
CITY OF SWAN
Belmont
Rivervale CITY OF BELMONT LEGEND Zone Substations
Kewdale LGA
22kV (B)
TOWN OF VICTORIA PARK
Welshpool Tate Street
SHIRE OF KALAMUNDA
CITY OF CANNING Bentley
CITY OF SOUTH PERTH
CITY OF GOSNELLS
98 Metro South 22 kV (C) planning and underground distribution As discussed in Section 6, substation cluster networks, with the most significant capacity shortfalls are anticipated at This cluster covers the coastal strip issue requiring management being Mandurah and Meadow Springs over that extends from north of thermal constraints. This is caused by the five year outlook. To relieve these Rockingham to Naval Base, consisting either feeder exit cable congestion or limitations, Western Power is of heavy industrial loads and lower rated feeder backbone sections. proposing to install additional supporting light industrial and The feeder thermal constraints are transformers at Meadow Springs and commercial activities. The Kwinana expected to be resolved by either Mandurah substations by winter 2017 Industrial Area has been earmarked for upgrading existing assets or installing and summer 2019/20 respectively. new feeders. significant expansion and Given the lead times associated with redevelopment. The cluster consists Western Power has recently installed a some projects, Western Power is primarily of high growth residential third transformer at Mason Road investigating other opportunities to loads from Rockingham in the north to substation allowing for future load transfer load between substations to Dawesville in the south. There are growth, new customer connections best manage the reliability of supply higher densities of residential dwellings and the decommissioning of British until the new reinforcements enter are found around the Rockingham and Petroleum substation. British service. Furthermore, non-network Mandurah city centres, which also Petroleum substation has been solutions such as DM will also be contain commercial developments. identified to be in degraded condition investigated to identify opportunities to The distribution voltage in this cluster and it is anticipated that the substation defer capital investment, where it is is 22 kV, with a mixture of overhead load will be transferred to Mason Road economic to do so. substation by summer 2015/16.
TABLE 42: METRO SOUTH 22 KV (C) - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions British Petroleum City of Cockburn Peel Mandurah City of Kwinana Perth Metropolitan Mason Road City of Mandurah Meadow Springs Shire of Murray Medina City of Rockingham Pinjarra Shire of Serpentine-Jarrahdale Rockingham Waikiki
TABLE 43: METRO SOUTH 22 KV (C) - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Transfer four feeders from existing BP substation to MSR and MED substations British Petroleum Kwinana Summer 2015/16 due to the decommissioning of BP substation.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 99 7. SUPPLY ISSUES
FIGURE 36: METRO SOUTH 22 KV (C) PLANNING CLUSTER
CITY OF COCKBURN
TOWN OF KWINANA British Petroleum Medina Mason Road
Rockingham
Waikiki SHIRE OF SERPENTINE-JARRAHDALE
CITY OF ROCKINGHAM
LEGEND
Zone Substations
LGA Meadow Springs SHIRE OF MURRAY 22kV (C)
CITY OF MANDURAH
Mandurah
Pinjarra
N
METRO SOUTH PLANNING SECTOR
100 7.1.4 METRO EAST PLANNING East planning region; however no Corporation’s facilities, with Mundaring SECTOR feeders interconnect the two planning Weir the cluster’s only zone substation. regions. The Metro East planning sector is To accommodate a Water Corporation bordered by the Swan River in the This sector is divided into the following expansion at Mundaring Weir, Western north-west and extends north towards voltage planning clusters, based on Power installed a second 132/22 kV the southern end of the Avon Valley their ability to transfer load between transformer at Sawyers Valley 132 kV National Park, east towards zone substations: substation in summer 2013/14. This Boononging, south towards Canning has offloaded Mundaring Weir • Metro East 6.6 kV Dam and south-west towards Wattle substation almost entirely. This will also Grove and west towards the Perth • Metro East 22 kV. allow for the potential 2018/19 International Airport. decommissioning of the Mundaring Metro East 6.6 kV planning cluster The Metro East planning sector has Weir substation, which has assets that been separated from the Metro North This cluster mainly supplies facilities for are in degraded condition and that have and Metro South planning sectors, as the Water Corporation’s operations at reached the end of their service lives. Mundaring Weir and is not it has different characteristics and There are currently no committed interconnected with the surrounding requirements for future growth. This capacity expansion projects in this area. The load growth is constant and catchment covers the eastern hills planning cluster. areas of Perth and adjoins the Country is dominated by the Water
TABLE 44: METRO EAST 6.6 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Mundaring Weir Shire of Mundaring Perth Metropolitan
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 101 7. SUPPLY ISSUES
FIGURE 37: METRO EAST PLANNING SECTOR
N
CITY OF SWAN METRO PLANNING SECTOR
SHIRE OF MUNDARING Midland Junction
Hazelmere Sawyers Valley
Darlington
Mundaring Weir CITY OF BELMONT Forrestfield
Kalamunda
SHIRE OF KALAMUNDA
SHIRE OF YORK
CITY OF GOSNELLS LEGEND
Zone Substations
LGA
6.6kV SHIRE OF BEVERLEY
CITY OF ARMADALE 22kV
SHIRE OF WANDERING
102 Metro East 22 kV planning cluster covering the outskirts of the cluster, improved designs to feeder routes Although the Metro East planning particularly through the eastern portion from these substations. of the Darling Escarpment. The cluster overlaps the Shires of York, Western Power completed the remaining land is undeveloped Beverley and Wandering, the feeder installation of a fourth transformer at parklands, reserves or state forest. network does not yet extend this far. Midland Junction in 2014/15, The Metro East 22 kV planning cluster The distribution voltage in this cluster increasing capacity to the area. is 22 kV with a mixture of overhead supplies a wide range of loads. Heavy In terms of voltage constraint, feeders and underground distribution network. industrial loads exist in the east near from Sawyers Valley and Darlington the Perth International Airport. There Main supply issues in this area are the substations have long distribution are a number of residential and thermal and voltage constraints of overhead networks. Capacitor banks commercial precincts at Midland, distribution feeder assets. Feeder exit and voltage regulators are often Forrestfield and Kalamunda. This cable de-rating is caused by feeder required to provide voltage support. planning cluster consists of a high cable congestion at Darlington, Western Power has committed to the intensity agricultural load centred Kalamunda and Midland Junction reinforcement of the under fault rated around Middle Swan and with low substations. This issue does not exist conductor from Darlington, Hazelmere density residential development and at the newly established Forrestfield and Kalamunda distribution network to supporting commercial activities and Hazelmere substations due to reduce safety risk.
TABLE 45: METRO EAST 22 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Darlington City of Armadale Perth Metropolitan Forrestfield City of Belmont Hazelmere Shire of Beverley Kalamunda City of Gosnells Midland Junction Shire of Kalamunda Sawyers Valley Shire of Mundaring Munday City of Swan Shire of Wandering Shire of York
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 103 7. SUPPLY ISSUES
7.2 COUNTRY DISTRIBUTION The Country Planning Region consists subject to lower reliability service PLANNING of a mixture of rural and urban standards due to their large exposure The Country Planning Region of the networks. Overhead distribution to environmental conditions. networks dominate, with underground Western Power Network extends north Underground networks and overhead generally only found in urban town to Kalbarri, south to Albany and east to networks within the urban areas (of the centres. However, all new residential Kalgoorlie-Boulder. It is divided into country region) frequently exhibit and commercial subdivisions must four smaller planning regions: thermal constraints that may impinge incorporate underground distribution on load growth and new • Country North networks, so the proportion of developments. This is often underground networks is growing. • Country South compounded by restrictions on feeder • Country East The overhead rural networks typically exit cable ratings caused by feeder consist of long feeders, often exhibiting congestion around some substations. • Country Goldfields voltage constraints. Rural feeders are
FIGURE 38: COUNTRY PLANNING REGION
LEGEND
Country Towns
Country North
Country South
Country East
Country Goldfields
104 7.2.1 COUNTRY NORTH REGION The Northern Wheat belt area is towns of Cervantes, Jurien Bay, The Country North region extends characterised by long, lightly loaded Eneabba and Dongara are supplied northwards from the outer Perth overhead networks. The loads from these networks and are more metropolitan region to Kalbarri. The supplied are generally small and heavily loaded than the remainder of planning region also extends into the dispersed for broad acre agricultural the area. There is also some larger northern areas of the Wheatbelt, purposes, with the exception being the industry in this area, which includes around 150 km east of the coast. supply to the towns of Moora and mining loads around Eneabba. Three Springs, which are shorter and There are currently eight substations The Geraldton-Greenough area has more heavily loaded rural networks. feeding the Country North region. moderate load density. The majority of The Kalbarri town network is unique in the networks are overhead, with the In general, the networks supplying the this load area, as it is connected to the exception being the newer 11 kV Country North region are radial, Western Power Network and supplied networks in Geraldton. The networks overhead power lines with the majority via a step down transformer at 6.6 kV. of the networks supplied at 33 kV. This supply residential and industry loads region is divided into three distinct The coastal area is also characterised servicing the horticulture, fishing, port, areas: Northern Wheatbelt, Coastal by long, lightly loaded overhead mining and tourism activities in the and Geraldton-Greenough. networks. A large proportion of users area. These loads generally peak in are relatively small and dispersed for summer, driven by water pumping, air broad acre agricultural purposes. The conditioning or cool storage.
FIGURE 39: COUNTRY NORTH PLANNING REGION
Note : Kalbarri townsite is Kalbarri supplied at 6.6kV
NORTHAMPTON
CHAPMAN YALGOO VALLEY
CITY OF GERALDTON MULLEWA Chapman Durlacher Geraldton Rangeway
GREENOUGH
MORAWA MINGENEW IRWIN
Three Springs SANDSTONE MENZIES THREE PERENJORI SPRINGS Chapman CARNAMAH
Geraldton YILGARN Durlacher Eneabba COOROW MOUNT MARSHALL Rangeway DALWALLINU
MOORA DANDARAGAN
GERALDTON Moora WONGAN-BALLIDU KOORDA
LEGEND Regans VICTORIA PLAINS DOWERIN Zone Substations GOOMALLING GINGIN LGA CHITTERING
6.6kV
11kV
33kV
N
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 105
WESTERN POWER NETWORK Country North 33 kV planning substation, a third transformer and remotely controlled switches to allow cluster reconfiguration of the congested interconnection. However, large The 33 kV network in Country North distribution exits from the site are portions of customers are fed from supplies a range of mining and proposed. single phase rural distribution lines, which were specifically designed to industrial loads, as well as many rural One of the transformers at Moora supply farming loads. Material new centres. The network is predominantly substation failed catastrophically in block loads such as grain handling overhead. Development has slowed in February 2015 and a strategic spare facilities and processing plants will the past few years, seemingly transformer was immediately deployed require significant reinforcement coinciding with the downturn in the to replace the failed transformer. The works, such as the extension of three global economy. immediate transformer deployment phase power lines. Major developments expected to had deficiencies in the transformer’s influence the cluster include: bund and protection. These The 33 kV network is constrained deficiencies are expected to be typically by voltage capacity rather 50 • completion of Indian Ocean Drive addressed by 2015/16. than the thermal capacity of existing power lines. This is due to the relatively • WA State Government “Super-town” With a number of customers agreeing large distances required to transfer scheme to connect on a curtailable power from zone substations to supply arrangement as well as recent • future development of the customers. Generally, the 33 kV reductions in load forecasts the Oakajee Port network in Country North has requirement for the new substation has adequate capacity to supply the • Mid West Energy Project been deferred beyond a ten year forecast natural load growth. • Development of new magnetite horizon. It is now anticipated that the mines and expansion of the third transformer at Rangeway will be Opportunities for non-network Geraldton Port. sufficient for the medium term. solutions have been considered as Recognising the potential for new large alternative options, but show limited Load transfer between zone industrial block loads to connect in the potential for application at this stage. substations in Country North is limited area with relatively short lead times The viability of non-network solutions by voltage regulation constraints and Western Power’s network development is largely dependent on the rate of few interconnections between the long plan for the area allows for significant underlying growth of the feeder peak radial distribution power lines. flexibility. Depending on the size of load demand, types of loads (such as To address ageing assets at Durlacher some spare capacity will be available industrial and commercial) and risk to substation, planning is under way for a at both Rangeway substation and network security. For a non-network staged load transfer from Durlacher Geraldton terminal and a future new alternative to be the preferred solution, substation (supplied by the terminal) to substation can also be established on it must also deliver the required Rangeway substation over a number of the Durlacher site, following outcome at a lower cost to the network years to 2017/18. This allows for the decommissioning of the existing alternative. substation by summer 2018/19. decommissioning of most assets There are currently no committed within the Durlacher substation Where practical to do so, Western capacity expansion projects in this perimeter. In order to accommodate Power has extended three phase planning cluster. the additional load at Rangeway power lines and installed automated,
50 This major highway will reduce driving time from Perth to Geraldton by 40 minutes and is expected to be a significant driver for the growth of the central coast area.
106 TABLE 46: COUNTRY NORTH 33 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions WDC region51 Eneabba Shire of Carnamah Mid West Geraldton Shire of Chapman Valley Wheatbelt Kalbarri Shire of Chittering Central Midlands Moora Shire of Coorow Regans Shire of Dalwallinu Central Midlands Three Springs Shire of Dandaragan Central Coast Shire of Dowerin Avon Shire of Gingin Central Coast Shire of Goomalling Avon Shire of Greenough Shire of Irwin Shire of Koorda Avon Shire of Mingenew Shire of Moora Central Midlands Shire of Morawa Shire of Mullewa Shire of Northampton Shire of Perenjori Shire of Three Springs Shire of Victoria Plains Central Midlands
Country North 11 kV planning The 11 kV network in Geraldton - There is limited distribution transfer cluster Greenough has seen moderate capability between the 11 kV zone Load density in the Geraldton - growth with several residential and substations. This is due mainly to Greenough area is moderate due to commercial applications over the thermal capacity constraints and residential and commercial loads in the last couple of years. limited physical interconnection points between feeders. Transfer capability is city of Geraldton. The distribution Major developments that may affect mainly reserved for fault conditions to networks supplying the City of the cluster include: Geraldton consist of three phase 11 kV restore power and minimise feeder feeders. The primary constraint on the • Geraldton Port Authority outage times. development 11 kV network is thermal capacity. There are currently no committed • Asia Iron ore handling facility near capacity expansion projects in this the port. planning cluster.
TABLE 47: COUNTRY NORTH 11 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Chapman City of Geraldton Mid West Durlacher Shire of Greenough Rangeway
51 Wheatbelt Development Commission region (where applicable).
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 107 7. SUPPLY ISSUES
7.2.2 COUNTRY SOUTH REGION 2. Great Southern Study Area, which In general, the networks supplying the generally supplies broad acre, low Country South region are radial, rural density networks and is overhead power lines. Two defined geographically located to the east of study areas are defined within the the South-West study area. Country South region: All 19 substation feeder exits in this 1. South-West Study Area, supplying region are 22 kV. However, as shown large urban centres of the coastal in the map of the area, voltage in the region from Pinjarra in the north to eastern section of the Great Southern Augusta in the south, as well as study area is stepped up to 33 kV to moderate density loads driven by increase the voltage capacity of the horticulture, viticulture and tourism, feeders supplying loads over such with some larger industry and long distances. mining loads.
TABLE 48: COUNTRY SOUTH 22 KV SOUTH-WEST STUDY AREA - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Beenup Shire of Augusta-Margaret River South West Bunbury Harbour Shire of Boyup Brook Busselton Shire of Bridgetown-Greenbushes Bridgetown City of Bunbury Capel Shire of Busselton Collie Shire of Capel Coolup Shire of Collie Margaret River Shire of Dardanup Marriott Road Shire of Donnybrook-Balingup Manjimup Shire of Harvey Picton Shire of Manjimup Wagerup Shire of Nannup Shire of Murray Shire of Waroona
108 TABLE 49: COUNTRY SOUTH 22 KV GREAT SOUTHERN STUDY AREA - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Albany City of Albany Great Southern Boddington Shire of Beverly Katanning Shire of Brookton Kojonup Shire of Broomehill Mt Barker Shire of Boddington Narrogin Shire of Cranbrook Wagin Shire of Cuballing Shire of Denmark Shire of Dumbleyung Shire of Gnowangerup Shire of Katanning Shire of Kent Shire of Kojonup Shire of Jerramungup Shire of Manjimup (Walpole) Shire of Narrogin Town of Narrogin Shire of Pingelly Shire of Plantagenet Shire of Ravensthorpe Shire of Tambellup Shire of Wagin Shire of Wandering Shire of West Arthur Shire of Wickepin Shire of Williams Shire of Woodanilling
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 109 7. SUPPLY ISSUES
FIGURE 40: COUNTRY SOUTH PLANNING REGION
N
ARMADALE BEVERLEY WESTERN POWER NETWORK KWINANA
ROCKINGHAM SERPENTINE JARRAHDALE BROOKTON CORRIGIN KONDININ
PINGELLY MANDURAH MURRAY WANDERING KULIN Boddington CUBALLING Coolup BODDINGTON WAROONA Wagerup WICKEPIN Narrogin NARROGIN HARVEY LAKE GRACE ESPERANCE WILLIAMS
Marriott Road WAGIN COLLIE DUMBLEYUNG Bunbury Harbour Wagin Collie Picton DARDANUP WEST ARTHUR CAPEL Capel KENT WOODANILLING KATANNING RAVENSTHORPE DONNYBROOK- Busselton BALINGUP Katanning BUSSELTON Kojonup BOYUP BROOK BROOMEHILL Bridgetown Margaret River KOJONUP GNOWANGERUP BRIDGETOWN- AUGUSTA- GREENBUSHES JERRAMUNGUP MARGARET RIVER TAMBELLUP NANNUP Beenup
Manjimup CRANBROOK
MANJIMUP PLANTAGENET Mount Barker
ALBANY LEGEND
DENMARK Zone Substations Albany LGA
22kV
33kV
110 South-West study area neighbouring sites is more economic. Strong demand growth due to urban developments in and around Bunbury The South-West study area has Given the lead times associated with and Busselton are driving moderate load density for rural feeders some projects, opportunities to reinforcement requirements in both of and reasonably strong but heavily transfer load between substations are these areas. Moderate demand growth loaded ageing rural feeders. The being investigated to best manage the continues along the coastal edge of majority of the networks are of reliability of supply until the new the study area with some major future overhead construction. The networks reinforcements are in service, including augmentation required. The rest of the supplies moderately sized towns, non-network solutions. There is study area has low demand growth some industry, horticulture, viticulture minimal transfer capability between the levels and reinforcement activity is and tourism loads and the loads following pairs of substations due to generally driven by customer bulk loads. associated with some small mining distance, high network peak loading activities. The loads generally peak in levels and strength of the distribution In the medium term, capacity summer, driven by water pumping, air networks in this study area: augmentation will continue to be conditioning or cool storage. required for the higher growth areas • Wagerup and Marriott Road around Bunbury and Busselton. As discussed in Section 6.8.2, substations capacity shortfalls arise at a number of Forecast growth levels in the Bunbury substations in the area over the five • Capel and Picton substations region and in particular, the Eaton and Dalyellup areas, are likely to require a year outlook, including Capel, Bunbury • Capel and Busselton substations Harbour and Busselton substations. In new feeder installations in the next few order to relieve capacity limitations at • Busselton and Margaret River years. With recent growth in Busselton, Busselton substation, a new substations. the distribution capacity is at or near limits. A new Busseton East feeder is transformer is proposed by winter Within this study area, interconnections presently being investigated to resolve 2017, which also facilitates a reduction exist between the substations that this capacity issue. in peak loading of existing 66/22 kV supply Bunbury and its surrounds. transformers in degraded condition. However, thermal capacity constraints Over the next five years, a number of With both transformers at Capel on the distribution network limit the heavily loaded single phase spurs will substation also in degraded condition, ability of the interconnections to require reinforcement to ensure power replacement of this plant with higher transfer significant portions of load quality and local capacity is capacity transformers is planned by between Bunbury Harbor, Picton and maintained. 2018/19 to address both capacity and Marriott Road substations. condition limitations. A new fourth Great Southern study area Voltage regulation is the major issue for transformer at Bunbury Harbour The majority of the distribution network provision of capacity in this study area, substation is proposed by 2019/20 to in this study area is characterised by due to the distances of the load from address capacity limitations. long, lightly loaded overhead lines. The the dispersed substations. Two degraded condition transformers associated load profiles are generally at Margaret River substation are Load imbalance issues also affect small, dispersed and for broad acre intended to be replaced with a single power quality, reliability and capacity agricultural purposes. The exceptions transformer of higher capacity by within this study area. Over the next are the networks supplying the larger 2016/17. Similarly, a transformer at three to four years, significant work will towns of Albany, Katanning, Narrogin Picton substation is proposed to be be required to rectify heavily loaded and Kojonup, as well as the coastal replaced by 2018/19 due to degraded single phase spurs to address strip from Albany to Walpole, which is condition. imbalance issues. The preferred shorter and more heavily loaded. solution involves reconfiguring the Western Power has recently replaced Numerous assets at Collie and Coolup spurs and installing isolation the three existing transformers at substations as well as their connecting transformers, which assist in balancing Narrogin substation with a single transmission line circuits have been the single phase loads. This reduces higher capacity unit due to degraded identified to be in degraded condition. the likelihood of power supply asset condition. This has also created Investigations are underway to interruptions due to protection relays additional capacity to the area. understand whether asset being triggered by high levels of replacement or decommissioning the imbalance. A number of transformers at Wagin sites and a resupply of load from and Katanning substations are planned
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 111 7. SUPPLY ISSUES
to be replaced by 2018/19 and The long radial distribution networks in possible this will be deferred through 2019/20, respectively, due to asset this study area were designed to cater the use of reactive power support, condition. Whilst there are no capacity for typical broad acre rural load types. along with demand management and constraints at these sites, the This has become apparent in the the more traditional application of transformer replacements ensure changing characteristic of load in areas voltage regulators. capacity is available for the foreseeable such as Boddington, where increased Opportunities exist for non-network future. activity due to local mining has solutions such as demand occurred, as well as Denmark and The majority of load growth in this management and energy efficiency Walpole, where more load intensive study area has been centred around programs for Denmark and Walpole, viticulture and tourism-based the City of Albany and along the south as well as the introduction of fast- industries have affected the distribution coast between Albany and Walpole. acting reactive power devices (such as networks. Steady load growth is expected to Statcoms). These non-network continue and therefore it is envisaged Over the next ten years, further solutions are required to mitigate that incremental reinforcement to the reinforcement of the distribution capacity constraints on the distribution network will be required. With minimal network that supplies Denmark to network in the short and medium load growth elsewhere, any associated Walpole will be required in order to terms. augmentation to the distribution meet forecast demand. This will network has been driven by material ultimately include an additional block loads. distribution feeder, however it is
TABLE 50: COUNTRY SOUTH 22 KV - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Capacity increase for the Dunsborough area. Installation of feeder to supply the Busselton: Feeder reinforcement Commonage Rd area and offload Dunsborough Summer 2015/16 and reconfiguration Margaret River and Dunsborough feeders. Increase in capacity for the single phase Capel: Goodwood Rd Single Goodwood Rd spur out of Capel Capel Summer 2015/16 phase spur upgrade Substation. Improve thermal capacity of the supply Capel: 509 Feeder upgrade to Donnybrook via upgrade of under Donnybrook June 2016 thermally under rated conductor rated conductor. Reconfiguration of feeders at the Busselton: Feeder Busselton substation as part of the reconfiguration of new 22 kV Donnybrook June 2016 installation of a new 22 kV switchboard switchboard in BSN substation. Margaret River: Replace degraded transformers at Address degraded asset condition. Margaret River Summer 2016/17 substation Busselton: Partial conversion of Address degraded asset condition; Busselton 66 kV substation to accommodate increasing demand in Busselton Winter 2017 132 kV the area.
112 Country South 33 kV planning There are no committed capacity There has not been a need to build cluster expansion projects in this planning significant new infrastructure, as there This voltage cluster supplies the cluster. has been minimal agricultural eastern section of the region. Due to development in this cluster over the 7.2.3 COUNTRY EAST REGION the extremely long and lightly loaded past five years. The Country East region covers the distribution networks, the supply Load transfer in this cluster is restricted Wheatbelt to the east of Perth. The voltage has been increased from 22 kV by voltage regulation and limited region is defined by Sawyers Valley in to 33 kV at some point along the interconnections between the long the west, Coolgardie in the east, feeders at four distribution substations. radial distribution power lines. This is Mount Marshal in the north and Lake These are Dumbleyung substation typical of most rural feeders. Where Grace in the south. The demand is a (from Wagin Zone substation), practical, Western Power has extended mixture of general agriculture and Badgebup substation (from Katanning three phase power lines and installed water pumping. There are also Zone substation), Gnowangerup automated remote control switches to residential, commercial and light substation (from Katanning Zone allow interconnection. For safety industrial loads in towns such as substation) and Green Range reasons, Western Power does not Northam, Kellerberrin, Cunderdin, substation (from Albany Zone generally interconnect single phase Merredin and Kondinin. Mining loads substation). lines. also exist in and around Southern The long radial distribution networks in Cross. A large portion of customers are this voltage cluster were not originally supplied from single phase rural As load density in the Country East designed to cater for load types above distribution lines. These spurs were region is relatively low, the power lines typical broad acre farming needs. This specifically designed for farming type have been designed for a lower has become apparent with the electricity demands. Significant block current-carrying capacity. The primary changing characteristic of load in areas loads such as grain handling facilities constraint in the region is voltage such as Ravensthorpe, which has seen and processing plants often require regulation, due to the long radial nature an increase in activity due to local major reinforcement and extension of of the local distribution networks. mining and Bremer Bay, which has three phase power lines. The Block load applications tend to experienced growth due to its distribution networks within this cluster dominate growth levels in the area, popularity as a tourist destination and are robust. through increases in abalone farming. rather than from the underlying load growth rates. There are presently no major thermal Edge-of-grid power stations present constraints within this cluster. However, Ten substations supply the Country opportunities to increase capacity, as there are a few minor issues on some East region at either 22 kV or 33 kV. well as address reliability problems of the single phase spurs connected to experienced by communities located Country East 22 kV planning the feeder backbone. As the loads on at the end of long radial feeders. Diesel cluster individual single phase spurs grow, the power stations have been already phase imbalance is approaching a Western Power has recently relocated been deployed at locations such as point where augmentation will be two 132/66 kV transformers from Ravensthorpe and Bremer Bay. required to balance the loads on each Cannington terminal to Merredin phase and reduce neutral currents. Western Power has worked with the substation, relieving thermal capacity community in Ravensthorpe to limitation in the area. The strategy for reducing phase establish a medium term Network imbalance will be selected from the Transformers at Kellerberrin and Control Service to aid supply to the following options: community. Cunderdin substations have been assessed to be in degraded condition. • conversion of existing single phase This work allows significant These transformers are proposed to spurs into two phases or three expenditure to be deferred on very be replaced by summer 2019/20. phases long radial feeders that peak only for short periods throughout the year, The distribution networks in this region • installation of isolation transformers such as the Gnowangerup feeder that tend to follow agricultural boundaries. at the beginning of the heavily supplies Ravensthorpe. The power lines tend to concentrate loaded single phase spurs. west of Merredin due to the prominence of the agricultural load.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 113 7. SUPPLY ISSUES
Some supply areas have been install voltage regulators on those Nungarin will cause feeders in this identified as having the potential to feeder backbones to address these cluster to approach thermal capacity develop voltage constraints over the constraints. limits over the next few years. Western next few years. Load forecasts suggest Power is monitoring the cluster and In addition to the voltage constraints, it that the demand in these areas may further studies are being performed to is anticipated that load growth in exceed the distribution voltage determine prudent options to meet localities such as York, Toodyay and capacity. The proposed solution is to forecast load growth.
TABLE 51: COUNTRY EAST 22 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions WDC region52 Carrabin Shire of Beverley Wheatbelt Avon Cunderdin Shire of Bruce Rock Central East Kellerberrin Shire of Cunderdin Avon Merredin Shire of Dowerin Avon Northam Shire of Goomalling Avon Wundowie Shire of Kellerberrin Central East Shire of Koorda Avon Shire of Merredin Central East Shire of Mt Marshall Central East Shire of Mukinbudin Central East Shire of Mundaring (Perth) Shire of Northam Avon Town of Northam Avon Shire of Nungarin Central East Shire of Quairading Avon Shire of Tammin Avon Shire of Toodyay Avon Shire of Trayning Central East Shire of Victoria Plains Central Midlands Shire of Westonia Central East Shire of Wyalkatchem Avon Shire of York Avon Shire of Yilgarn Central East
TABLE 52: COUNTRY EAST 22 KV PLANNING CLUSTER - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Northam: York Feeder Beverly Mitigate the low voltage issues on the York feeder Summer Leg - install third voltage Beverly Leg. Reduce feeder utilisation and enable York 2015/16 regulator reliability of supply to new and existing loads.
52 Wheatbelt Development Commission region (where applicable).
114 FIGURE 41: COUNTRY EAST PLANNING REGION
N
MENZIES
MOUNT MARSHALL
WESTERN POWER NETWORK
MUKINBUDIN KOORDA
WESTONIA VICTORIA PLAINS YILGARN WYALKATCHEM TRAYNING NUNGARIN DOWERIN Southern Cross
Yilgarn Carrabin GOOMALLING MERREDIN COOLGARDIE KELLERBERRIN Merredin TOODYAY CUNDERDIN TAMMIN CHITTERING NORTHAM Northam Cunderdin Kellerberrin SWAN Wundowie
YORK
MUNDARING QUAIRADING BRUCE ROCK NAREMBEEN BEVERLEY Bounty
DUNDAS CORRIGIN KONDININ Kondinin
KULIN
WICKEPIN
LAKE GRACE
LEGEND
Zone Substations DUMBLEYUNG
LGA KENT 22kV
33kV
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 115 7. SUPPLY ISSUES
Country East 33 kV planning As in the Country East 22 kV area, within this cluster, there are no cluster load transfer in this cluster is restricted requirements for distribution network Recent infrastructure reinforcements by voltage regulation and limited reinforcements and therefore no within this cluster have been minimal. interconnections. Many customers in committed projects are currently listed. this cluster are also supplied off the Demand has remained steady, Areas of particular interest for planning single phase rural distribution lines, however, mining and water pumping investigation include Corrigin and which were originally designed for station loads become prominent east Narembeen. Load levels are being farming electrical demand. Significant of Merredin. As discussed in Section 6, studied to assess the likelihood of new block loads in this area will most no substation capacity constraints are overloaded spurs in the next few years. forecast to emerge in this cluster over likely require network reinforcement. the five year outlook. Considering the natural load growth
TABLE 53: COUNTRY EAST 33 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Bounty Shire of Bruce Rock Wheatbelt Kondinin Shire of Corrigin Southern Cross Shire of Coolgardie Yilgarn Shire of Dundas Shire of Dumbleyung Shire of Kondinin Shire of Kulin Shire of Lake Grace Shire of Mukinbudin Shire of Narembeen Shire of Nungarin Shire of Westonia Shire of Wickepin Shire of Yilgarn
7.2.4 COUNTRY GOLDFIELDS There are currently five substations REGION feeding the Goldfields region. Two The Country Goldfields region consists distribution voltage levels, 11 kV (for predominantly of mining loads near Ora the City of Kalgoorlie-Boulder) and Banda, Black Flag, Kanowna, Boulder, 33 kV (mainly for mining customers) Coolgardie and towards Kambalda. The are used to reticulate electricity region also includes the City of throughout the region. Kalgoorlie-Boulder, whose loads are mainly residential with pockets of commercial and light industrial.
116 FIGURE 42: COUNTRY GOLDFIELDS PLANNING REGION N
MENZIES
WESTERN POWER NETWORK
YILGARN
Black Flag
Piccadilly
West Kalgoorlie Terminal Boulder
KALGOORLIE-BOULDER
COOLGARDIE LEGEND
Zone Substations Western Mining Kambalda LGA
11kV
33kV
YILGARN
DUNDAS
Country Goldfields 11 kV planning Load transfer between the 11 kV Based on load growth forecast over cluster networks of Western Kalgoorlie terminal the next five years, a small number of Load growth in Kalgoorlie-Boulder and Piccadilly substation is viable, with thermal constraints may arise on the fluctuates, as the local economy is the existing interconnections and 11 kV distribution network within the largely dependent on the mining feeder exit cable ratings. Due to their City of Kalgoorlie-Boulder. Load industry. The commodities sector separation, Western Mining transfers to adjacent lightly loaded boom has contributed to significant Kambalda’s 11 kV feeders are islanded feeders will be the most efficient way growth in the last decade. The with the other 11 kV distribution to resolve these issues. networks within the region. distribution networks in the City of There are currently no committed Kalgoorlie-Boulder are relatively There are currently no major thermal or capacity expansion projects in this robust, with very few capacity voltage capacity constraint issues on planning cluster. constraints at this point in time. the distribution networks within this As discussed in Section 6, no cluster. Reinforcement of the 11 kV substation capacity constraints are distribution networks is sporadic and forecast to emerge in this cluster over normally driven by specific mining and the five year outlook. industrial block loads.
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 117 7. SUPPLY ISSUES
TABLE 54: COUNTRY GOLDFIELDS 11 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Piccadilly City of Kalgoorlie-Boulder Goldfields-Esperance West Kalgoorlie terminal 11 kV Shire of Coolgardie Western Mining Kambalda
Country Goldfields 33 kV planning As discussed in Section 6, no of Kalgoorlie will likely trigger the cluster substation capacity constraints are requirement for installation of a third The feeders in this cluster are forecast to emerge in this cluster over transformer at Black Flag substation. predominantly mining feeders. There the five year outlook. All other reinforcement for new mining loads will be determined on a case-by- are very few constraints imposed on Interconnection exists between case basis. natural load growth. However, new Western Kalgoorlie terminal and mining loads are generally significant Boulder substation, but this is limited There are currently no committed and require major reinforcement. by the thermal rating of the 33 kV capacity expansion projects in this These are determined on a case-by- distribution power lines. planning cluster. case basis. Additional mining loads are required to queue for connection to the Considering the natural load growth network. Significant capital within this cluster, there are no contributions are often required upfront requirements for distribution network to underwrite large investments in the reinforcements. However, any distribution network. proposed significant block load north
TABLE 55: COUNTRY GOLDFIELDS 33 KV - ZONE SUBSTATION, LGA AND REGION
Zone substations Local government authorities DRD regions Black Flag Shire of Coolgardie Goldfields-Esperance Boulder City of Kalgoorlie-Boulder West Kalgoorlie terminal 33 kV Shire of Menzies
7.3 UNDER FAULT RATED current passing through an under fault distribution network, of which 1,027 CONDUCTOR rated section of the network may circuit km (1.7% of the total population Sections of the high voltage distribution cause the conductor to sag (breaching of overhead conductor) is estimated to network have been identified as safe clearance requirements) or break. be under fault rated. Conductor failures, in turn, have the under-fault-rated, which means they There is a committed plan to either potential to cause power outages, have insufficient rating to safely carry remove or suitably protect these bushfires or injury to the public and currents likely to flow in worst-case fault sections of conductor over the next ten Western Power personnel. conditions. These situations arise when years. These high priority sections are augmentations (such as the This constraint occurs primarily in the being investigated and detailed options construction of a new zone substation) country distribution network where analysis is being carried out to identify increase the fault levels in the conductors are designed to carry the most prudent investment option to distribution network. Assets installed lower load currents which also have address these conductors by the end prior to the event that caused the lower fault rating withstand ability. of AA3 (2016/17). It is envisaged that increase of fault levels may have a the remainder of the medium to lower As at 30 June 2015, there were 59,091 fault-limiting characteristic which is less risk conductors will be addressed by circuit km of overhead high voltage than the new fault levels. This leads to the end of the fourth Access conductor in the Western Power the asset being under fault rated. Fault Arrangement (2021/22).
118 TABLE 56: UNDER FAULT RATED CONDUCTOR - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Mitigation safety risk of under fault rated conductor Bridgetown: Mitigate and inadequate protection of the BTN Distribution under fault rated Bridgetown June 2016 network via either replacement and or improvement conductor in protection. Mitigate safety risk and risk of outages due to under Busselton, Busselton: Mitigate under Winter fault rated conductor; ensure compliance with the Dunsborough, fault rated conductor 2015/16 Technical Rules in relation to fault level requirements. Yallingup, Broadwater Mitigate safety risk and risk of outages due to under Cunderdin: Mitigate under Summer fault rated conductor; ensure compliance with the Cunderdin fault rated conductor 2015/16 Technical Rules in relation to fault level requirements. Darlington and Hazelmere: Midland, Woodbridge, Winter Mitigate under fault rated Reduce safety risk of under fault rated conductor. Viveash, Middle Swan, 2015/16 conductor Midvale, Bellevue Geraldton 33kV: Mitigate Mitigate safety risk and risk of outages due to under Summer under fault rated fault rated conductor; ensure compliance with the Geraldton 2016/17 conductor - STG 2 Technical Rules in relation to fault level requirements. Neerabup, Carramar, Kalamunda: Mitigate Banksia Grove, Winter under fault rated Reduce safety risk of under fault rated conductor. Tapping, Ashby, 2015/16 conductor Sinagra, Wanneroo, Hocking Kondinin: Mitigate under Mitigate safety risk and risk of outages due to under Summer fault rated conductor & fault rated conductor; ensure compliance with the Kondinin 2015/16 protection reach Technical Rules in relation to fault level requirements. Mitigate safety risk and risk of outages due to under Merredin: Mitigate under Summer fault rated conductor; ensure compliance with the Merredin fault rated conductor 2015/16 Technical Rules in relation to fault level requirements. Mitigate safety risk and risk of outages due to under Piccadilly: Mitigate under Winter fault rated conductor; ensure compliance with the Kalgoorlie fault rated conductor 2016/17 Technical Rules in relation to fault level requirements. Mitigation safety risk of under fault rated conductor Wagerup: Mitigate under and inadequate protection of the WGP Distribution Warrona June 2016 fault rated conductor network via either replacement and or improvement in protection. West Kalgoorlie Terminal: Mitigate safety risk and risk of outages due to under Summer Mitigate under fault rated fault rated conductor; ensure compliance with the Kalgoorlie 2016/17 conductor Technical Rules in relation to fault level requirements. Yanchep: Mitigate under Wilbinga, Woodridge, Summer Reduce safety risk of under fault rated conductor. fault rated conductor Chitna, Barunah 2015/16
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 119 7. SUPPLY ISSUES
7.4 CONSTRAINED The risk of transformer failures has As a result of this program, the DISTRIBUTION TRANSFORMERS been reduced significantly by the transformers at highest risk of being The Western Power Network includes Overloaded Transformer Program. overloaded have been identified and a a fleet of 65,828 distribution Since its introduction in 2005, fewer committed project for the replacement transformers. than five (on average) transformers of identified transformers for 2015/16 is have failed each year as result of currently underway. After summer For large units (capacity of 100 kVA or overloading, compared to 52 2015/16, analysis will begin to identify greater), the risk of distribution transformer failures in a single high the transformers at risk for 2016/17. transformer overload increases load day in 2004. significantly in heatwave conditions53 in Distribution transformers with which load increases of 200% - 300% Each year, a load analysis is conducted capacities below 100 kVA are are common. At the time of a on all distribution transformers in the managed through the asset transformer’s installation, there is network, assessing parameters such as: replacement program using a “run-to-fail” strategy. Their condition is, usually no information available on the • customer consumption data number of customers it will service or however, routinely monitored during the load to which it will be subjected. • summer peak feeder loads the four year pole inspection cycle and any with physical evidence of • transformer capacity and the As transformers of lower capacity deterioration (such as significant oil number of customers connected. usually service single customers and leaks) are addressed before they fail are normally sized for the maximum The analysis prioritises the in service. load of that customer, they are less replacement of overloaded likely to be overloaded. transformers, based on risk. A Historical data indicates that distribution transformer is considered approximately 5% of the larger to be at risk of overloading when its: capacity transformers identified as • calculated peak load exceeds the being at risk of overloading will fail if nameplate continuous rating by not replaced before the next heatwave, 35%54 possibly exploding. Such failures are assessed as presenting a high public • Transformer Utilisation Factor (TUF) 55 safety risk, due to the possibility of exceeds 0.5. their initiating a fire. This failure rate increases significantly for overloaded transformers subjected to a second heatwave period.
53 In this discussion, a heatwave is defined a period of three or more consecutive days in which daytime temperatures exceed 40°C and remain at 26°C or higher at night. 54 Transformers can be operated safely beyond their nameplate continuous rating for short periods without adversely affecting asset life. The combination of the peak load and utilisation factor criteria account for this. 55 This is an internally-developed measure of the relationship between actual energy delivered by a transformer and its capacity. Empirically, using TUF in conjunction with the degree of overload has been demonstrated to be a reliable predictor of failure risk.
120 TABLE 57: OVERLOADED TRANSFORMER PROGRAM - COMMITTED PROJECTS AND EXPECTED BENEFITS
Project Benefit/s Area/s By when Identify and replace distribution assets performing Metro Transformer Yearly beyond their design capacity to mitigate the risk of Metro Overload Upgrade program asset failure. North Country Transformer Replace distribution assets performing beyond their Yearly North Country Overload Upgrade designed capacity; reduce risk of asset failure. program South Country Replace distribution assets performing beyond their Yearly Transformer Overload South Country designed capacity; reduce risk of asset failure. program Upgrade
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 121 APPENDIX A GLOSSARY
Term Explanation AA3 Access Arrangement 3 - regulatory period from 1 July 2012 to 30 June 2017. Access Code Electricity Networks Access Code 2004 AEMO Australian Energy Market Operator APR Transmission and Distribution Annual Planning Report AQP Applications and Queuing Policy CAG Competing Applications Group CAGR Compound Annual Growth Rate CBD Central Business District Load value on a substation that is at a maximum when other substations in a group or the Coincident network have a maximum value. DEC Department of Environment and Conservation (Western Australia) As applied to transformers, this assessment indicates that the asset's condition will continue to Degraded condition deteriorate, although this may be slowed by remedial action. This assessment is not associated with any reduction in short-term reliability. DRD Department of Regional Development (Western Australia) DM Demand Management Declared Sent-Out Capacity - maximum amount of power that a generator has contracted DSOC with Western Power to export to the network. DTC Distribution Transfer Capacity EMR Electricity Market Review EP Act Western Australian Environmental Protection Act 1986 EPA Environmental Protection Authority (Western Australia) EPBC Act Commonwealth Environment Protection and Biodiversity Conservation Act 1999 ERA Economic Regulation Authority (Western Australia) EV Electric vehicles HV High Voltage IMO Independent Market Operator (Western Australia) IRCR Individual Reserve Capacity Requirement (demand reduction mechanism) IWC Interconnection Works Contract kA Kiloampere (measure of electrical current) kV Kilovolt (measure of electrical potential) kWh Kilowatt hour (measure of electrical energy) LGA Local Government Authority LV Low Voltage MVA Megavolt Ampere (measure of electrical demand) MW Megawatt (measure of the active component of electrical demand) MWEP Mid West Energy Project A Technical Rules planning criterion allowing the loss of load following any single contingency N-0 event under peak demand conditions.
122 Term Explanation A Technical Rules planning criterion allowing no loss of load following any single contingency N-1 event under peak demand conditions. A Technical Rules planning criterion allowing for no loss of load following two concurrent N-1-1 contingency events (generally one planned, one unplanned) at 80% peak load, allowing for generation redespatch. A Technical Rules planning criterion allowing no loss of load following any two concurrent N-2 contingency events under peak demand conditions. NCMT Network Capacity Mapping Tool NCR Network Capacity Rollback or Normal Cyclic Rating A Technical Rules planning criterion allowing a substation to be loaded higher than its N-1 capacity and permitting the disconnection of a limited number of customers for up to 12 hours. NCR Criterion NCR substations are restricted to the Perth metropolitan area due to the practical limitations in deploying a rapid response spare transformer within 12 hours. NCS Network Control Services NDP Network Development Plan NEM National Electricity Market NFIT New Facilities Investment Test NMP Network Management Plan Load value on a substation that is not a maximum when other substations in a group or the Non-coincident network have a maximum value. Probability of Exceedence - the percentage of time that an actual value will exceed the forecast PoE value. For example, under a 'PoE10' forecast, the actual value is expected to exceed the forecast once every ten years. PV Photovoltaic (solar cell) SEWPAC Department of Sustainability, Environment, Water, Population and Communities STATCOM Static Synchronous Compensator SVC Static VAR Compensator South West Interconnected Network - the transmission and distribution components of the SWIN electricity system. South West Interconnected System - the entire electricity system including all of the SWIS generators. ERA-administered definitions of network planning criteria and technical requirements for plant Technical Rules connected to the network. TUF Transformer Utilisation Factor WEM Wholesale Electricity Market The element of the South West Interconnected Network that is owned and operated by Western Power Network Western Power. WPR Works Planning Report
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 123 APPENDIX B CROSS-REFERENCE OF WESTERN POWER PLANNING REGIONS
SOURCES 1. Regions listed on Department of Regional Development and Lands website as at 27 August 2015 (www.drd.wa.gov.au)
2. WA Local Councils listed on ScreenWest’s website as at 27 August 2015 (www.screenwest.wa.gov.au)
Note: Local Government Areas that do not have a matching Western Power Planning Region / Sector / Cluster are not supplied by the SWIN and are not listed.
Perth Metropolitan / Local Government Area Western Power Planning Region / DRD Region (by Perth Metropolitan / DRD Region) Sector / Cluster Goldfields-Esperance Coolgardie (S) Country Goldfields 33 kV Dundas (S) Esperance (S) Kalgoorlie/Boulder (C) Country Goldfields 11 kV Laverton (S) Leonora (S) Menzies (S) Ngaanyatjarraku (S) Ravensthorpe (S) Great Southern Albany (C) Country South / Great Southern Study Area Broomehill-Tambellup (S) Country South / Great Southern Study Area Cranbrook (S) Country South / Great Southern Study Area Denmark (S) Country South / Great Southern Study Area Gnowangerup (S) Country South / Great Southern Study Area Jerramungup (S) Country South / Great Southern Study Area Katanning (S) Country South / Great Southern Study Area Kent (S) Country South / Great Southern Study Area Kojonup (S) Country South / Great Southern Study Area Plantagenet (S) Country South / Great Southern Study Area Woodanilling (S) Country South / Great Southern Study Area Mid West Carnamah (S) Chapman Valley (S) Country North 11 kV, Country North 33 kV Coorow (S) Cue (S) Greater Geraldton (C)) Country North 11 kV, Country North 33 kV Irwin (S) Country North 33 kV Meekatharra (S)
124 Perth Metropolitan / Local Government Area Western Power Planning Region / DRD Region (by Perth Metropolitan / DRD Region) Sector / Cluster Mingenew (S) Morawa (S) Country North 33 kV Mount Magnet (S) Murchison (S) Northampton (S) Country North 6.6 kV, Country North 33 kV Perenjori (S) Country North 33 kV Sandstone (S) Three Springs (S) Country North 33 kV Wiluna (S) Yalgoo (S) Peel Boddington (S) Country East 22 kV Mandurah (C) Metro South 22 kV (C) Murray (S) Metro South 22 kV (C), Country South Serpentine-Jarrahdale (S) Metro South 22 kV (A) Waroona (S) Country South / South West Study Area South West Augusta-Margaret River (S) Country South / South West Study Area Boyup Brook (S) Country South / South West Study Area Bridgetown-Greenbushes (S) Country South / South West Study Area Bunbury (C) Country South / South West Study Area Busselton (S) Country South / South West Study Area Capel (S) Country South / South West Study Area Collie (S) Country South / South West Study Area Dardanup (S) Country South / South West Study Area Donnybrook-Balingup (S) Country South / South West Study Area Harvey (S) Country South / South West Study Area Manjimup (S) Country South / South West Study Area Nannup (S) Country South / South West Study Area Wheatbelt Beverley (S) Country South, Country East 22 kV Brookton (S) Country South Bruce Rock (S) Country East 22 kV, Country East 33 kV Chittering (S) Metro North 22 kV (B) Corrigin (S) Country South, Country East 33 kV Cuballing (S) Country South Cunderdin (S) Country East 22 kV
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 125 APPENDIX B CROSS-REFERENCE OF WESTERN POWER PLANNING REGIONS
Perth Metropolitan / Local Government Area Western Power Planning Region / DRD Region (by Perth Metropolitan / DRD Region) Sector / Cluster Dalwallinu (S) Country North 33 kV Dandaragan (S) Country North 33 kV Dowerin (S) Country North 33 kV, Country East 22 kV Dumbleyung (S) Country South, Country East 33 kV Gingin (S) Metro North 22 kV (B) Goomalling (S) Country East 22 kV, Country North 33 kV Kellerberrin (S) Country East 22 kV Kondinin (S) Country East 33 kV Koorda (S) Country North 33 kV, Country East 22 kV Kulin (S) Country East 33 kV Lake Grace (S) Country East 33 kV, Country South Merredin (S) Country East 22 kV Moora (S) Country North 33 kV Mount Marshall (S) Country East 22 kV Mukinbudin (S) Country East 22 kV Narembeen (S) Country East 33 kV Narrogin Shire (S) Country South Narrogin Town (T) Country South Northam (S) Country East 22 kV Nungarin (S) Country East 22 kV, Country East 33 kV Pingelly (S) Country South Quairading (S) Country East 22 kV Tammin (S) Country East 22 kV Toodyay (S) Metro North 22 kV (B), Country East 22 kV Trayning (S) Country East 22 kV Victoria Plains (S) Country North 33 kV Wagin (S) Country South Wandering (S) Country South West Arthur (S) Country South Westonia (S) Country East 22 kV, Country East 33 kV Wickepin (S) Country South, Country East 33 kV Williams (S) Country South Wongan-Ballidu (S) Country North 33 kV Wyalkatchem (S) Country East 22 kV Yilgarn (S) Country East 33 kV York (S) Country East 22 kV
126 Perth Metropolitan / Local Government Area Western Power Planning Region / DRD Region (by Perth Metropolitan / DRD Region) Sector / Cluster Perth Metropolitan Armadale (C) Metro South 22 kV (A) Bassendean (T) Metro North 22 kV (A) CBD, Metro North 11 kV (B), Metro North Bayswater (C) 22 kV (A) Belmont (C) Metro South 22 kV (B), Metro East 22 kV Metro North 6.6 kV, Metro North 11 kV (B), Cambridge (T) CBD Canning (C) Metro South 22 kV (A), Metro South 22 kV (B) Claremont (T) Metro North 11 kV (A), Metro North 6.6 kV Cockburn (C) Metro South 22 kV (B) Cottesloe (T) Metro North 11 kV (A) East Fremantle (T) Metro South 11 kV (B), Metro South 22 kV (A) Fremantle (C) Metro South 11 kV (B), Metro South 22 kV (A) Gosnells (C) Metro South 22 kV (A), Metro South 22 kV (B) Joondalup (C) Metro North 22 kV (B) Kalamunda (S) Metro South 22 kV (B), Metro East 22 kV Kwinana (T) Metro South 22 kV (C) Melville (C) Metro South 22 kV (B) Mosman Park (T) Metro North 11 kV (A) Mundaring (S) Metro East 22 kV Nedlands (C) Metro North 11 kV (A), Metro North 6.6 kV Peppermint Grove (S) Metro North 11 kV (A) Perth (C) Metro CBD, Metro North 6.6 kV Rockingham (C) Metro South 22 kV (C) South Perth (C) Metro South 11 kV (A), Metro South 22 kV (B) Metro North 11 kV (B), Metro North 22 kV (A), Stirling (C) Metro North 22 kV (B), Metro North 6.6 kV, Subiaco (C) Metro North 6.6 kV, Metro CBD Metro East 22 kV, Metro North 22 kV (A), Swan (C) Metro North 22 kV (B) Metro South 11 kV (A), Metro South 6.6 kV, Victoria Park (T) Metro South 22 kV (B) Vincent (T) CBD, Metro North 11 kV (B) Wanneroo (C) Metro North 22 kV (B)
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 127 APPENDIX C ESTIMATED MAXIMUM SHORT CIRCUIT LEVELS
This appendix lists maximum short The short circuit level calculations • For maximum fault levels, the C circuit levels forecast at each of were determined in accordance with factor (as defined by IEC 60909) is the Western Power Network’s the following: set at 1.10 pu at the faulted bus. major nodes. This information • The IEC 60909 method was used for • Zero fault impedance is assumed. should only be used as an the calculation; this is the source • All generation machines and step-up approximate guide. standard upon which the current transformers are turned on. Australian and New Zealand standard (AS/NZS 3851) is based. • All lines are assumed in service. • The expected fault current shown is 56 IKSS.
Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) Bunbury load area APJ - ALCOA Pinjarra 330.0 15.19 13.09 APJ - ALCOA Pinjarra 132.0 14.27 15.66 BDP - Binningup Desalination Plant 132.0 11.64 9.39 BSI - Barrack Silicon Smelter 132.0 15.24 13.67 BSN - Busselton 132.0 2.63 2.88 BSN - Busselton 66.0 4.38 5.20 BSN - Busselton 22.0 3.44 3.91 BUH - Bunbury Harbour 132.0 10.13 9.88 BUH - Bunbury Harbour 22.0 5.61 5.45 CAP - Capel 66.0 5.41 4.81 CAP - Capel 22.0 3.65 4.13 CLP - Coolup 66.0 1.02 0.70 CLP - Coolup 22.0 1.74 2.22 KEM - Kemerton 330.0 21.74 20.26 KEM - Kemerton 132.0 20.86 22.83 KMP - Kemerton Power 330.0 20.71 19.21 MR - Margaret River 66.0 1.58 1.21 MR - Margaret River 22.0 2.54 3.19 MRR - Marriot Road 22.0 5.46 4.65 MRR - Marriott Road 132.0 17.29 16.77 OLY - Oakley 330.0 17.33 15.10 PIC - Picton 132.0 12.02 11.77 PIC - Picton 66.0 9.87 12.36 PIC - Picton 22.0 6.15 6.08 WSD - Westralian Sands 66.0 5.24 4.82
56 AC component of the initial symmetrical short circuit current which occurs directly after the initiation of the fault (RMS value).
128 Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) Cannington load area BEC - Beckenham 132.0 26.76 28.95 BEL - Belmont 132.0 18.96 18.38 BEL - Belmont 22.0 4.35 0.99 BTY - Bentley 132.0 19.55 17.20 BTY - Bentley 22.0 4.40 0.99 CL - Clarence St 66.0 8.94 7.0 5 CL - Clarence St 11.0 7.8 0 8.05 COL - Collier 66.0 8.99 7.0 6 COL - Collier 11.0 9.39 10.65 CT - Cannington Terminal 132.0 28.54 30.80 CT - Cannington Terminal 66.0 14.62 17.6 4 KDL - Kewdale 132.0 18.34 16.93 KDL - Kewdale 22.0 4.38 0.98 KNL - Kenwick Link 330.0 16.51 15.77 KNL - Kenwick Link 132.0 26.00 26.86 RVE - Rivervale 132.0 17.81 16.57 RVE - Rivervale 22.0 4.57 0.98 TLN - Tomlinson Road 66.0 9.83 8.43 TT - Tate Street 66.0 12.50 13.51 TT - Tate Street 22.0 4.94 6.34 VP - Victoria Pak 66.0 11.98 12.43 WE - Welshpool 132.0 21.20 21.18 WE - Welshpool 22.0 4.50 1.01 East Country load area BDE - Bandee 66.0 1.82 1.53 BNY - Bounty 132.0 0.67 0.85 BNY - Bounty 33.0 1.74 2.49 CAR - Carrabin 66.0 1.26 0.96 CAR - Carrabin 22.0 1.68 1.99 CGT - Collgar Terminal 220.0 3.08 3.98 CGW - Collgar Wind Farm 220.0 3.08 3.98 CUN - Cunderdin 22.0 1.77 2.28 CUN - Cunderdin 66.0 1.13 0.82 KDN - Kondinin 220.0 2.98 2.97 KDN - Kondinin 132.0 1.51 1.67 KEL - Kellerberrin 66.0 1.18 0.90 KEL - Kellerberrin 22.0 1.42 1.91
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 129 APPENDIX C ESTIMATED MAXIMUM SHORT CIRCUIT LEVELS
Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) KDN - Kondinin 33.0 2.86 4.44 MDP - Merredin Power Station 132.0 5.55 7.0 6 MER - Merredin 132.0 4.85 5.63 MER - Merredin 66.0 3.75 4.96 MER - Merredin 22.0 3.31 0.16 MRT - Merredin Terminal 220.0 3.32 4.11 MRT - Merredin Terminal 132.0 5.55 7.0 6 MW - Mundaring Weir 66.0 3.73 2.60 MW - Mundaring Weir 6.6 7.39 8.36 NOR - Northam 132.0 5.26 4.87 NOR - Northam 66.0 4.63 4.30 NOR - Northam 22.0 5.81 4.55 SVY - Sawyers Valley 22.0 4.13 4.56 SVY - Sawyers Valley 132 kV 132.0 7.8 4 6.96 SX - Southern Cross 66.0 0.62 0.44 SX - Southern Cross 33.0 1.85 1.38 WUN - Wundowie 66.0 2.89 2.05 WUN - Wundowie 22.0 2.66 3.06 YER - Yerbillon 66.0 1.16 0.87 YLN - Yilgarn 220.0 2.54 2.52 YLN - Yilgarn 33.0 4.14 5.20 Eastern Goldfields load area BKF - Black Flag 132.0 2.99 3.11 BKF - Black Flag 33.0 5.39 5.15 BLD - Boulder 132.0 5.84 7.14 BLD - Boulder 33.0 6.78 9.28 JAN - Jan 132.0 2.13 2.20 LEF - Lefroy 132.0 2.36 2.59 PCY - Piccadilly St 132.0 5.78 7.22 PCY - Piccadilly St 11.0 10.99 2.08 PKS - Parkeston Substation 132.0 5.64 6.64 WKT - West Kalgoorlie 220.0 3.04 3.84 WKT - West Kalgoorlie 132.0 5.96 8.01 WKT - West Kalgoorlie 33.0 4.01 5.54 WKT - West Kalgoorlie 11.0 10.89 1.85 WMK - Western Mining Kambalda 132.0 2.98 3.32 WMS - Western Mining Smelter 132.0 4.98 5.47
130 Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) East Perth and CBD load area CK - Cook Street 132.0 22.98 23.02 CK - Cook Street 11.0 10.08 2.93 EP - East Perth 132.0 25.20 27.37 EP - East Perth 66.0 5.65 7.07 EP - East Perth 22.0 9.20 1.04 F - Forrest Ave 66.0 5.22 5.65 F - Forrest Ave 11.0 10.23 12.09 HAY - Hay Street 132.0 21.77 22.77 HAY - Hay Street 11.0 11.53 2.18 JTE - Joel Terrace 132 kV 132.0 24.84 26.19 JTE - Joel Terrace 132 kV 11.0 8.59 1.85 MIL - Milligan Street 132.0 19.26 20.93 MIL - Milligan Street 11.0 12.94 2.17 NP - North Perth 132.0 20.36 20.00 NP - North Perth 11.0 8.98 1.84 SUM - Summers Street 132.0 24.92 26.63 W - Wellington Street 66.0 5.39 6.05 W - Wellington Street 11.0 8.39 9.53 Guildford load area D - Darlington 132.0 13.61 13.09 D - Darlington 22.0 4.27 0.94 FFD - Forrestfield 132.0 13.31 13.22 FFD - Forrestfield 22.0 5.76 1.05 GLT - Guildford Terminal 330.0 16.58 16.17 GLT - Guildford Terminal 132.0 23.00 25.14 HZM - Hazelmere 132.0 22.39 23.90 HZM - Hazelmere 22.0 4.36 0.96 K - Kalamunda 132.0 11.33 10.93 K - Kalamunda 22.0 5.62 1.05 MDY - Munday 132.0 13.25 13.15 MDY - Munday 22.0 5.49 1.05 MJ - Midland Junction 132.0 21.57 23.32 MJ - Midland Junction 22.0 4.84 1.32 Kwinana load area AFM - Australian Fused Materials 132.0 20.82 19.10 AKW - ALCOA Kwinana 132.0 32.04 34.68
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 131 APPENDIX C ESTIMATED MAXIMUM SHORT CIRCUIT LEVELS
Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) BHK - Broken Hill Kwinana 66.0 7.16 7.9 8 BP - British Petroleum 66.0 7.31 7.97 BP - British Petroleum 22.0 4.67 4.33 BPR - B.P. Refinery 132.0 26.60 27.78 CBP - CSBP 132.0 24.84 24.66 CKB - Cockburn Power 132.0 31.33 34.59 HIS - Hismelt 132.0 23.49 23.05 KDP - Kwinana Desalination Plant 132.0 28.27 30.31 KMK - Kerr McGee Kwinana 132.0 29.32 32.59 KND - Kwinana Donaldson Road 132.0 28.20 31.33 KPP - Kwinana Power Partnership 132.0 27.47 29.36 KW - Kwinana 330.0 20.66 21.14 KW - Kwinana 132.0 32.38 35.36 KW - Kwinana 66.0 7.61 9.11 MED - Medina 132.0 22.69 20.15 MED - Medina 22.0 4.40 1.05 MSR - Mason Road 132.0 29.32 32.59 MSR - Mason Road 22.0 4.57 0.98 PLD - Parklands 132.0 11.01 10.83 RO - Rockingham 132.0 20.23 19.28 RO - Rockingham 22.0 6.28 1.03 TPP - Tiwest Pigment Plant 132.0 29.32 32.59 WM - Western Mining 132.0 23.18 22.19 Mandurah load area MH - Mandurah 132.0 10.47 10.18 MH - Mandurah 22.0 4.37 0.99 MSS - Meadow Springs 132.0 11.02 10.84 MSS - Meadow Springs 22.0 4.25 0.97 PNJ - Pinjarra 132.0 13.86 13.21 PNJ - Pinjarra 22.0 4.30 4.60 WAI - Waikiki 132.0 15.37 13.90 WAI - Waikiki 22.0 4.34 0.95 Muja load area ALB - Albany 132.0 1.63 1.91 ALB - Albany 22.0 6.21 6.96 BGM - Boddington Gold Mine 132.0 10.01 10.22 BLW - Bluewaters Terminal 330.0 22.22 21.27
132 Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) BNP - Beenup 132.0 1.26 1.25 BNP - Beenup 22.0 3.43 3.86 BOD - Boddington 132.0 10.01 10.22 BOD - Boddington 22.0 4.95 6.81 BTN - Bridgetown 132.0 4.77 4.93 BTN - Bridgetown 22.0 4.61 6.03 BWP - Bluewaters Power Station 330.0 22.22 21.27 CO - Collie 66.0 2.14 1.66 CO - Collie 22.0 2.43 3.26 CPS - Collie Power Station Terminal 330.0 20.13 19.21 KAT - Katanning 66.0 1.47 1.70 KAT - Katanning 22.0 2.74 2.82 KOJ - Kojonup 132.0 4.00 4.35 KOJ - Kojonup 66.0 2.62 2.87 KOJ - Kojonup 22.0 4.37 5.91 LWT - Landwehr Terminal 330.0 16.61 15.66 MBR - Mount Barker 132.0 1.67 1.88 MBR - Mount Barker 22.0 3.75 4.97 MJP - Manjimup 132.0 3.11 3.19 MJP - Manjimup 22.0 4.17 5.65 MU - Muja 330.0 22.69 21.95 MU - Muja 220.0 9.12 10.27 MU - Muja 132.0 23.51 28.17 MU - Muja 66.0 3.73 3.78 NGN - Narrogin 66.0 1.22 1.64 NGN - Narrogin 22.0 2.27 2.74 NGS - Narrogin South 220.0 3.72 3.08 NGS - Narrogin South 66.0 1.24 1.67 SHO - Shotts 330.0 21.89 21.00 WAG - Wagin 66.0 1.20 1.04 WAG - Wagin 22.0 1.39 1.98 WAPL - Worsley Alumina Pty Ltd 132.0 17.70 20.38 WAPL - Worsley Alumina Pty Ltd 66.0 4.13 4.62 WCG - Worsley Co Generation 132.0 17.91 20.53 WCL - Western Colleries Limited 132.0 16.34 13.88 WGP - Wagerup 132.0 8.72 7.0 6 WGP - Wagerup 22.0 4.02 4.35
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 133 APPENDIX C ESTIMATED MAXIMUM SHORT CIRCUIT LEVELS
Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) WLT - Wells Terminal 330.0 7.15 6.80 WLT - Wells Terminal 132.0 11.46 12.49 WOR - Worsley 132.0 17.91 20.53 Neerabup load area CKN - Clarkson 132.0 15.13 13.46 CKN - Clarkson 22.0 5.07 0.98 JDP - Joondalup 132.0 18.66 18.30 JDP - Joondalup 22.0 4.46 0.98 LDE - Landsdale 132.0 17.50 17.26 LDE - Landsdale 22.0 4.37 1.00 MUC - Muchea 132.0 17.6 0 15.29 MUC - Muchea 22.0 4.69 0.85 MUL - Mullaloo 132.0 19.20 19.66 MUL - Mullaloo 22.0 4.26 0.99 PBY - Padbury 132.0 17.59 16.63 PBY - Padbury 22.0 4.35 0.97 WGA - Wangara 132.0 16.99 16.44 WGA - Wangara 22.0 4.31 0.99 WNO - Wanneroo 132.0 20.08 19.95 WNO - Wanneroo 22.0 4.51 1.12 North Country load area CPN - Chapman 132.0 3.76 4.45 CPN - Chapman 11.0 9.03 10.01 CTB - Cataby 132.0 5.95 5.98 DUR - Durlacher Street 33.0 7.3 0 8.60 DUR - Durlacher Street 11.0 7.02 10.35 EMD - Emu Downs 132.0 4.49 4.66 ENB - Eneabba 132.0 5.66 5.51 ENB - Eneabba 33.0 3.03 4.09 GGV - Golden Grove 132.0 1.26 1.56 GRS - Greenough River Solar Farm 132.0 6.97 8.34 GTN - Geraldton 132.0 4.14 4.93 GTN - Geraldton 33.0 6.73 8.95 KMC - Kerr McGee Cataby 132.0 5.95 5.98 KRA - Karara Mine 330.0 2.09 3.03 MBA WF - Mumbida Windfarm 132.0 4.78 5.18 MGA - Mungarra 132.0 6.97 8.34
134 Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) MOR - Moora 132.0 2.75 1.84 MOR - Moora 33.0 1.58 1.87 RAN - Rangeway 132.0 3.77 4.48 RAN - Rangeway 11.0 9.07 11.96 RGN - Regans 132.0 5.72 5.78 RGN - Regans 33.0 3.10 3.67 RGN - Regans 22.0 4.19 1.01 TS - Three Springs 132.0 7.62 8.03 TS - Three Springs 33.0 2.06 1.97 TST - Three Springs Terminal 330.0 3.18 3.61 TST - Three Springs Terminal 132.0 7.53 8.29 WWF - Walkaway Windfarm 132.0 5.10 5.65 Northern Terminal load area A - Arkana 132.0 19.72 19.84 A - Arkana 22.0 5.68 1.07 BCH - Beechboro 132.0 19.51 18.77 BCH - Beechboro 22.0 4.40 1.01 BCT - Balcatta 132.0 18.89 18.04 BCT - Balcatta 22.0 4.36 1.00 EDG - Edgewater 132.0 19.20 19.65 GNN - Newgen Neerabup 330.0 13.25 13.45 H - Hadfields 132.0 16.51 15.56 H - Hadfields 22.0 4.39 0.99 HBK - Henley Brook 132.0 12.77 10.51 HBK - Henley Brook 22.0 4.29 0.98 KMM - Kerr McGee Muchea 132.0 14.08 11.21 MA - Manning Street 132.0 17.8 3 17.35 MA - Manning Street 11.0 11.59 2.03 MLA - Mount Lawley 132.0 21.18 22.06 MLG - Malaga 132.0 28.69 33.78 MLG - Malaga 22.0 5.38 0.97 MO - Morley 132.0 17.31 18.37 MO - Morley 11.0 12.06 2.01 NB - North Beach 132.0 19.35 19.29 NB - North Beach 22.0 5.65 1.03 NBT - Neerabup Terminal 330.0 13.62 13.82 NBT - Neerabup Terminal 132.0 21.31 21.51
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 135 APPENDIX C ESTIMATED MAXIMUM SHORT CIRCUIT LEVELS
Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) NOW- Nowergup 132.0 15.13 13.46 NT - Northern Terminal 330.0 17.8 9 18.30 NT - Northern Terminal 132.0 28.69 33.78 OP - Osborne Park 132.0 19.52 19.87 OP - Osborne Park 11.0 11.85 1.94 PJR - Pinjar Power Station 132.0 28.90 31.37 Y - Yokine 132.0 19.35 19.43 Y - Yokine 11.0 11.81 2.00 YP - Yanchep 132.0 14.88 13.16 YP - Yanchep 22.0 4.47 1.00 South Fremantle load area AMT - Amherst 132.0 20.03 17.15 AMT - Amherst 22.0 4.38 0.99 APM - Australian Paper Mills 66.0 9.36 8.05 APM - Australian Paper Mills 22.0 4.74 6.12 BIB - Bibra Lake 132.0 21.64 18.73 BIB - Bibra Lake 22.0 4.38 0.99 E - Edmund Street 66.0 10.91 10.55 E - Edmund Street 11.0 8.42 8.43 MYR - Myaree 66.0 8.76 7.45 MYR - Myaree 22.0 4.62 4.90 NF - North Fremantle 66.0 10.18 9.09 NF - North Fremantle 11.0 7.72 8.61 OC - OConnor 66.0 9.94 9.81 OC - OConnor 22.0 4.79 5.10 SF - South Fremantle 132.0 27.6 4 25.17 SF - South Fremantle 66.0 14.07 17.31 SF - South Fremantle 22.0 14.59 1.04 Southern Terminal load area BYF - Byford 132.0 13.26 11.65 BYF - Byford 22.0 6.24 1.01 CC - Cockburn Cement 132.0 24.14 21.54 CC - Cockburn Cement 22.0 6.96 0.98 CCL - Cockburn Cement Ltd 132.0 24.02 21.45 CVE - Canning Vale 132.0 18.92 18.66 CVE - Canning Vale 22.0 4.50 1.01 G - Gosnells 132.0 22.46 21.66
136 Fault level Fault level Substation Voltage (kV) 3 phase (kA) 1 phase (kA) G - Gosnells 22.0 5.91 1.03 GNI - Glen Iris 132.0 26.71 28.58 MDN - Maddington 132.0 22.80 20.84 MDN - Maddington 22.0 4.40 0.96 MUR - Murdoch 132.0 25.39 23.48 MUR - Murdoch 22.0 4.75 0.94 RTN - Riverton 132.0 20.69 18.05 RTN - Riverton 22.0 4.86 0.99 SNR - Southern River 132.0 20.64 19.08 SNR - Southern River 22.0 4.38 1.01 ST - Southern Terminal 330.0 21.92 22.86 ST - Southern Terminal 132.0 35.02 38.98 WLN - Willeton 22.0 4.36 0.96 WLN - Willetton 132.0 19.56 19.21 Western Terminal load area C - Cottesloe 11.0 8.71 1.88 CTE - Cottesloe 132 kV 132.0 18.38 15.78 HE - Herdsman 6.6 11.45 12.76 HE - Herdsman Parade 66.0 8.35 6.69 MCE - Medical Centre 132kV 66.0 9.85 10.80 MCE - Medical Centre 11.0 9.72 1.89 N - Nedlands 66.0 10.95 11.30 N - Nedlands 6.6 11.71 12.73 SP - Shenton Park 66.0 11.45 13.01 SP - Shenton Park 6.6 11.80 13.02 U - University 66.0 9.89 10.08 U - University 6.6 11.46 13.22 WD - Wembley Downs 66.0 9.61 8.06 WD - Wembley Downs 11.0 9.48 10.72 WT - Western Terminal 132.0 21.84 22.04 WT - Western Terminal 66.0 13.20 16.73
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 137 APPENDIX D CONNECTION APPLICATION PROCESS MAPS
This appendix contains the following process maps:
1. Competing Applications Group (CAG) Solution
2. Applicant-Specific Solution
3. Non-Competing and Unconstrained Applications.
FIGURE 43: PROCESS MAP - COMPETING APPLICATIONS GROUP (CAG) SOLUTION
Connecting transmission loads and large generators to the Western Power Network
MUST BE COMPLETED BEFORE FOLLOWING PHASE
Submit an Submit a Connection Identify CAG Preliminary Enquiry Form with Application and Technical Access Offer Solution Access Offer Lodgement fee Data with Lodgement fee
Project Project Project Construction & Phase Enquiry Operation Initiation Scoping Planning Commissioning
The Enquiry phase The Project Initiation phase The Project Scoping phase The Project Planning The required network Once constructed, provides guidance on the involves identifying network involves developing a phase involves Western modifications are the new or modified information required to constraints applicable to scope of work for each Power preparing business then constructed and connection assets become complete a Connection your application, assessing option to modify the cases, contracts, detailed commissioned by Western the property of Western Application form. An if your application is network, assessing each designs and estimates, and Power under the terms of Power. Enquiry Assessment competing for network option, and selecting the construction plans for the the Interconnection Works Assets can now begin will assist you to identify capacity, and identifying final technical solution to final technical solution to Contract (IWC). operating under the terms a suitable network viable options to modify be implemented. modify the network. of the Electricity Transfer connection point and the network to meet your Access Contract (ETAC). evaluate the feasibility of requirements. your project.
Fact GETTING STARTED APPLICATIONS & STUDIES STATUTORY APPROVALS PERFORMANCE sheets QUEUING POLICY VERIFICATION AND OTHER INFORMATION ENQUIRY ASSESSMENT COMPUTER MODELS MODEL VALIDATION Regulatory Requirements TESTS – TECHNICAL PRELIMINARY Contribution Payments ASSESSMENT RULES COMPLIANCE ENVIRONMENTAL Contracts and Invoicing ASSESSMENT & STAKEHOLDER Useful Contacts ENGAGEMENT
PROJECT PLANNING DEFINITION (PPD)
Competing Applications DESIGNS
Group (CAG) Solution ESTIMATES
CAG solutions enable the connection of multiple customers via a common shared network solution. CAG SOLUTION FEE CAG SOLUTION FEE (POPF) (PAF) Each applicant participates in the CAG solution and progresses their individual Connection Works. CAG SOLUTION (NOI) CAG SOLUTION (PAO & AO)
138 FIGURE 44: PROCESS MAP - APPLICANT-SPECIFIC SOLUTION
Connecting transmission loads and large generators to the Western Power Network
MUST BE COMPLETED BEFORE FOLLOWING PHASE
Submit an Submit a Connection Identify Solution Develop Enquiry Form with Application and Technical Access Offer Options Access Offer Lodgement fee Data with Lodgement fee
Project Project Project Construction & Phase Enquiry Operation Initiation Scoping Planning Commissioning
The Enquiry phase The Project Initiation phase The Project Scoping phase The Project Planning The required network Once constructed, provides guidance on the involves identifying network involves developing a phase involves Western modifications are the new or modified information required to constraints applicable to scope of work for each Power preparing business then constructed and connection assets become complete a Connection your application, assessing option to modify the cases, contracts, detailed commissioned by Western the property of Western Application form. An if your application is network, assessing each designs and estimates, and Power under the terms of Power. Enquiry Assessment competing for network option, and selecting the construction plans for the the Interconnection Works Assets can now begin will assist you to identify capacity, and identifying final technical solution to final technical solution to Contract (IWC). operating under the terms a suitable network viable options to modify be implemented. modify the network. of the Electricity Transfer connection point and the network to meet your Access Contract (ETAC). evaluate the feasibility of requirements. your project.
Fact GETTING STARTED APPLICATIONS & STUDIES STATUTORY APPROVALS PERFORMANCE sheets QUEUING POLICY VERIFICATION AND OTHER INFORMATION ENQUIRY ASSESSMENT COMPUTER MODELS MODEL VALIDATION Regulatory Requirements TESTS – TECHNICAL PRELIMINARY Contribution Payments ASSESSMENT RULES COMPLIANCE ENVIRONMENTAL Contracts and Invoicing ASSESSMENT & STAKEHOLDER Useful Contacts ENGAGEMENT
PROJECT PLANNING DEFINITION (PPD)
Applicant-Specific Solution DESIGNS
ESTIMATES An Applicant-Specific solution enables the connection of a single customer. An Access Offer is made subject to a positive outcome from the Objections Process. APPLICANT-SPECIFIC SOLUTION
OBJECTIONS PROCESS
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 139 APPENDIX D CONNECTION APPLICATION PROCESS MAPS
FIGURE 45: PROCESS MAP - NON-COMPETING AND UNCONSTRAINED APPLICATIONS
Connecting transmission loads and large generators to the Western Power Network
MUST BE COMPLETED BEFORE FOLLOWING PHASE
Submit an Submit a Connection Identify Solution Develop Enquiry Form with Application and Technical Access Offer Options Access Offer Lodgement fee Data with Lodgement fee
Project Project Project Construction & Phase Enquiry Operation Initiation Scoping Planning Commissioning
The Enquiry phase The Project Initiation phase The Project Scoping phase The Project Planning The required network Once constructed, provides guidance on the involves identifying network involves developing a phase involves Western modifications are the new or modified information required to constraints applicable to scope of work for each Power preparing business then constructed and connection assets become complete a Connection your application, assessing option to modify the cases, contracts, detailed commissioned by Western the property of Western Application form. An if your application is network, assessing each designs and estimates, and Power under the terms of Power. Enquiry Assessment competing for network option, and selecting the construction plans for the the Interconnection Works Assets can now begin will assist you to identify capacity, and identifying final technical solution to final technical solution to Contract (IWC). operating under the terms a suitable network viable options to modify be implemented. modify the network. of the Electricity Transfer connection point and the network to meet your Access Contract (ETAC). evaluate the feasibility of requirements. your project.
Fact GETTING STARTED APPLICATIONS & STUDIES STATUTORY APPROVALS PERFORMANCE sheets QUEUING POLICY VERIFICATION AND OTHER INFORMATION ENQUIRY ASSESSMENT COMPUTER MODELS MODEL VALIDATION Regulatory Requirements TESTS – TECHNICAL PRELIMINARY Contribution Payments ASSESSMENT RULES COMPLIANCE ENVIRONMENTAL Contracts and Invoicing ASSESSMENT & STAKEHOLDER Useful Contacts ENGAGEMENT
PROJECT PLANNING DEFINITION (PPD)
Non-Competing and DESIGNS
Unconstrained Applications ESTIMATES
Non-Competing and Unconstrained Applications progress as an Applicant-Specific solution without APPLICANT-SPECIFIC SOLUTION: the Objections Process. NON COMPETING / UNCONSTRAINED
140 APPENDIX E PEAK FORECAST DATA
COMPARISON OF WESTERN POWER NETWORK CENTRAL CASE ANNUAL PEAK DEMAND FORECASTS - 2011/12 TO 2014/15
Peak load Year 2014/15 - PoE50 2013/14 - PoE50 2012/13 - PoE50 2011/12 - PoE50 (historical) 1998/99 2,019 1999/00 2,263 2000/01 2,299 2001/02 2,216 2002/03 2,491 2003/04 2,760 2004/05 2,834 2005/06 2,856 2006/07 3,201 2007/08 3,238 2008/09 3,341 2009/10 3,607 2010/11 3,581 2011/12 3,694 2012/13 3,611 4,043 2013/14 3,514 3,923 4,141 2014/15 3,605 3,677 4,069 4,275 2015/16 3,712 3,720 4,140 4,372 2016/17 3,707 3,710 4,203 4,464 2017/18 3,705 3,709 4,266 4,578 2018/19 3,700 3,705 4,326 4,674 2019/20 3,721 3,727 4,387 4,771 2020/21 3,727 3,734 4,444 4,865 2021/22 3,734 3,742 4,504 4,960 2022/23 3,755 3,765 4,562 5,059 2023/24 3,778 3,788 4,634 5,160 2024/25 3,801 3,812 4,704 5,258
WESTERN POWER ANNUAL PLANNING REPORT 2015/16 141 APPENDIX E PEAK FORECAST DATA
COMPARISON OF 2014/15 CENTRAL CASE PEAK LOAD FORECASTS - WESTERN POWER NETWORK AND IMO
IMO Western Power Network Electricity Adjusted Expected Expected Expected Central Central Central (raw) historical Peak load case case case case case case Year entering peak demand - PoE10 - PoE50 - PoE90 - PoE10 - PoE50 - PoE90 SWIS demand (historical) (2014/15) (2014/15) (2014/15) (2014/15) (2014/15) (2014/15) (historical) - PoE10 2000/01 2,538 2,299 2001/02 2,473 2,216 2002/03 2,721 2,491 2003/04 3,004 2,760 2004/05 3,055 2,834 2005/06 3,008 2,856 2006/07 3,364 3,474 3,201 2007/08 3,392 3,806 3,238 2008/09 3,509 3,818 3,341 2009/10 3,758 3,926 3,607 2010/11 3,735 4,160 3,581 2011/12 3,857 4,064 3,694 2012/13 3,732 4,054 3,611 2013/14 3,702 4,252 3,514 2014/15 3,744 4,145 3,605 2015/16 4,114 3,858 3,634 3,962 3,712 3,462 2016/17 4,149 3,886 3,657 3,962 3,707 3,452 2017/18 4,191 3,924 3,690 3,965 3,705 3,446 2018/19 4,223 3,951 3,713 3,965 3,700 3,435 2019/20 4,244 3,968 3,726 3,992 3,721 3,450 2020/21 4,265 3,984 3,738 4,003 3,727 3,450 2021/22 4,308 4,026 3,779 4,018 3,734 3,451 2022/23 4,343 4,058 3,808 4,045 3,755 3,466 2023/24 4,380 4,093 3,841 4,074 3,778 3,481 2024/25 4,415 4,124 3,869 4,105 3,801 3,497 2023/24 3,778 3,788 4,634 5,160 2024/25 3,801 3,812 4,704 5,258
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