>Distribution Annual Planning Report 2015

>Distribution Annual Planning Report 2015 For Public Release December 2015

DISCLAIMER Essential Energy is registered as a Distribution Network Service Provider. This Distribution Annual Planning Report (DAPR) 2015 has been prepared and published by Essential Energy under clause 5.12.2 and 5.13.2 of the National Electricity Rules to notify Registered Participants and Interested Parties of the results of the distribution network annual planning review and should only be used for those purposes. This document does not purport to contain all of the information that a prospective investor or participant or potential participant in the National Electricity Market, or any other person or interested parties may require. In preparing this document it is not possible nor is it intended for Essential Energy to have regard to the investment objectives, financial situation and particular needs of each person who reads or uses this document. In all cases, anyone proposing to rely on or use the information in this document should independently verify and check the accuracy, completeness, reliability and suitability of that information for their own purposes. Accordingly, Essential Energy makes no representations or warranty as to the accuracy, reliability, completeness or suitability for particular purposes of the information in this document. Persons reading or utilising this document acknowledge that Essential Energy and their employees, agents and consultants shall have no liability (including liability to any person by reason of negligence or negligent misstatement) for any statements, opinions, information or matter (expressed or implied) arising out of, contained in or derived from, or for any omissions from, the information in this document, except in so far as liability under any New South Wales and Commonwealth statute cannot be excluded. Contact For all enquiries regarding the Distribution Annual Planning Report 2015 and for making written submissions contact: Essential Energy DM Coordinator PO Box 5730 Port Macquarie NSW 2444 Email: dmcoordinator@essentialenergy.com.au For Public Release December 2015 Page 2 of 183

CONTENTS EXECUTIVE SUMMARY... 6 1 INTRODUCTION... 7 1.1 About Essential Energy... 7 1.1.1 Our Objectives... 7 1.1.2 Our Vision... 8 1.1.3 Operating Environment... 8 1.1.4 Essential Energy statistics... 9 1.2 Essential Energy s Network... 9 1.2.1 Number and Types of Distribution Assets... 11 1.3 Annual Planning Review... 12 1.3.1 Network planning process... 13 1.4 Significant changes from previous DAPR... 14 1.4.1 Analysis and explanation of forecast changes... 14 1.4.2 Analysis and explantion of changes in other information... 14 2 FORECASTS for the FORWARD PLANNING PERIOD... 15 2.1 Forecasting Strategy... 15 2.2 Forecasting Methodology and Process... 16 2.2.1 Sources of load forecast input information... 17 2.2.2 Assumptions applied to load forecasts... 18 2.3 North Coast... 19 2.3.1 Terranora Supply Area... 19 2.3.2 Lismore Supply Area... 22 2.3.3 Casino Supply Area... 26 2.3.4 Grafton Supply Area... 27 2.3.5 Coffs Harbour Supply Area... 30 2.3.6 Nambucca Heads Supply Area... 33 2.3.7 Kempsey Supply Area... 34 2.3.8 Port Macquarie Supply Area... 37 2.3.9 Herons Creek Supply Area... 40 2.3.10 Taree Supply Area... 41 2.3.11 Stroud Supply Area... 44 2.3.12 Hawks Nest Supply Area... 47 2.4 Northern Region... 48 2.4.1 Armidale Supply Area... 48 2.4.2 Glen Innes Supply Area... 51 2.4.3 Inverell Supply Area... 53 2.4.4 Tenterfield Supply Area... 55 2.4.5 Waggamba (Ergon) Supply Area... 56 2.4.6 Moree Supply Area... 57 2.4.7 Narrabri Supply Area... 59 2.4.8 Gunnedah Supply Area... 61 2.4.9 Tamworth Supply Area... 62 2.4.10 Beryl Supply Area... 65 2.4.11 Wellington Supply Area... 68 2.4.12 Dubbo Supply Area... 69 2.4.13 Nyngan Supply Area... 73 2.4.14 Broken Hill Supply Area... 75 2.5 South East Region... 77 2.5.1 Bathurst Supply Area... 77 2.5.2 Oberon Supply Area... 80 2.5.3 Orange Supply Area... 81 2.5.4 Molong Supply Area... 83 2.5.5 Moruya North Supply Area... 84 2.5.6 Bega Supply Area... 87 2.5.7 Cooma Supply Area... 90 2.5.8 Steeple Flat Supply Area... 93 2.5.9 Munyang Supply Area... 94 2.5.10 Queanbeyan Supply Area... 96 2.5.11 Goulburn Supply Area... 98 2.5.12 Murrumburrah Supply Area... 101 2.5.13 Tumut Supply Area... 103 2.5.14 Yass Supply Area... 106 2.6 Southern Region... 108 For Public Release December 2015 Page 3 of 183

2.6.1 Parkes Supply Area... 108 2.6.2 Forbes Supply Area... 110 2.6.3 Cowra Supply Area... 111 2.6.4 Temora Supply Area... 114 2.6.5 Wagga North Supply Area... 117 2.6.6 Wagga Wagga (Copland St) Supply Area... 120 2.6.7 Morven Supply Area... 122 2.6.8 Albury Supply Area... 123 2.6.9 Finley Supply Area... 125 2.6.10 Deniliquin Supply Area... 127 2.6.11 Coleambally Supply Area... 128 2.6.12 Darlington Point Supply Area... 130 2.6.13 Griffith Supply Area... 131 2.6.14 Yanco Supply Area... 134 2.6.15 Buronga Supply Area... 137 2.7 Future Connection Points... 139 2.8 Transmission Distribution Connection Point Forecast... 140 2.8.1 Transmission - Distribution Connection Point load forecast North... 140 2.8.2 Transmission - Distribution Connection Point load forecast Central... 141 2.8.3 Transmission - Distribution Connection Point load forecast South and Far West... 142 2.9 Forecast of Reliability Target Performance... 143 3 IDENTIFIED SYSTEM LIMITATIONS... 144 3.1 Subtransmission Feeder Limitations... 145 3.2 Subtransmission and Zone Limitations... 147 3.3 Primary Distribution Feeder Limitations... 148 4 NETWORK INVESTMENTS... 151 4.1 Regulatory Test / RIT-Ds completed or in progress... 151 4.2 Potential RIT-Ds for identified system limitations... 151 4.3 Commited Investments... 151 4.3.1 Refurbishment and replacement investments... 151 4.3.2 Urgent and unforseen investments... 155 5 JOINT PLANNING... 156 5.1 Results of Joint Planning with the TNSP TransGrid in 2015... 156 5.1.1 Summary of the process and methodology... 156 5.1.2 Investments jointly planned in 2015... 157 5.1.3 Additional Information... 157 5.2 Results of Joint Planning with the TNSP Powerlink in 2015... 157 5.2.1 Summary of the process and methodology... 157 5.2.2 Investments jointly planned in 2015... 157 5.2.3 Additional Information... 157 5.3 Results of Joint Planning with the DNSP Energex in 2015... 157 5.3.1 Summary of the process and methodology... 157 5.3.2 Investments jointly planned in 2015... 158 5.3.3 Additional Information... 158 5.4 Results of Joint Planning with the DNSP Ergon in 2015... 158 5.4.1 Summary of the process and methodology... 158 5.4.2 Investments jointly planned in 2015... 158 5.4.3 Additional Information... 158 5.5 Results of Joint Planning with the DNSP Ausgrid in 2015... 158 5.5.1 Summary of the process and methodology... 158 5.5.2 Investments jointly planned in 2015... 158 5.5.3 Additional Information... 158 5.6 Results of Joint Planning with the DNSP Endeavour Energy in 2015... 158 5.6.1 Summary of the process and methodology... 158 5.6.2 Investments jointly planned in 2015... 158 5.6.3 Additional Information... 159 5.7 Results of Joint Planning with the DNSP ActewAGL in 2015... 159 5.7.1 Summary of the process and methodology... 159 5.7.2 Investments jointly planned in 2015... 159 5.7.3 Additional Information... 159 5.8 Results of Joint Planning with the DNSP Powercor in 2015... 159 5.8.1 Summary of the process and methodology... 159 5.8.2 Investments jointly planned in 2015... 159 5.8.3 Additional Information... 159 6 NETWORK PERFORMANCE... 160 For Public Release December 2015 Page 4 of 183

6.1 Reliability Performance... 160 6.1.1 Performance against Feeder Category Standards... 160 6.1.2 Performance against Individual Feeder Standards... 160 6.2 Quality of Supply Performance... 161 7 ASSET MANAGEMENT... 164 7.1 Essential Energy s asset management approach... 164 7.1.1 Introduction... 164 7.1.2 Asset Management Plans... 164 7.1.3 Network Planning Strategy... 165 7.1.4 Distribution Growth Strategy... 165 7.1.5 Reliability Strategy... 165 7.1.6 Power Quality Strategy... 166 7.1.7 Bushfire Prevention Strategy... 167 7.1.8 Environmental Management Strategy... 167 7.1.9 Refurbishment Strategy... 167 7.1.10 Maintenance Strategy... 168 7.1.11 Network Operating Strategy... 168 7.1.12 Asset Disposal Strategy... 168 7.1.13 Delivering the Network Management Strategies... 169 7.2 Treatment of Distribution Losses... 169 7.3 Asset issues impacting identified system limitations... 169 7.4 Obtaining further information on the asset management strategy and methodology... 170 8 DEMAND MANAGEMENT... 171 8.1 Demand management activities in the preceding year... 171 8.2 Plans for demand management and embedded generation... 173 8.3 Issues arising from applications to connect embedded generation... 174 8.4 Generation Connection Details... 175 9 INVESTMENTS in METERING and INFORMATION TECHNOLOGY... 176 9.1 Metering... 176 9.2 Information Technology... 177 10 REGIONAL DEVELOPMENT PLANS... 181 11 GLOSSARY... 183 For Public Release December 2015 Page 5 of 183

EXECUTIVE SUMMARY Since 1 January 2013, the National Electricity Rules (NER) have stated that all Distribution Network Service Providers (DNSPs) operating in the national electricity market are required to: conduct an annual planning review and publish a Distribution Annual Planning Report (DAPR); conduct economic assessments of potential project options under a new regulatory investment test for distribution (RIT-D), and implement a Demand Side Engagement Strategy to consult with and engage nonnetwork providers in the development and evaluation of potential solutions to identified network needs. The annual planning review includes the planning for all assets and activities carried out by Essential Energy that would materially affect the performance of its network. This includes planning activities associated with replacement and refurbishment of assets and negotiated services. The objective of the annual planning review is to identify possible future issues that could negatively affect the performance of the distribution network to enable DNSPs to plan for and adequately address such issues in a timely manner. The outcome of the annual planning review is the Distribution Annual Planning Report (DAPR). Essential Energy is required to prepare and publish a Distribution Annual Planning Report that is compliant with the requirements of the National Electricity Rules (Section 5.13.2 and Schedule 5.8) to: provide transparency to Essential Energy s decision making processes and provide a level playing field for all regions in the national electricity market in terms of attracting investment and promoting efficient decisions; set out the results of Essential Energy s annual planning review, including joint planning, covering a minimum five year forward planning period for distribution assets; inform registered participants and interested parties on the annual planning review outcomes - report on capacity and load forecasts for sub-transmission lines, zone substations and transmission-distribution connection points, plus, where they have been identified, any 11 primary distribution feeders which were overloaded or forecast to be overloaded within the next two years; provide information on Essential Energy's demand management activities and actions taken to promote non-network initiatives each year; and plans for demand management and embedded generation over the forward planning period; and assist non-network providers, Transmission Network Service Providers (TNSPs), DNSPs, and connection applicants to make efficient investment decisions. The DAPR covers a minimum five year forward planning period for distribution network assets. For Public Release December 2015 Page 6 of 183

1 INTRODUCTION 1.1 About Essential Energy Essential Energy is a State Owned Corporation (SOC) responsible for building, operating and maintaining Australia s largest electricity network and delivering safe, reliable energy supplies to more than 820,000 customers. Spanning 95 per cent of New South Wales, the company s distribution area covers diverse terrain including humid coastal environments in the north coast, semi-arid desert in the far west, alpine peaks in the south and a grain belt that crosses central NSW from north to south. Essential Energy is responsible for building and maintaining almost 200,000 kilometres of powerlines, around 1.4 million power poles, over 136,000 distribution substations and 333 zone substations that span a diverse geographical area. Essential Water, an operating division of Essential Energy, delivers water services to more than 10,000 customers in Broken Hill, Menindee, Sunset Strip and Silverton and sewerage services to around 9,500 customers in Broken Hill. Funding of the electricity distribution network is through a five-yearly distribution network revenue determination made by the Australian Energy Regulator (AER) in accordance with the National Electricity Law and National Electricity Rules economic regulatory framework. In early 2015, Essential Energy consolidated its regions from four to three. Essential Energy s business purpose is to be of service to our communities by efficiently distributing electricity to our customers in a way that is safe, reliable and sustainable. 1.1.1 Our Objectives Essential Energy s principal objectives, stated in Section 6B of the Energy Services Corporations Act 1995 No. 95 are: (a) (b) (c) (d) (e) (f) to be a successful business and, to this end: to operate at least as efficiently as any comparable businesses, to maximise the net worth of the State s investment in it, to exhibit a sense of social responsibility by having regard to the interests of the community in which it operates, to protect the environment by conducting its operations in compliance with the principles of ecologically sustainable development contained in section 6 (2) of the Protection of the Environment Administration Act 1991, to exhibit a sense of responsibility towards regional development and decentralisation in the way in which it operates, to operate efficient, safe and reliable facilities for the distribution of electricity and other forms of energy, to be an efficient and responsible supplier of electricity and other forms of energy and of services relating to the use and conservation of electricity and other forms of energy, to be a successful participant in the wholesale and retail markets for electricity and other forms of energy and for services relating to the use and conservation of electricity and other forms of energy. Each of the principal objectives is of equal importance. For Public Release December 2015 Page 7 of 183

Essential Energy also has an objective to improve value for money and reduce price pressures for electricity users, through adopting measures to enhance efficiency and productivity and ensure an appropriate and cost-effective investment program. 1.1.2 Our Vision The Essential Energy vision is to be of service to our communities by efficiently distributing electricity to our customers in a way that is safe, reliable and sustainable. Essential Energy aims to achieve balanced commercial outcomes supporting the long term sustainability of electricity distribution in regional NSW. Our Principal Activities A leading provider of essential services Operating under a decentralised regional management structure, with a recent consolidation from four to three regional management teams responding quickly and effectively to local needs and priorities Providing essential energy services to more than 820,000 homes and businesses across rural and regional NSW, and water services to over 10,000 homes and businesses in Far West NSW Maintaining almost 200,000 kilometres of power lines, around 1.4 million power poles and over 136,000 distribution substations across a diverse geographical area Investing in network upgrades to meet changing population and energy demands, renew ageing assets and ensure the continued delivery of safe, reliable and affordable essential services Transforming the electricity network through a focus on cost effective alternatives to improve reliability, support the growth of renewable energy and make energy efficiency simpler for customers. 1.1.3 Operating Environment Essential Energy is regulated by statutory and legislative requirements including work health and safety (WH&S), environmental, competition, industrial, consumer protection and information laws, the National Electricity Rules, the NSW Electricity Supply Act, the Energy Services Corporations Act, and a NSW Distribution Network Service Provider licence. Essential Energy ensures compliance with these laws and regulations through its internal codes and policies and a common control framework. It comprises plans, policies, procedures, delegations, instruction and training, audits of compliance, and risk management. Essential Energy is subject to the National Electricity Law (NEL) and National Electricity Rules (NER) which regulate the National Electricity Market. As a NSW Statutory State Owned Corporation and NSW Energy Services Corporation, Essential Energy is generally subject to most of the statutory and other legal requirements as other businesses. Essential Energy operates in the National Electricity Market (NEM) as a Distribution Network Service Provider (DNSP). Essential Energy is also required to follow government and regulatory direction. Locally the NSW Government Industry and Investment NSW department (IIN - Legislative framework) mandates the Network Design, Reliability and Performance Licence Conditions. The Independent Pricing and Regulatory Tribunal (IPART - Electricity) is responsible for administering licensing within the NSW energy industry and monitoring compliance with licence requirements. The Australian Energy Regulator (AER) regulates the transmission and distribution sectors of the National Electricity Market under the National Electricity Laws and National Electricity Rules. Essential Energy s operations are guided by a number of important policies and codes, including a Code of Conduct, Safety Policy, Environmental Code of Conduct and Policy and Statement of Business Ethics. For Public Release December 2015 Page 8 of 183

1.1.4 Essential Energy statistics Table 1 - Essential Energy Statistics for the 2014/15 Financial Year Category Number at 30/6/15 Distribution Customer Numbers (Total) 824,459 Customer Numbers at Year End (Southern) 168,165 Customer Numbers at Year End (Northern) 171,317 Customer Numbers at Year End (South Eastern) 179,635 Customer Numbers at Year End (North Coast) 305,342 Maximum Demand (MW) 2,162 Feeder Number CBD - Feeder Number Urban 294 Feeder Number Short Rural 915 Feeder Numbers Long Rural 244 Energy Received by Dist Network to Year End GWh 13,098 Energy Distributed to Year End (Residential) GWh 4,406 Energy Distributed to Year End (Non-Residential including un-metered supplies) GWh 7,726 Energy Distributed to Year End (Southern) GWh 3,155 Energy Distributed to Year End (Northern) GWh 3,105 Energy Distributed to Year End (South Eastern) GWh 3,045 Energy Distributed to Year End (North Coast) GWh 2,827 System Loss Factor (%) 7.38 Transmission System (km) - Transmission (number) 1 20 Sub Transmission System (km) 10,752 - Zone (number) 333 - Distribution (number) 137,678 High Voltage Overhead (km) 146,901 High Voltage Underground (km) 2,405 Low Voltage Overhead (km) 20,162 2 Low Voltage Underground (km) 6,805 2 Pole (Number) 1,386,609 3 Streetlights (Number) 158,284 1.2 Essential Energy s Network Essential Energy s network is unique in terms of the geographic area it covers, the terrain it traverses, the vegetation that grows within it and the diversity of weather that impacts it. The scale of assets required to ensure the network physically reaches customers in the most far reaching corners of NSW is unlike any other network in Australia. Essential Energy is the largest regionally based 1 Essential Energy assumes any substation that converts to a voltage that is not used for distribution is a Transmission. 2 A significant amount of data cleansing occurred during the year to identify overhead and underground Low Voltage services which were captured as Low Voltage mains. This has contributed to the reduction of Low Voltage overhead and increase in Low Voltage underground. 3 Reduction due to Private Poles being re-classified during the 2014-15 reporting period For Public Release December 2015 Page 9 of 183

Network Service Provider in Australia. Its core business is the distribution of electricity to customers in a specified geographical boundary of New South Wales and authorised supply areas of Queensland and Victoria. It is important to understand the scale of assets Essential Energy must manage, and acknowledge that the majority of costs associated with electricity distribution are not driven by the number of customers or their demand on the network. Rather, network costs are driven by the number of assets required to deliver electricity to each customer. Whether there are 50 customers connected to one pole or 50 poles connecting one customer, each asset needs to be inspected, safely maintained, and replaced at the end of its life. Essential Energy s franchise area, as shown in Figure 1, covers approximately 737,000 km², or 95 per cent of New South Wales, with over 820,000 network customers. The electricity distribution network is one component of an integrated system by which electricity is generated, transmitted and then distributed to customers. The network has a large number of asset types across different voltage levels, and customers can be connected at any voltage level from 132 down to low voltage (400/230 volts) depending on their power needs. Electrical loads on the network range from large single customers, such as gold and coal mines, cotton gins, abattoirs, feedlots, irrigation pumps, shopping complexes, to urban commercial and residential centres, as well as rural farms, villages and remote Single Wire Earth Return (SWER) connected customers. Figure 1 - Essential Energy's Network Area to 5 October 2015. For Public Release December 2015 Page 10 of 183

Figure 2 - The consolidation of Essential Energy s regions occurred on 6 October 2015. 1.2.1 Number and Types of Distribution Assets Essential Energy s network consists of almost 200,000 kilometres of subtransmission, high voltage distribution, low voltage distribution power lines, and around 1.4 million poles. This network of wires is predominantly an overhead system that traverses terrain varying from coastal, alpine and mountainous in the east to the open plains in the west, and is exposed to a variety of extreme climatic conditions. The majority of the rural distribution network is radial in nature with most parts only able to be supplied from one source. There is little opportunity for interconnection with other circuits for security and continuation of supply when performing maintenance activities or in the event of unplanned outages. This is equally true of the radial 132 and 66 subtransmission networks. Due to the low customer densities found throughout the rural network, capital expenditure cannot generally be justified to improve this situation. Essential Energy is however committed to continually reviewing the reliability of its network in all parts of its supply area with a view to utilising available technologies and appropriate practices to provide the maximum reliability and security of supply possible within these constraints. Approximately 95 per cent of the network is of an overhead construction type and 95 per cent of the distribution substation population are pole-mounted due to the predominately rural nature of the supply area. For Public Release December 2015 Page 11 of 183

Table 2 - Network Assets at 30 June 2015 ASSETS Overhead lines Circuit kilometres Underground cables Number Transformers Nominal capacity 220 3.0 - - - 132 2081.6 9.8 80 3117.5 110 21.0-3 300.0 66 7607.5 33.1 401 5496.6 33 5335.2 46.9 1513 1612.0 22 42433.5 317.2 34287 2443.1 11 and below 70423.3 2062.9 91621 6990.2 SWER (all voltages) 29686.9 38.9 8689 141.7 Low voltages 4 26069.0 6217.1 - - Total network 183661.0 8725.9 136594 20101.1 5 Figure 3 - Typical components of Essential Energy's electricity network 1.3 Annual Planning Review The NER require that the Annual Planning Review includes the planning for all assets and activities carried out by Essential Energy that would materially affect the performance of its network. This includes planning activities associated with replacement and refurbishment of assets and negotiated services. The objective of the Annual Planning Review is to identify possible future issues that could adversely impact the performance of the distribution network to enable DNSPs to plan for and 4 Includes services 5 The reduction in transformer capacity compared to the 2014 Distribution Annual Planning Report is due to aligning with the definition of total installed capacity from the Regulatory Information Notice For Public Release December 2015 Page 12 of 183

adequately address such issues in a timely manner. The outcome of the Annual Planning Review is the Distribution Annual Planning Report (DAPR). This Distribution Annual Planning Report provides information to Registered Participants and interested parties on the nature and location of emerging constraints on Essential Energy s subtransmission and 11 distribution network assets, commonly referred to as the Distribution Network. The timely identification and publication of emerging network constraints allows the market to identify potential non-network solutions and Essential Energy to develop and implement appropriate and timely solutions to them. 1.3.1 Network planning process The planning and development process for the distribution network is carried out in accordance with the National Electricity Rules (NER) Chapter 5 Part B Planning and Expansion. Essential Energy carries out network planning at both a strategic and project level. The processes used for each of these levels of network planning are set out in the Essential Energy Subtransmission and Distribution Network Planning Criteria and Guidelines stored in Essential Energy s Business Management System. The Essential Energy investment governance process ensures continuous review and assurance that capital prudence and efficiency are being achieved, as well as being consistently and seamlessly aligned with longer term strategic planning. The Essential Energy network planning process is designed to identify the most efficient ways of ensuring the network business meets its network performance obligations. Significant emphasis is placed on the planning and project identification stage, assessing customer supply needs, identifying and selecting the optimal solution to meet those needs, and provide the most pragmatically prudent and efficient outcome. All relevant potential credible options, including non-network and operational alternatives are considered in determining how to best meet network performance obligations and the objectives of the National Electricity Law. There is a robust selection process based on Present Value of Cost options analyses together with a range of sensitivity analyses that explicitly trade off alternative investment options using quantified estimates for credible option costs and market benefits, against business performance targets, to identify the optimum portfolio of projects that minimises the cost of achieving desired performance. In accordance with NER obligations and statutory requirements, network augmentation and demand management options are assessed impartially, using a consistent cost effectiveness review process. Demand management options are evaluated on the extent to which they can avoid or defer the need for network augmentation. This allows various combinations of demand management and deferred augmentation projects to be assessed. The requirement to consider demand management and non-network option solutions to address identified network needs is included in Chapter 5 Part B Network Planning and Expansion section of the NER. The first stage of the network planning process involves the gathering of all data required to inform the investment process. This includes historical and existing peak demands, the preparation of a range of seasonal demand forecasts, examining network capacity limits, assessing asset condition, forecasting new customer connections (including new or augmented spot loads and/or embedded generators) and taking into account duty of care obligations. The forecast adequacy of the network is assessed against key criteria which include: Meeting modern infrastructure standards, including safety and security of the network, and environmental compliance Addressing any Demand Capacity imbalance Risk, Reliability & Power Quality performance Asset condition & re-investment considerations Customer connection requirements (both loads & embedded generation) For Public Release December 2015 Page 13 of 183

When emerging network limitations are identified, a range of feasible options including both network and non-network solutions are developed to address the network need and to ensure continuing compliance. A rigorous review then selects the most economic option (or options). Each network capital investment is required to be consistent with Essential Energy s longer term network plans and standards whilst being compliant with the National Electricity Law objective. This Distribution Annual Planning Report seeks to inform stakeholders and provides advice on emerging network limitations and network adequacy. It also provides details of the expected time required to allow appropriate corrective network augmentation, non-network alternatives or modifications to connection facilities. The Essential Energy network planning approach is outlined in its Network Management Plan and is consistent with the principles of the NSW Government Total Asset Management framework. Essential Energy is required to comply with mandatory service standards in accordance with the Reliability and Performance Licence Conditions for Electricity Distributors (July 2014), imposed by the NSW Minister for Energy. These Licence Conditions facilitate the delivery of a safe and reliable supply of electricity. This document provides information for locations where investment is required to address network limitations due to forecast demand and other prudent inseparable considerations. 1.4 Significant changes from previous DAPR The majority of the 2015 DAPR consists of only minor changes, though there has been a major focus placed on redeveloping the forecasting process to use a nationally consistent methodology. The new methodology is explained in detail in Section 2.2. 1.4.1 Analysis and explanation of forecast changes Overall network load is expected to increase at a steady rate, however as to be expected, the recorded demand has allowed for refinement of the previous forecasts over the next five years. At the subtransmission and zone substation level, forecasts have also been adjusted to account for expected load transfers for new and decommissioned sites. There have been a number of changes to Essential Energy s network including the addition of new zone substations and subtransmission lines, these may affect the recorded loads on the existing system based on various load transfers. The methodology used to generate Zone forecasts has seen substantial change to a more complex, repeatable process, closely aligned with the AEMO connection point forecasting methodology. This change in methodology is detailed in Section 2.2, and is evident with minor variations in Subtransmission (STS) and Zone (ZS) forecasts compared to previous years. 1.4.2 Analysis and explantion of changes in other information There are some minor variations in this document attributed to equipment classifications. These changes enable the published data to align with the annual Regulatory Information Notice. For Public Release December 2015 Page 14 of 183

2 FORECASTS for the FORWARD PLANNING PERIOD This section provides a detailed assessment of the current peak demand forecast process. The peak demand forecasts provide Essential Energy with the basis for identifying network limitations, identifying and evaluating the credible network and non-network options to address those limitations and (if applicable) commencing the RIT-D process. It also feeds into the strategic asset management plan which documents the capital and operating investment expected to be required for the forward planning period. Essential Energy s Network System peak demand for the 2015 Winter peaked at 2,259 megawatts (MW) at 6:30 pm (EDST) on Thursday 16 July 2015. Figure 4 - Essential Energy's recorded maximum demands 2.1 Forecasting Strategy A primary driver in the development of the network and the identification of specific projects is the forecast of electricity demand and energy. The spatial demand forecast is a critical process which supports planning, development of the capital program and the regulatory submission. Given the importance of the demand forecast on the required capital expenditure and the strategic asset management plan, Essential Energy s main objectives are; Efficient, closed-loop development and refinement of the forecasting process, data and documentation Engagement of the wider audience to appropriately inform of the impacts and building blocks of demand. In the process of moving towards achieving these objectives Essential Energy has seen a substantial transition in the network forecasting methodology and process from a relatively simplistic process For Public Release December 2015 Page 15 of 183

(such as minimal weather correction and reconciliation between top-down and bottom up forecasts) which required a high level of subjectivity to a more complex, repeatable process, closely aligned with the AEMO connection point forecasting methodology. 2.2 Forecasting Methodology and Process The forecasting methodology has been developed and refined using two main vision items as the driving force, these items are: That the demand forecasting process undertaken is commensurate with the benefits the forecast provides That all demand forecasts are auditable and repeatable. Essential Energy has developed a methodology which provides for the establishment of the building blocks required to achieve this vision, this methodology is summarised in Figure 5. Figure 5 - Forecasting Methodology Question What data may be important for a specific forecast? Prediction Testing Analysis Document potential forecasting inputs and sources Predict accuracy improvement and required forecast effort Develop or refine forecasting processes appropriate for the benefits derived from the output Produce forecasts using process applicable to the benefits derived from the output Document forecasting accuracy, benefit and risk over any alternate forecast processes previously undertaken As shown in Figure 5, Essential Energy s methodology calls for continuous improvement in the forecasting process specific to the site in question and dependant on the predicted cost/benefit, as an example some sites may have poor input data and hence poor forecasting accuracy, however if no benefits can be identified from improving the forecast then the cost to improve the process cannot be justified and the forecast inaccuracy specific to the site in question will remain, alternatively high benefits (such as capital deferral) would justify substantial forecasting effort and the appropriate level of expense and rigour. To assist in the network planning process and to identify regional growth patterns, several levels of forecast are used by Essential Energy: Overall Essential Energy network forecast Regional TransGrid and Powerlink connection point forecast Subtransmission feeder forecast Zone forecasts Local distribution feeder forecasts as necessary. The base forecasting process used by Essential Energy is fundamentally the same as AEMO s published Connection Point Forecasting Methodology 6. 6 Report to Australian Energy Market Operator - Connection Point Forecasting A Nationally Consistent Methodology for Forecasting Maximum Electricity Demand. Acil Allen Consulting. 26 June 2013 For Public Release December 2015 Page 16 of 183

At a high level, the process consists of: Data collection and collation To cater for regional and local needs, a forecast of the demand at each zone substation is developed based on historical demands and information provided by major customers. Account is taken of load diversity between connection points. generation is recognised and included in the forecast where it offers firm capacity at the time of demand Outlier removal / Data preparation In order to ensure only system normal conditions are evaluated, this may include the removal of large customers, etc Temperature correction (or normalisation) In order to provide a reference set of conditions from which each year can be compared (with a probability of exceedance of 50 per cent) Repeat for each season over the time periods available The forecast covers both summer and winter demands and uses data going back to 2004 where possible Determine the most applicable growth rate based on known variables Growth rates can be applied using residential growth rates or similar Calculate forecast load The forecast extends over a planning horizon of five to ten years Apply any post model adjustments Where there is known potential for the connection of major spot load developments such as mining loads and major subdivisions, the forecast takes into account any reasonably firm step load increases in the medium term. Where the impacts of government policy decisions of technological developments can be determined, Essential Energy endeavours to include an appropriate adjustment factor Reconciliation of forecasts Calculation to ensure the forecast aligns with previously developed forecasts for upstream and downstream network components 2.2.1 Sources of load forecast input information Potential inputs to an individual forecast and the applicable source data may include: Table 3 Potential sources of load forecast input information Potential Inputs Historic demands Seasonal indicators Future step loads (large customer or residential subdivision) Residential growth rates Economic conditions Weather patterns Technology changes Potential Source Data Interval meter data, SCADA data, recloser data, derived loads, assumed factors Seasonal trends Information from large customers and developers Department of Planning Australian Bureau of Statistics Bureau of Meteorology Industry Reports, Government Department Reports e.g. Department of Industry, Innovation and Science For Public Release December 2015 Page 17 of 183

Potential Inputs Generation Individual customer demands Regulatory variation Distribution changes Distribution programs Tariff changes Potential Source Data Interval meter data, Bureau of Meteorology, customer information Interval meter data AER documentation, MEPS reports, other government initiatives Network information (planning, operations, load control) Network program information (planning, load control) Network Tariff information 2.2.2 Assumptions applied to load forecasts Numerous assumptions are required in order to streamline the forecasting process. Some of these include: All large customers, embedded generations are recorded appropriately Historic demand data used for summer forecasts comprise the high temperature days from months November to March inclusive while winter forecasts consider the low temperature days from months May to September All load information is actual (i.e. no erroneous readings, metering drift, etc) All switching events are recorded or easily detected in analysis All temperature related data is actual The selected temperate sites are the best currently available to Essential Energy for representation of the conditions at the load sites All historic network changes have been accounted for Information provided by large load customers and developers will come to fruition Subtransmission Feeder forecasts are a special case, using a proportion of the Bulk Supply point forecast rather than an actual forecast, hence subtransmission forecasts may not reconcile to Zone forecasts Site forecasts are performed individually; consequently there may be deviations to combined upstream forecasts. For Public Release December 2015 Page 18 of 183

2.3 North Coast 2.3.1 Terranora Supply Area 2.3.1.1 Description of Terranora area The Terranora subtransmission substation is owned by Essential Energy and is supplied from the Queensland transmission system via 2 x 110 lines that are jointly owned by Essential Energy and Powerlink. A high voltage direct current transmission network is connected between Mullumbimby and Terranora (via Bungalora) which allows supply to be either injected into the Lismore area from Terranora or injected into the Terranora area from Lismore. Population growth in the Tweed Shire is one of the highest in regional NSW and is expected to remain above the state average. TERRANORA Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.1.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 757 110 Powerlink Mudgeeraba 275/110 STS Terranora 110/66 STS 106 39.3 39.8 39.8 40.3 40.3 126 40.3 40.8 40.8 41.3 41.3 758 110 Powerlink Mudgeeraba 275/110 STS Terranora 110/66 STS 106 39.3 39.8 39.8 40.3 40.3 126 40.3 40.8 40.8 41.3 41.3 9501 66 Terranora 110/66 STS Cudgen ZS 59 20.0 20.3 20.3 20.5 20.5 66 21.1 21.3 21.3 21.6 21.6 9502 66 Terranora 110/66 STS Murwillumbah ZS 61 8.9 9.0 9.0 9.1 9.1 68 9.3 9.4 9.4 9.5 9.5 9503 66 Terranora 110/66 STS Banora Pt ZS 59 26.5 26.8 26.8 27.2 27.2 66 26.3 26.6 26.6 27.0 27.0 9504 66 Terranora 110/66 STS Condong Sw Stn 61 7.7 7.8 7.8 7.9 7.9 68 8.0 8.1 8.1 8.2 8.2 9505 66 Cudgen ZS Banora Point ZS 53 2.1 2.2 2.2 2.2 2.2 59 1.2 1.2 1.2 1.2 1.2 9508 66 Terranora 110/66 STS Tweed Heads ZS 41 13.1 13.3 13.3 13.5 13.5 46 11.9 12.0 12.0 12.2 12.2 9510 66 Banora Point ZS Tweed Heads South ZS 49 16.1 16.3 16.3 16.5 16.5 55 13.4 13.6 13.6 13.7 13.7 9514 66 Condong Sw Stn Murwillumbah ZS 61 7.8 7.9 7.9 8.0 8.0 68 8.1 8.2 8.2 8.3 8.3 9516 66 Tweed Head South ZS Tweed Heads ZS 49 3.9 4.0 4.0 4.0 4.0 55 1.2 1.2 1.2 1.2 1.2 9406 33 Cudgen ZS Casuarina Sw Stn 19 9.4 9.5 9.7 9.8 9.9 21 10.5 10.6 10.6 10.7 10.7 9407 33 Casuarina Sw Stn Hastings Pt ZS 20 0.0 0.0 0.0 0.0 0.0 20 0.0 0.0 0.0 0.0 0.0 9409 33 Casuarina Sw Stn Hastings Pt ZS 20 9.4 9.5 9.7 9.8 9.9 20 10.5 10.6 10.6 10.7 10.7 A 30MW generator is located at Condong and is connected to the Terranora 110/66 STS at 66 via feeders 9504, 9514 and 9502. For Public Release December 2015 Page 19 of 183

2.3.1.3 STS and ZS load forecast SUMMER Terranora Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Banora Point 66/11 24/30 24/30 33 0.99 12.1 11.7 11.4 11.2 10.9 4.24 3 Cudgen 11 66/33/11 70/40/30 70/40/30 33 1.00 11.5 11.7 11.8 11.9 12.0 3.10 7 Cudgen 33 66/33/11 70/40/30 70/40/30 44 0.99 9.3 9.3 9.4 9.4 9.4 0.00 7 Hastings Point 33/11 15 15/18 16.5 0.98 9.4 9.5 9.7 9.8 9.9 3.58 5 Murwillumbah 66/11 15/20/25 15/20/25 27.5 0.94 15.7 15.6 15.5 15.4 15.3 5.96 8 Terranora 110/66 110/66 70/100 70/100 70/100 220 1.00 82.5 82.3 82.1 82.0 81.8 0.00 6 Terranora 11 66/11 24/30 24/30 33 0.98 4.4 4.3 4.3 4.2 4.2 2.32 3 Tweed Heads 66/33 25 25 27.5 0.95 17.3 17.1 16.9 16.7 16.5 1.03 31 Tweed Heads South 66/11 20/30 20/30 33 0.97 15.1 15.0 14.9 14.9 14.8 3.88 51 WINTER Terranora Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Banora Point 66/11 24/30 24/30 36 1.00 12.5 12.2 12.0 11.7 11.5 4.24 6 Cudgen 11 66/33/11 70/40/30 70/40/30 36 1.00 12.3 12.4 12.4 12.5 12.5 3.10 5 Cudgen 33 66/33/11 70/40/30 70/40/30 48 1.00 10.6 10.6 10.6 10.5 10.5 0.00 2 Hastings Point 33/11 15 15/18 18 0.99 10.5 10.6 10.6 10.7 10.7 3.58 6 Murwillumbah 66/11 15/20/25 15/20/25 30 0.97 16.0 15.8 15.6 15.4 15.3 5.96 7 Terranora 110/66 110/66 70/100 70/100 70/100 240 0.99 72.9 72.9 72.9 72.9 72.9 0.00 4 Terranora 11 66/11 24/30 24/30 36 1.00 5.7 5.6 5.5 5.4 5.3 2.32 6 Tweed Heads 66/33 25 25 30 0.96 14.3 14.2 14.1 14.0 14.0 1.03 3 Tweed Heads South 66/11 20/30 20/30 36 0.99 14.3 14.5 14.7 14.9 15.1 3.88 80 For Public Release December 2015 Page 20 of 183

2.3.1.4 Subtransmission Single Diagram of Terranora area TWEED Mudgeeraba (Qld) Powerlink (note 1) NSW-Qld border Essential Energy 758 757 double-circuit 110 Notes 1) Essential Energy owns the NSW side of the 110 double circuit (757,758), Powerlink owns the QLD side 2) Energex take backup supply from Essential Energy at their Kirra substation during contingencies on their 33 system 3) Directlink is privately owned Bungalora 9502 TERRANORA 9901 9504 DirectLink (Mullumbimby) (note 3) Condong Sw Stn Murwillumbah 9514 G Condong Co-generation Private Essential Energy Zone s Essential Energy Transmission G Generator 110/66/11 66/33/11 66/11 AC/DC Converter 110 33/11 66 Switching Station 9508 Energex 33 Kirra (note 2) n.o. Tweed Heads 9516 Tweed Heads South Banora Point 9510 9503 9505 9501 Cudgen 9406 9407 9409 Hastings Point & Sub-transmission s 66 110 33 For Public Release December 2015 Page 21 of 183

2.3.2 Lismore Supply Area 2.3.2.1 Description of Lismore area The Lismore 132/66 subtransmission substation is owned by Essential Energy. It receives its supply via three Essential Energy 132 lines from the TransGrid 330/132 subtransmission substation at Lismore. A high voltage direct current transmission network is connected between Mullumbimby and Terranora (via Bungalora) which allows supply to be either injected into the Lismore area from Terranora or injected into the Terranora area from Lismore. LISMORE Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section For Public Release December 2015 Page 22 of 183

2.3.2.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 9U8 132 9U9 132 9W1 132 TransGrid Lismore 330/132 STS TransGrid Lismore 330/132 STS TransGrid Lismore 330/132 STS Lismore 132/66 STS 183 44.2 44.2 45.0 45.0 45.0 214 47.4 47.4 47.7 47.7 48.1 Lismore 132/66 STS 128 40.9 40.9 41.6 41.6 41.6 143 43.9 43.9 44.2 44.2 44.5 Lismore 132/66 STS 128 37.8 37.8 38.5 38.5 38.5 143 40.6 40.6 40.9 40.9 41.2 9G2 132 Ballina ZS Lennox Head ZS 124 9.7 9.7 9.9 9.9 9.9 139 9.5 9.5 9.5 9.5 9.6 9G3 132 Lennox Head ZS Suffolk Park ZS 124 13.0 13.0 13.3 13.3 13.3 139 13.8 13.8 13.9 13.9 14.0 9G4 132 Suffolk Park ZS Ewingsdale ZS 124 18.2 18.2 18.5 18.5 18.5 139 19.9 19.9 20.1 20.1 20.2 9G5 132 Ewingsdale ZS Mullumbimby ZS 122 31.7 31.7 32.3 32.3 32.3 137 37.8 37.8 38.1 38.1 38.4 9U6 132 Lismore 132/66 STS Mullumbimby ZS 107 20.0 20.0 20.3 20.3 20.3 123 24.2 24.2 24.4 24.4 24.6 9U7 132 Lismore 132/66 STS Dunoon ZS 107 22.6 22.6 23.0 23.0 23.0 123 27.0 27.0 27.2 27.2 27.4 9U7/1 132 Dunoon ZS Mullumbimby ZS 107 17.4 17.4 17.7 17.7 17.7 123 21.3 21.3 21.5 21.5 21.6 892 66 Lismore 132/66 STS Woodburn ZS 11 5.5 5.5 5.5 5.5 5.5 19 6.1 6.1 6.1 6.1 6.1 893 66 Lismore 132/66 STS Casino ZS 38 0.0 0.0 0.0 0.0 0.0 43 0.0 0.0 0.0 0.0 0.0 894:LME 66 Lismore 132/66 STS Kyogle ZS 11 7.1 7.1 7.1 7.1 7.1 19 6.4 6.3 6.2 6.2 6.1 0897:LME 66 Lismore 132/66 STS Alstonville ZS 62 15.5 15.5 15.8 15.8 15.8 69 17.7 17.7 17.8 17.8 18.0 8502 66 Lismore East ZS Alstonville ZS 62 8.2 8.2 8.4 8.4 8.4 69 9.9 9.9 10.0 10.0 10.1 8503 66 Ballina ZS Alstonville ZS 62 7.2 7.2 7.3 7.3 7.3 69 7.9 7.9 7.9 7.9 8.0 8507 66 Alstonville ZS Ballina ZS 61 8.3 8.3 8.5 8.5 8.5 68 9.2 9.2 9.2 9.2 9.3 8510 66 Lismore Sw Stn East Lismore ZS 61 18.7 18.7 19.0 19.0 19.0 68 21.1 21.1 21.3 21.3 21.5 8511 66 Lismore 132/66 STS Lismore Sw Stn 62 16.4 16.4 16.7 16.7 16.7 69 17.5 17.5 17.7 17.7 17.8 8512 66 Lismore Sw Stn Lismore University ZS 54 8.0 8.0 8.0 8.0 8.0 54 6.9 6.8 6.7 6.6 6.5 8513 66 Lismore Sw Stn Lismore University ZS 54 8.0 8.0 8.0 8.0 8.0 54 6.9 6.8 6.7 6.6 6.5 8514 66 Lismore 132/66 STS South Lismore ZS 68 11.6 11.4 11.2 11.0 10.8 68 8.0 7.9 7.7 7.6 7.6 8515 66 Lismore 132/66 STS South Lismore ZS 68 11.5 11.3 11.1 10.9 10.7 68 7.9 7.8 7.6 7.5 7.5 8516 66 Lismore 132/66 STS Lismore Sw Stn 62 16.3 16.3 16.6 16.6 16.6 69 17.4 17.4 17.6 17.6 17.7 A 30MW generator is located at Broadwater and is connected to the Lismore 132/66 STS at 66 via feeder 0892 to the Lismore 132/66 STS. For Public Release December 2015 Page 23 of 183

2.3.2.3 STS and ZS load forecast SUMMER Lismore Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Alstonville 66/11 20 16/20 22 0.99 8.4 8.2 8.1 8.1 8.0 4.03 2 Ballina 66/11 30 30 33 0.98 23.0 23.2 23.3 23.4 23.5 6.53 4 Ballina 132 132/66 75/112 0 1.00 9.1 9.1 9.2 9.2 9.3 0.00 1 Dunoon 132/11 10 10 11 0.98 5.3 5.2 5.2 5.1 5.1 2.15 8 Ewingsdale 132/11 30/45 30/45 49.5 0.97 13.1 13.1 13.1 13.1 13.1 4.02 16 Kyogle 66/11 8/10 8/10 11 0.93 7.1 7.1 7.1 7.1 7.1 1.88 3 Lennox Head 132/11 16 16 17.6 1.00 3.6 3.6 3.5 3.5 3.5 1.93 6 Lismore 132/66 132/66 80/120 80/120 80/120 264 0.96 71.5 71.5 71.5 71.5 71.5 0.00 3 Lismore East 66/11 15/19/23 15/20/25 25.3 0.97 10.8 10.7 10.6 10.5 10.4 3.70 2 Lismore South 66/11 15/19/25 15/19/23 20/25 52.8 0.92 23.2 22.8 22.4 22.1 21.7 3.10 6 Lismore Uni 66/11 20/30 20/30 33 0.98 15.9 15.9 16.0 16.0 16.0 2.70 6 Mullumbimby 132/11 16 10 11 0.99 5.8 5.7 5.6 5.6 5.5 2.90 3 Suffolk Park 132/11 30 0 0.99 8.7 8.7 8.7 8.7 8.7 2.68 7 Woodburn 66/11 8/10 8/10 11 0.95 5.5 5.5 5.5 5.5 5.5 2.09 5 WINTER Lismore Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Alstonville 66/11 20 16/20 24 1.00 10.5 10.4 10.4 10.3 10.3 4.03 4 Ballina 66/11 30 30 36 0.99 23.0 23.0 23.0 23.0 23.1 6.53 7 Ballina 132 132/66 75/112 0 0.99 11.6 11.5 11.5 11.6 11.6 0.00 4 Dunoon 132/11 10 10 12 1.00 6.2 6.3 6.3 6.3 6.3 2.15 9 Ewingsdale 132/11 30/45 30/45 54 0.99 13.9 13.9 13.9 13.9 13.9 4.02 5 Kyogle 66/11 8/10 8/10 12 0.98 6.4 6.3 6.2 6.2 6.1 1.88 2 Lennox Head 132/11 16 16 19.2 1.00 5.3 5.2 5.2 5.1 5.1 1.93 3 Lismore 132/66 132/66 80/120 80/120 80/120 288 0.96 68.7 68.7 68.7 68.7 68.7 0.00 2 Lismore East 66/11 15/19/23 15/20/25 27.6 0.99 11.4 11.2 11.1 10.9 10.8 3.70 3 Lismore South 66/11 15/19/25 15/19/23 20/25 57.6 0.93 16.0 15.7 15.5 15.3 15.1 3.10 8 Lismore Uni 66/11 20/30 20/30 36 0.99 13.8 13.5 13.4 13.2 13.1 2.70 5 Mullumbimby 132/11 16 10 12 1.00 7.4 7.2 7.1 6.9 6.8 2.90 5 Suffolk Park 132/11 30 0 1.00 10.4 10.4 10.4 10.4 10.4 2.68 9 Woodburn 66/11 8/10 8/10 12 0.98 6.1 6.1 6.1 6.1 6.1 2.09 1 For Public Release December 2015 Page 24 of 183

2.3.2.4 Subtransmission Single Diagram of Lismore area LISMORE AND CASINO DirectLink (Bungalora) (note 1) Mullumbimby Urbenville 9G5 Ewingsdale 9G4 9U6 Suffolk Park Kyogle 9U7 9G3 8403 Dunoon 0894:LME Lismore Uni Lennox Head Bonalbo Tenterfield 8402 Mallanganee Regulator 8401 Mallanganee CASINO n.o 96L 0893 LISMORE 9U9 9U8 9W1 8515 Lismore Sth 8514 n.o 8512 8513 8511 8516 8510 Lismore Sw Stn 0897:LME Lismore East 8502 8503 8507 Alstonville 9G2 Ballina 6501 0892/1 0892 G Broadwater Mill Co-generation 89 967 Rappville n.o Woodburn Koolkhan Notes Coffs Harbour 1) Directlink is privately owned Koolkhan TransGrid Subs Essential Energy Zone s Transmission & Sub-transmission s 330/132 132/66 132/66/33/11 66/11 TransGrid Essential Energy Private 132/66/11 33/11 330 G Generator 132/11 66 Switching Station 132 33 132 66 For Public Release December 2015 Page 25 of 183

2.3.3 Casino Supply Area 2.3.3.1 Description of Casino area The Casino area subtransmission system is supplied from the Essential Energy 132/66 subtransmission substation at Casino which is teed off the TransGrid 132 Tenterfield to Lismore line. On loss of the single 132/66 transformer, 66 supply reverts to Lismore 132/66 substation via the Lismore Casino 66 line (0893). CASINO Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.3.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 96L 132 Feeder Origin Transgrid Casino 132 96L Tee Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Casino ZS 140 25.8 25.8 25.8 25.8 25.8 157 22.4 22.4 22.4 22.4 22.4 6501 66 Casino ZS Rappville Tee 16 1.0 1.0 1.0 1.0 1.0 25 0.9 0.9 0.9 0.9 0.9 8401 33 Casino ZS Mallanganee ZS 4 3.3 3.3 3.3 3.3 3.3 6 3.0 3.0 3.0 3.0 3.0 8402 33 Mallanganee ZS Bonalbo ZS 4 2.0 2.0 2.0 2.0 2.0 6 1.8 1.8 1.8 1.8 1.8 8403 33 Bonalbo ZS Urbenville ZS 4 1.0 1.0 1.0 1.0 1.0 7 1.1 1.1 1.1 1.1 1.1 2.3.3.3 Subtransmission and Zone load forecast SUMMER Casino Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bonalbo 33/11 3 2.5 2.75 0.90 0.7 0.7 0.7 0.7 0.7 0.18 6 Casino 132/66 132/66 35/45/60 0 0.97 25.8 25.6 25.3 25.0 24.8 0.00 6 Casino 66/11 66/11 20/30 20/30 33 0.98 24.0 24.8 24.7 24.5 24.3 3.60 7 Casino 66/33 66/33 8 3.5 3.85 0.97 2.7 2.7 2.7 2.7 2.6 0.00 7 Mallanganee 33/11 5/8 2.5 2.75 0.98 1.1 1.1 1.1 1.1 1.1 0.24 4 Rappville 66/11 5/6.25 5 5.5 0.96 0.8 0.7 0.7 0.6 0.6 0.17 1 Urbenville 33/11 8 2.5 2.75 0.96 0.7 0.7 0.7 0.7 0.7 0.18 7 WINTER Casino Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bonalbo 33/11 3 2.5 3 0.90 0.6 0.6 0.6 0.6 0.6 0.18 7 Casino 132/66 132/66 35/45/60 0 1.00 20.5 20.4 20.4 20.3 20.3 0.00 12 Casino 66/11 66/11 20/30 20/30 36 1.00 18.5 19.4 19.3 19.3 19.2 3.60 8 Casino 66/33 66/33 8 3.5 4.2 0.99 2.8 2.8 2.8 2.8 2.8 0.00 16 Mallanganee 33/11 5/8 2.5 3 1.00 1.2 1.2 1.2 1.2 1.2 0.24 21 Rappville 66/11 5/6.25 5 6 0.98 0.9 0.9 0.9 0.9 0.9 0.17 9 Urbenville 33/11 8 2.5 3 0.99 0.8 0.8 0.8 0.8 0.8 0.18 3 2.3.3.4 Subtransmission Single Diagram of Casino area See the Lismore diagram on Page 25. For Public Release December 2015 Page 26 of 183

2.3.4 Grafton Supply Area 2.3.4.1 Description of Grafton area The Grafton area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Koolkhan. GRAFTON Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.4.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 825 66 826 66 Feeder Origin TransGrid Koolkhan 132/66 STS TransGrid Koolkhan 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Koolkhan ZS 62 17.9 17.9 17.9 17.9 17.9 69 16.4 16.4 16.4 16.4 16.4 Grafton North ZS 61 14.6 14.6 14.6 14.6 14.6 68 13.0 13.0 13.0 13.0 13.0 6503 66 Grafton North ZS South Grafton ZS 14 9.5 9.5 9.5 9.5 9.5 21 7.6 7.6 7.6 7.6 7.6 6504 66 Five Mile Sw Stn South Grafton ZS 61 4.1 4.1 4.1 4.1 4.1 68 3.3 3.3 3.3 3.3 3.3 6505 66 Koolkhan SS Grafton ZS 52 15.9 15.9 15.9 15.9 15.9 58 14.1 14.1 14.1 14.1 14.1 6506 66 Shannon Creek ZS Nymboida ZS 14 0.3 0.3 0.3 0.3 0.3 21 0.4 0.4 0.4 0.4 0.4 6508 66 Maclean ZS Yamba ZS 28 9.3 9.3 9.2 9.2 9.2 32 10.2 10.1 10.1 10.0 10.0 6509 66 Shannon Creek ZS Five Mile Sw Stn 14 1.1 1.1 1.1 1.1 1.1 21 1.1 1.1 1.1 1.1 1.1 6510 66 Grafton North ZS Five Mile Sw Stn 15 5.2 5.2 5.2 5.2 5.2 25 4.1 4.1 4.1 4.1 4.1 896:MLN 66 8G1 66 TransGrid Koolkhan 132/66 STS TransGrid Koolkhan 132/66 STS Maclean ZS 21 8.5 8.5 8.5 8.5 8.5 25 7.9 7.9 7.9 7.9 7.9 Maclean ZS 68 10.9 10.9 10.9 10.9 10.9 68 10.0 10.0 10.0 10.0 10.0 6402 33 Maclean ZS Yamba Tee 8 0.4 0.4 0.4 0.4 0.4 9 0.3 0.3 0.3 0.3 0.3 6403 33 Yamba Tee Redcliff ZS 3 0.4 0.4 0.4 0.4 0.4 5 0.4 0.4 0.4 0.4 0.4 6404 33 Yamba Tee Yamba ZS 10 0.0 0.0 0.0 0.0 0.0 12 0.0 0.0 0.0 0.0 0.0 For Public Release December 2015 Page 27 of 183

2.3.4.3 STS and ZS load forecast SUMMER Grafton Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Grafton North 66/11 24/30 15/20/25 27.5 0.98 16.3 16.2 16.2 16.1 16.1 2.80 6 Grafton South 66/11 15/19/25 15/19/24.5 26.95 0.94 17.6 17.6 17.6 17.7 17.7 3.68 3 Koolkhan 11 66/11 7.5/10 0 0.99 2.6 2.6 2.6 2.6 2.6 0.55 1 Maclean 66/11 66/11 16 16 17.6 1.00 7.5 7.5 7.5 7.5 7.5 2.23 2 Maclean 66/33 66/33 8/10 0 0.95 0.4 0.4 0.4 0.4 0.4 0.00 3 Nymboida 66/11 0.6 0.6 0.66 0.98 0.4 0.4 0.3 0.3 0.3 0.13 5 Redcliff 33/11 0.5 0.5 0.55 0.95 0.4 0.4 0.4 0.4 0.4 0.08 3 Yamba 66/11 20/30 15/19/23 25.3 1.00 9.3 9.3 9.2 9.2 9.2 2.49 3 WINTER Grafton Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Grafton North 66/11 24/30 15/20/25 30 1.00 11.8 11.4 11.1 10.9 10.6 2.80 2 Grafton South 66/11 15/19/25 15/19/24.5 29.4 0.98 14.0 14.0 14.1 14.1 14.1 3.68 8 Koolkhan 11 66/11 7.5/10 0 0.99 2.4 2.4 2.4 2.4 2.4 0.55 1 Maclean 66/11 66/11 16 16 19.2 0.99 8.1 8.2 8.3 8.5 8.6 2.23 2 Maclean 66/33 66/33 8/10 0 0.95 0.3 0.3 0.3 0.3 0.3 0.00 2 Nymboida 66/11 0.6 0.6 0.72 0.95 0.5 0.5 0.5 0.5 0.5 0.13 Redcliff 33/11 0.5 0.5 0.6 0.95 0.3 0.3 0.3 0.3 0.3 0.08 2 Yamba 66/11 20/30 15/19/23 27.6 0.99 10.2 10.1 10.1 10.0 10.0 2.49 4 For Public Release December 2015 Page 28 of 183

2.3.4.4 Subtransmission Single Diagram of Grafton area TransGrid Subs 132/66 Private P GRAFTON Casino via Rappville Lismore 6501 Lismore 89 967 0896:MLN Koolkhan 0825 KOOLKHAN 6505 0826 Grafton Nth 966 6503 6510 Grafton Sth Shannon Ck P 6509 6504 Five Mile (note 1) Armidale Coffs Harbour Nymboida 6506 G n.o Essential Energy Zone s 66/11/6.6 G Nymboida Hydro Generation Maclean 6508 Yamba n.o. 8G1 6404 6402 6403 Redcliff 96H Coffs Harbour Notes 1) Five Mile is three pole mounted 66 ABS s. Transmission & Sub-transmission s TransGrid Essential Energy 330 66 132 33 66/33/11 66/11 33/11 For Public Release December 2015 Page 29 of 183

2.3.5 Coffs Harbour Supply Area 2.3.5.1 Description of Coffs Harbour area The Coffs Harbour area subtransmission system is supplied from the TransGrid 330/132/66 subtransmission substation at Coffs Harbour (Karangi). The Dorrigo substation is normally connected via the Essential Energy 132 tee line from the TransGrid 132 transmission line between Armidale and Coffs Harbour with back up from the 66 system. Boambee South is an Essential Energy 132/66/11 substation that is supplied by the TransGrid 132 transmission network between Kempsey and Coffs Harbour. COFFS HARBOUR Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.5.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 96C/2(D) 132 Feeder Origin TransGrid 96C Armidale Coffs Harbour Dorrigo Tee Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Dorrigo ZS 122 2.1 2.1 2.1 2.1 2.1 137 2.6 2.6 2.6 2.6 2.6 702 66 Boambee South 132/66 STS Sawtell ZS 61 7.5 7.6 7.8 7.9 8.1 68 7.9 8.0 8.1 8.2 8.2 705 66 706 66 TransGrid Coffs Harbour 132/66 STS TransGrid Coffs Harbour 132/66 STS South Coffs ZS 52 13.6 13.8 13.8 13.8 13.9 58 13.0 13.0 13.0 13.0 13.2 South Coffs ZS 52 15.4 15.7 15.7 15.7 15.7 58 14.7 14.7 14.7 14.7 15.0 7501 66 Nana Glen ZS Woolgoolga ZS 29 5.1 5.2 5.2 5.2 5.2 33 4.8 4.8 4.8 4.8 4.9 7502 66 Nana Glen ZS Ulong ZS 9 0.6 0.6 0.6 0.6 0.6 15 0.6 0.6 0.6 0.6 0.6 7503 66 Ulong ZS Dorrigo ZS 9 0.0 0.0 0.0 0.0 0.0 15 0.0 0.0 0.0 0.0 0.0 7509 66 Moonee ZS Woolgoolga ZS 30 8.2 8.4 8.5 8.7 8.8 36 10.0 9.9 9.9 9.9 9.8 7510 66 North Coffs ZS Moonee ZS 61 6.6 6.7 6.7 6.7 6.7 68 6.3 6.3 6.3 6.3 6.4 703:NGN 66 711:CHN 66 TransGrid Coffs Harbour 132/66 STS TransGrid Coffs Harbour 132/66 STS Nana Glen ZS 62 8.3 8.4 8.4 8.4 8.5 69 7.9 7.9 7.9 7.9 8.1 North Coffs ZS 62 16.7 17.0 17.0 17.0 17.0 69 15.9 15.9 15.9 15.9 16.2 87C 66 North Coffs ZS South Coffs ZS 68 10.4 10.6 10.6 10.6 10.6 68 9.9 9.9 9.9 9.9 10.1 For Public Release December 2015 Page 30 of 183

2.3.5.3 STS and ZS load forecast SUMMER Coffs Harbour Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Boambee South 11 132/66/11 60/30/30 33 0.99 8.0 8.2 8.4 8.5 8.7 2.00 42 Boambee South 66 132/66/11 60/30/30 33 0.99 7.1 7.2 7.2 7.3 7.3 0.00 3 Coffs Harbour North 66/11 15/19/23 15/20/25 15/19/23 50.6 1.00 21.5 21.4 21.3 21.3 21.2 3.18 2 Coffs Harbour South 66/11 20/30 20/30 33 0.96 21.2 20.9 20.7 20.5 20.3 2.30 10 Dorrigo 132/11, 66/11 10 5 5.5 0.95 2.1 2.1 2.1 2.1 2.1 0.68 11 Moonee 66/11 10/16 10/16 17.6 0.98 3.6 3.6 3.6 3.6 3.6 1.30 5 Nana Glen 66/11 5/6.25 8 6.875 0.95 2.7 2.7 2.7 2.6 2.6 0.84 1 Sawtell 66/11 15/19/25 15/19/25 27.5 1.00 7.5 7.6 7.8 7.9 8.1 1.65 3 Ulong 66/11.4 1 0 0.71 0.3 0.3 0.3 0.3 0.3 0.10 8 Woolgoolga 66/11 20/30 20/30 33 1.00 8.2 8.4 8.5 8.7 8.8 3.01 3 WINTER Coffs Harbour Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Boambee South 11 132/66/11 60/30/30 36 1.00 9.8 9.8 9.8 9.8 9.8 2.00 4 Boambee South 66 132/66/11 60/30/30 36 1.00 7.7 7.7 7.7 7.7 7.8 0.00 4 Coffs Harbour North 66/11 15/19/23 15/20/25 15/19/23 55.2 1.00 20.1 20.1 20.1 20.1 20.1 3.18 6 Coffs Harbour South 66/11 20/30 20/30 36 0.99 16.7 16.7 16.7 16.7 16.7 2.30 9 Dorrigo 132/11, 66/11 10 5 6 0.95 2.6 2.6 2.6 2.6 2.6 0.68 9 Moonee 66/11 10/16 10/16 19.2 0.99 4.4 4.3 4.2 4.2 4.1 1.30 3 Nana Glen 66/11 5/6.25 8 7.5 0.95 2.4 2.3 2.3 2.2 2.2 0.84 6 Sawtell 66/11 15/19/25 15/19/25 30 1.00 7.9 8.0 8.1 8.2 8.2 1.65 5 Ulong 66/11.4 1 0 0.89 0.3 0.3 0.3 0.3 0.3 0.10 3 Woolgoolga 66/11 20/30 20/30 36 1.00 10.0 9.9 9.9 9.9 9.8 3.01 7 For Public Release December 2015 Page 31 of 183

2.3.5.4 Subtransmission Single Diagram of Coffs Harbour area COFFS HARBOUR AND NAMBUCCA HEADS Koolkhan Lismore 96H 89 7501 Woolgoolga 7509 Ulong Nana Glen 7502 703:NGN COFFS HARBOUR 711:CHN Moonee 7510 Coffs Harbour North 87 96C/1(C) 706 87C Armidale 96C/2(D) 96C/1(A) Dorrigo 9W3 7503 Boambee South n.o. double-circuit Raleigh Coffs Harbour South 9W8 705 Sawtell 702 9W7 NAMBUCCA HEADS 751 Nambucca Heads 9W6 Macksville double-circuit 9W2 9W5 Kempsey TransGrid s Essential Energy Zone s Transmission & Sub-trans. s TransGrid Essential Energy 330/132/66 132/66/11 66/11 132/66 132/11 330 132 66 132 For Public Release December 2015 Page 32 of 183

2.3.6 Nambucca Heads Supply Area 2.3.6.1 Description of Nambucca Heads area The Nambucca Heads area subtransmission system is supplied from the TransGrid 132 transmission network. Nambucca Heads is a 66/11 substation supplied via a 66 line from TransGrid s Nambucca 132/66 substation, while Raleigh and Macksville are 132/11 substations supplied from the TransGrid 132 transmission network between Kempsey and Coffs Harbour. NAMBUCCA HEADS Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.6.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 751 66 Feeder Origin TransGrid Nambucca 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Nambucca ZS 15 5.9 5.7 5.6 5.5 5.5 25 7.6 7.4 7.2 7.1 6.9 2.3.6.3 STS and ZS load forecast SUMMER Nambucca Heads Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Macksville 132/11 24/30 24/30 33 0.97 8.3 8.2 8.2 8.2 8.2 2.45 7 Nambucca Heads 66/11 15/19/23 17/22/24 25.3 0.99 5.9 5.7 5.6 5.5 5.5 1.78 1 Raleigh 132/11 30 30 33 0.97 8.7 8.8 8.9 8.9 9.0 2.83 3 WINTER Nambucca Heads Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Macksville 132/11 24/30 24/30 36 0.99 9.8 9.8 9.8 9.9 9.9 2.45 10 Nambucca Heads 66/11 15/19/23 17/22/24 27.6 1.00 7.6 7.4 7.2 7.1 6.9 1.78 13 Raleigh 132/11 30 30 36 0.99 9.6 9.5 9.4 9.4 9.3 2.83 7 2.3.6.4 Subtransmission Single Diagram of Nambucca Heads area See the Coffs Harbour diagram on Page 32. For Public Release December 2015 Page 33 of 183

2.3.7 Kempsey Supply Area 2.3.7.1 Description of Kempsey area The Kempsey area subtransmission system is supplied from the TransGrid 132/66/33 subtransmission substation at Kempsey. KEMPESY Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.7.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 7R1 33 7R2/1 33 Feeder Origin TransGrid Kempsey 132/33 STS TransGrid Kempsey 132/33 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Prince St ZS 30 6.0 6.0 6.2 6.2 6.2 34 6.7 6.7 6.7 6.9 6.9 North St Tee 26 6.9 6.9 7.2 7.2 7.2 29 7.4 7.4 7.4 7.7 7.7 7R2/2 33 North St Tee Smithtown ZS 19 3.5 3.5 3.6 3.6 3.6 21 4.3 4.3 4.3 4.5 4.5 7R2/3 33 North St Tee North St ZS 10 3.4 3.4 3.6 3.6 3.6 19 3.0 3.0 3.0 3.1 3.1 7R3 33 7R4 33 7R5 33 TransGrid Kempsey 132/33 STS TransGrid Kempsey 132/33 STS TransGrid Kempsey 132/33 STS Prince St ZS 26 6.0 6.0 6.3 6.3 6.3 29 6.7 6.7 6.7 6.9 6.9 Munga ZS 3 1.1 1.1 1.1 1.1 1.1 4 1.1 1.1 1.1 1.0 1.0 North St ZS 19 5.3 5.3 5.5 5.5 5.5 21 5.6 5.6 5.6 5.8 5.8 7R6/1 33 Prince St ZS Smithtown Tee 15 4.4 4.4 4.6 4.6 4.6 18 5.3 5.3 5.3 5.4 5.4 7R6/2 33 Smithtown Tee South West Rocks ZS 15 2.2 2.2 2.3 2.3 2.3 18 2.7 2.7 2.7 2.8 2.8 7R6/3 33 Smithtown Tee Smithtown ZS 15 2.1 2.1 2.1 2.1 2.1 18 2.4 2.4 2.4 2.5 2.5 7R7 33 Prince St ZS Crescent Head ZS 5 1.4 1.4 1.4 1.4 1.4 8 1.8 1.8 1.8 1.8 1.8 7R8 33 Smithtown ZS South West Rocks ZS 30 2.6 2.6 2.7 2.7 2.7 34 3.2 3.2 3.2 3.3 3.3 For Public Release December 2015 Page 34 of 183

2.3.7.3 STS and ZS load forecast SUMMER Kempsey Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Crescent Head 33/11 2.5/3.25 5 3.575 0.96 1.4 1.4 1.4 1.4 1.4 0.34 2 Munga 33/11 2.5/3.25 3 3.3 0.98 1.1 1.1 1.1 1.1 1.1 0.49 1 North St 33/11 10 10 11 0.95 9.6 9.5 9.4 9.3 9.2 1.67 7 Prince St 33/11 10/15 10/15 16.5 0.91 7.6 7.5 7.4 7.4 7.3 1.70 9 Smithtown 33/11 5/6.5 5 5.5 0.93 4.2 4.2 4.2 4.2 4.2 0.65 30 South West Rocks 33/11 10/12.5 16 13.75 1.00 5.3 5.3 5.3 5.3 5.3 1.56 3 WINTER Kempsey Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Crescent Head 33/11 2.5/3.25 5 3.9 0.98 1.8 1.8 1.8 1.8 1.8 0.34 4 Munga 33/11 2.5/3.25 3 3.6 1.00 1.1 1.1 1.1 1.0 1.0 0.49 8 North St 33/11 10 10 12 0.99 9.5 9.4 9.3 9.3 9.2 1.67 13 Prince St 33/11 10/15 10/15 18 0.96 7.0 7.0 7.0 7.0 7.0 1.70 3 Smithtown 33/11 5/6.5 5 6 0.97 3.9 3.9 3.9 3.9 3.9 0.65 3 South West Rocks 33/11 10/12.5 16 15 1.00 6.1 6.1 6.1 6.1 6.1 1.56 5 For Public Release December 2015 Page 35 of 183

2.3.7.4 Subtransmission Single Diagram of Kempsey area KEMPSEY Raleigh Macksville Armidale 965 9W2 9W5 double-circuit Munga South West Rocks 7R8 Smithtown North St. 7R4 7R5 7R2 7R6 n.o. 7R1 KEMPSEY Prince St. 7R3 7R7 96G 9W9 Crescent Head Port Macquarie TransGrid s Essential Energy Zone s Transmission & Sub-trans. s 132/66/33 33/11 TransGrid Essential Energy 132 33 For Public Release December 2015 Page 36 of 183

2.3.8 Port Macquarie Supply Area 2.3.8.1 Description of Port Macquarie area The Port Macquarie area subtransmission system is supplied from the TransGrid 132/33 subtransmission substation at Port Macquarie. PORT MACQUARIE Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.8.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 70Y 33 Rocks Ferry ZS Telegraph Point ZS 8 1.3 1.2 1.2 1.2 1.2 12 1.5 1.4 1.4 1.4 1.4 701 33 703:BPM 33 707 33 708 33 710 33 711:CPM 33 712 33 TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS TransGrid Port Macquarie 132/33 STS Rocks Ferry ZS 22 8.8 8.9 8.9 8.9 9.1 26 8.8 8.9 8.9 8.9 9.1 Boronia Street ZS 26 7.2 7.4 7.4 7.4 7.5 29 7.5 7.6 7.6 7.6 7.7 Boronia Street ZS 26 8.2 8.3 8.3 8.3 8.5 29 8.5 8.6 8.6 8.6 8.7 Owen Street ZS 26 9.5 9.7 9.7 9.7 9.8 29 11.0 11.2 11.2 11.2 11.3 Clearwater ZS 31 10.3 10.5 10.5 10.5 10.7 34 12.7 12.9 12.9 12.9 13.0 Clearwater ZS 20 10.3 10.5 10.5 10.5 10.6 20 12.6 12.8 12.8 12.8 13.0 Rocks Ferry ZS 12 5.8 5.9 5.9 5.9 6.0 14 5.8 5.9 5.9 5.9 6.0 715 33 Clearwater ZS Owen Street ZS 31 4.3 4.4 4.4 4.4 4.5 34 3.5 3.5 3.5 3.5 3.6 719/1 33 Clearwater ZS Lake Cathie ZS 20 3.7 3.7 3.7 3.7 3.7 22 5.3 5.5 5.7 5.8 5.9 719/2 33 Lake Cathie ZS Laurieton ZS 12 0.0 0.0 0.0 0.0 0.0 14 0.0 0.0 0.0 0.0 0.0 765 33 Rocks Ferry ZS Koree ZS 9 3.9 4.0 4.0 4.0 4.0 11 4.4 4.4 4.4 4.4 4.5 784 33 Koree ZS Byabarra ZS 9 1.0 1.0 1.0 1.0 1.1 11 1.0 1.1 1.1 1.1 1.1 For Public Release December 2015 Page 37 of 183

2.3.8.3 STS and ZS load forecast SUMMER Port Macquarie Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Boronia St 33/11 20/30 20/30 33 0.94 17.6 17.0 16.5 16.1 15.7 3.20 5 Byabarra 33/11 2.5/3 2.5 2.75 0.90 1.3 1.3 1.3 1.3 1.3 0.39 3 Clearwater Cr 33/11 20/30 20/30 33 1.00 11.3 11.2 11.2 11.1 11.1 4.82 3 Koree Island 33/11 5/8 3.5 3.85 0.95 1.4 1.4 1.4 1.4 1.4 0.71 1 Lake Cathie 33/11 5 10/16 5.5 0.97 3.7 3.7 3.7 3.7 3.7 1.48 6 Owen St 33/11 15/20 15/20 22 0.98 13.9 13.9 14.0 14.0 14.1 1.54 27 Rocks Ferry 33/11 10/16 10/15 16.5 0.96 8.7 8.6 8.5 8.4 8.3 2.92 6 Telegraph Point 33/11 3/4 4 4.4 0.97 1.3 1.2 1.2 1.2 1.2 0.51 5 WINTER Port Macquarie Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Boronia St 33/11 20/30 20/30 36 0.99 16.6 16.4 16.2 16.1 16.0 3.20 7 Byabarra 33/11 2.5/3 2.5 3 0.94 1.2 1.2 1.2 1.2 1.2 0.39 13 Clearwater Cr 33/11 20/30 20/30 36 1.00 17.6 17.6 17.6 17.5 17.5 4.82 7 Koree Island 33/11 5/8 3.5 4.2 0.99 1.3 1.3 1.3 1.3 1.3 0.71 4 Lake Cathie 33/11 5 10/16 6 0.99 5.3 5.5 5.7 5.8 5.9 1.48 4 Owen St 33/11 15/20 15/20 24 0.96 16.5 16.5 16.5 16.5 16.4 1.54 12 Rocks Ferry 33/11 10/16 10/15 18 0.99 8.9 8.8 8.7 8.7 8.6 2.92 7 Telegraph Point 33/11 3/4 4 4.8 0.99 1.5 1.4 1.4 1.4 1.4 0.51 7 For Public Release December 2015 Page 38 of 183

2.3.8.4 Subtransmission Single Diagram of Port Macquarie area Byabarra 132/33 P Private Sub 784 Koree Island P HMC Pumps PORT MACQUARIE Kempsey Telegraph Point 96G 9W9 Rocks Ferry 765 70Y 712 PORT MACQUARIE 703:BPM 701 707 710 711:CPM 708 Boronia St n.o. 708 Owen St 715 Clearwater Cres P HMC Pumps double-circuit 964 719 Lake Cathie 719 Taree Laurieton N/O TransGrid s Essential Energy Zone s Transmission & Sub-trans. s TransGrid Essential Energy 33/11 66/33/11 132 33 For Public Release December 2015 Page 39 of 183

2.3.9 Herons Creek Supply Area 2.3.9.1 Description of Herons Creek area The Herons Creek 132/66 substation is owned by Essential Energy. It receives supply via a tee off TransGrid s Taree Port Macquarie 132 line (#964). Johns River, Kew and Laurieton 66/11 zone substations take normal 66 supply from Herons Creek, and backup 66 supply from TransGrid s Taree 132/66/33 substation via the Essential Energy 66 line (#862). HERONS CREEK Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.9.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 866:KEW 66 Feeder Origin Herons Creek 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Kew ZS 16 9.5 9.5 9.5 9.5 9.5 25 10.2 10.2 10.2 10.2 10.2 871 66 Kew ZS Laurieton ZS 36 6.5 6.6 6.6 6.6 6.6 42 7.7 7.7 7.7 7.7 7.7 862/1 66 Kew ZS Johns River ZS 16 0.9 0.9 0.9 0.9 0.9 25 1.0 1.0 1.0 1.0 1.0 862/2 66 TransGrid Taree 132/66/33 STS Johns River ZS 16 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 2.3.9.3 STS and ZS load forecast SUMMER Herons Creek Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Herons Creek 132/66 60 0 0.92 9.0 9.0 9.0 9.0 9.0 0.00 7 Johns River 66/11 3 0 0.88 0.9 0.9 0.9 0.9 0.9 0.31 12 Kew 66/11 5 8 5.5 0.94 3.7 3.6 3.6 3.5 3.5 0.84 5 Laurieton 66/11, 33/11 15/20 15/20 22 0.96 6.5 6.6 6.6 6.6 6.6 2.73 4 WINTER Herons Creek Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Herons Creek 132/66 60 0 0.97 10.1 10.1 10.1 10.1 10.1 0.00 3 Johns River 66/11 3 0 0.96 1.0 1.0 1.0 1.0 1.0 0.31 10 Kew 66/11 5 8 6 0.98 3.4 3.4 3.4 3.4 3.4 0.84 2 Laurieton 66/11, 33/11 15/20 15/20 24 0.98 7.7 7.7 7.7 7.7 7.7 2.73 1 2.3.9.4 Subtransmission Single Diagram of Herons Creek area See the Taree diagram on Page 43. For Public Release December 2015 Page 40 of 183

2.3.10 Taree Supply Area 2.3.10.1 Description of Taree area The Taree area subtransmission system is supplied from the TransGrid 132/66/33 subtransmission substation at Taree. Whitbread St is a three transformer zone substation and is supplied via two 66 feeders which are transformer ended. However manual switching is required to energise the third transformer. TAREE Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.10.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 861 66 863:WTE 66 867 66 Feeder Origin TransGrid Taree 132/66/33 STS TransGrid Taree 132/66/33 STS TransGrid Taree 132/66/33 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Whitbread ZS 62 9.9 9.9 10.1 10.1 10.1 69 7.7 7.7 7.9 7.9 7.9 Whitbread ZS 62 10.2 10.2 10.4 10.4 10.4 69 7.9 7.9 8.1 8.1 8.1 Failford ZS 34 12.3 12.3 12.6 12.6 12.6 39 13.5 13.5 13.8 13.8 13.8 867/1 66 Failford ZS Tuncurry ZS 39 9.8 9.8 12.6 12.6 12.6 43 11.2 11.2 13.8 13.8 13.8 868 66 TransGrid Taree 132/66/33 STS Bohnock Tee 36 17.3 17.3 17.7 17.7 17.7 41 19.6 19.6 20.0 20.0 20.0 868/2 66 Bohnock Tee Bohnock ZS 16 4.0 4.0 4.0 4.0 4.0 26 5.8 5.8 5.8 5.8 5.8 868 66 Bohnock Tee Hallidays Point ZS 38 12.3 12.3 12.5 12.5 12.5 43 13.2 13.2 13.5 13.5 13.5 872 66 Tuncurry ZS Forster ZS 30 6.6 6.6 6.7 6.7 6.7 37 7.7 7.7 7.8 7.8 7.8 86C 66 Tuncurry ZS Forster ZS 42 5.8 5.8 5.9 5.9 5.9 46 6.7 6.7 6.9 6.9 6.9 86R 66 Hallidays Point ZS Tuncurry ZS 38 8.0 8.0 8.1 8.1 8.1 43 9.0 9.0 9.2 9.2 9.2 7G2/1 33 TransGrid Taree 132/66/33 STS Kanangra Tee 22 5.1 5.1 5.1 5.1 5.3 27 5.0 5.0 5.0 5.0 5.0 7G2/2 33 Kanangra Tee Coopernook ZS 7 4.3 4.3 4.3 4.3 4.5 12 4.5 4.5 4.5 4.5 4.5 7G2/3 33 Coopernook ZS Harrington ZS 8 2.4 2.5 2.5 2.6 2.6 13 3.0 3.0 3.0 3.0 3.0 7G4 33 Bootawa ZS Wingham ZS 18 2.0 2.0 2.0 2.0 2.1 21 2.2 2.2 2.2 2.2 2.2 7G5 33 1a 33 3a 33 TransGrid Taree 132/66/33 STS TransGrid Taree 132/66/33 STS TransGrid Taree 132/66/33 STS Kanangra Dr ZS 17 7.5 7.5 7.5 7.5 7.8 17 7.4 7.4 7.4 7.4 7.4 Bootawa ZS 17 5.5 5.5 5.5 5.5 5.7 19 4.9 4.9 4.9 4.9 4.9 Wingham ZS 18 5.7 5.7 5.7 5.7 6.0 20 5.4 5.4 5.4 5.4 5.4 For Public Release December 2015 Page 41 of 183

2.3.10.3 STS and ZS load forecast SUMMER Taree Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bohnock 66/11 5/7 5/7 7.7 0.98 4.0 4.0 4.0 4.0 4.0 1.51 2 Bootawa 33/11 5 5 5.5 0.96 2.9 3.0 3.0 3.0 3.0 0.49 6 Coopernook 33/11 5/8 5/6.5 7.15 0.99 2.0 2.0 1.9 1.8 1.8 0.70 6 Failford 66/11 12.5/16 12.5/16 17.6 0.87 3.4 0.0 0.0 0.0 0.0 0.72 4 Forster 66/11 15/20/25 15/20/25 27.5 1.00 12.5 12.6 12.6 12.6 12.6 2.76 6 Hallidays Point 11 66/11 12/16 12/16 17.6 0.99 1.3 4.3 4.3 4.3 4.3 0.45 2 Harrington 33/11 5/8 5/6.25 6.875 0.98 2.4 2.5 2.5 2.6 2.6 0.94 3 Kanangra Dr 33/11 20/30 20/25 27.5 1.00 9.6 9.6 9.6 9.6 9.6 2.07 2 Tuncurry 66/11 10/16 12.5/16 17.6 0.98 6.5 6.5 6.5 6.5 6.5 1.62 9 Whitbread St 66/11 15/19 20 20 42.9 0.94 19.1 18.7 18.3 17.9 17.6 2.36 6 Wingham 33/11 7.5/10 7.5/10 11 0.95 9.1 8.9 8.7 8.6 8.4 1.79 3 WINTER Taree Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bohnock 66/11 5/7 5/7 8.4 0.98 5.8 5.8 5.8 5.8 5.8 1.51 9 Bootawa 33/11 5 5 6 0.97 3.5 3.5 3.5 3.5 3.5 0.49 1 Coopernook 33/11 5/8 5/6.5 7.8 0.98 2.0 2.0 2.0 2.0 1.9 0.70 10 Failford 66/11 12.5/16 12.5/16 19.2 0.95 2.6 0.0 0.0 0.0 0.0 0.72 6 Forster 66/11 15/20/25 15/20/25 30 1.00 15.2 15.2 15.2 15.2 15.2 2.76 2 Hallidays Point 11 66/11 12/16 12/16 19.2 0.98 1.8 4.9 4.9 4.9 4.9 0.45 Harrington 33/11 5/8 5/6.25 7.5 0.99 3.0 3.0 3.0 3.0 3.0 0.94 3 Kanangra Dr 33/11 20/30 20/25 30 1.00 10.0 10.1 10.1 10.2 10.2 2.07 3 Tuncurry 66/11 10/16 12.5/16 19.2 0.98 8.8 8.8 8.9 8.9 8.9 1.62 3 Whitbread St 66/11 15/19 20 20 46.8 0.96 15.2 15.0 14.9 14.8 14.7 2.36 3 Wingham 33/11 7.5/10 7.5/10 12 0.95 7.4 7.4 7.3 7.2 7.2 1.79 5 For Public Release December 2015 Page 42 of 183

2.3.10.4 Subtransmission Single Diagram of Taree area Wingham 7G4 Bootawa 96P 963 Stroud Tomago 132/66/33 TAREE 964 Coopernook 3a TAREE 7G2 7G5 n.o. Kanangra Drive 1a 861 863: WTE 868 868/2 Whitbread St 867 868 Failford Hallidays Point 867/1 86R Tuncurry 86C 872 Forster 66/33/11 66/11 Port Macquarie 866 Kew HERONS CREEK 871 n.o. Lake Cathie Johns River Laurieton 862 7G2 Harrington Bohnock TransGrid s Essential Energy Zone s Transmission & Sub-trans. s 33/11 TransGrid Essential Energy 132 132 132/66 66 33 For Public Release December 2015 Page 43 of 183

2.3.11 Stroud Supply Area 2.3.11.1 Description of Stroud area The Stroud 132/33 subtransmission substation is owned by Essential Energy. It receives supply via two TransGrid 132 lines. Subtransmission supply to Martins Creek and Gresford is taken from Stroud, with a secondary supply point at Thornton. The 33 subtransmission line is partly owned by Essential Energy. STROUD Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.11.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 STR4B2 33 Stroud 132/33 STS Dungog ZS 27 21.4 21.4 21.4 21.4 21.4 27 20.2 20.2 20.2 20.2 20.2 STR4B2/2 33 Dungog ZS Martins Creek ZS 21 32.0 32.2 32.3 32.4 32.5 27 33.0 33.2 33.4 33.6 33.8 STR4B3/1 33 Stroud 132/33 STS Booral ZS 7 4.1 4.1 4.1 4.1 4.1 12 4.9 4.9 4.9 4.9 4.9 STR4B3/2 33 Booral ZS Bulahdelah ZS 7 3.0 3.0 3.0 3.0 3.0 12 3.6 3.6 3.6 3.6 3.6 STR4B4 33 Stroud 132/33 STS Dungog ZS 4 7.3 7.3 7.3 7.3 7.3 6 6.7 6.7 6.7 6.7 6.7 STR4B5/1 33 Stroud 132/33 STS Wards River Sw Stn 19 5.9 5.9 5.9 5.9 5.9 21 5.4 5.4 5.4 5.4 5.4 STR4B5/2 33 Wards River Sw Stn Stratford Coal 19 7.5 7.5 7.5 7.5 7.5 21 7.2 7.2 7.2 7.2 7.2 STR4B5/3 33 Stratford Coal Gloucester ZS 19 2.3 2.3 2.3 2.3 2.3 21 1.7 1.7 1.7 1.7 1.7 STR4B6/1 33 Stroud 132/33 STS Wards River Sw Stn 19 6.8 6.8 6.8 6.8 6.8 21 6.3 6.3 6.3 6.3 6.3 STR4B6/2 33 Wards River Sw Stn Gloucester ZS 19 4.6 4.6 4.6 4.6 4.6 21 4.0 4.0 4.0 4.0 4.0 STR4B7 33 Stroud 132/33 STS Dungog ZS 7 11.1 11.1 11.1 11.1 11.1 12 12.2 12.2 12.2 12.2 12.2 STR4B8 33 Stroud 132/33 STS Bulahdelah ZS 7 3.8 3.8 3.8 3.8 3.8 12 4.2 4.2 4.2 4.2 4.2 3801 33 Bulahdelah ZS Pacific Palms ZS 7 2.1 2.1 2.1 2.1 2.1 12 5.8 5.8 5.8 5.7 5.7 3803 33 Bulahdelah ZS Bungwahl Sw Stn 7 0.0 0.0 0.0 0.0 0.0 12 0.0 0.0 0.0 0.0 0.0 BLH4B4 33 Bulahdelah ZS Hawks Nest 132/33 STS 7 0.2 0.2 0.2 0.2 0.2 12 0.2 0.2 0.2 0.2 0.2 7J1 33 Ausgrid Recloser 33175 (Patterson) Martins Creek Tee 8 0.0 0.0 0.0 0.0 0.0 10 0.0 0.0 0.0 0.0 0.0 7J1/2 33 Martins Creek Tee Martins Creek ZS 4 2.7 2.7 2.7 2.7 2.7 7 2.5 2.6 2.7 2.8 2.9 7J1/3 33 Martins Creek Tee Gresford ZS 4 29.3 29.5 29.6 29.7 29.8 7 30.5 30.6 30.7 30.8 30.9 For Public Release December 2015 Page 44 of 183

2.3.11.3 STS and ZS load forecast SUMMER Stroud Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Booral 33/11 2.5 2.5 2.75 0.95 1.3 1.1 1.1 1.0 0.9 0.32 5 Bulahdelah 33/11 5/6.5 5/6.5 7.15 0.87 3.0 2.9 2.9 2.9 2.9 0.62 4 Dungog 33/11 10/16 10/16 17.6 1.00 6.2 6.2 6.1 6.1 6.0 1.07 2 Gloucester 33/11 10 10/16 11 1.00 7.3 7.3 7.3 7.2 7.2 1.49 8 Gresford 33/11 5/8 5/6.5 7.15 1.00 2.1 2.1 2.1 2.1 2.1 0.34 8 Martins Creek 33/11 5/8 5/8 8.8 1.00 2.7 2.7 2.7 2.7 2.7 0.50 3 Pacific Palms 33/11 5/8 5/8 8.8 0.98 4.3 4.2 4.2 4.2 4.2 0.84 4 Stroud 132/33 132/33 50/60 50/60 66 1.00 29.3 29.5 29.6 29.7 29.8 0.00 3 Stroud 33/11 33/11 5 5/8 5.5 0.95 2.7 2.7 2.7 2.7 2.7 0.36 5 WINTER Stroud Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Booral 33/11 2.5 2.5 3 0.95 0.8 0.6 0.5 0.5 0.4 0.32 18 Bulahdelah 33/11 5/6.5 5/6.5 7.8 0.92 3.0 3.0 3.0 2.9 2.9 0.62 13 Dungog 33/11 10/16 10/16 19.2 0.97 5.8 5.8 5.8 5.7 5.7 1.07 12 Gloucester 33/11 10 10/16 12 0.98 6.5 6.5 6.5 6.5 6.5 1.49 8 Gresford 33/11 5/8 5/6.5 7.8 0.97 1.5 1.5 1.5 1.5 1.5 0.34 6 Martins Creek 33/11 5/8 5/8 9.6 1.00 2.7 2.8 2.8 2.8 2.8 0.50 5 Pacific Palms 33/11 5/8 5/8 9.6 0.97 4.5 4.5 4.4 4.4 4.4 0.84 9 Stroud 132/33 132/33 50/60 50/60 72 0.99 30.5 30.6 30.7 30.8 30.9 0.00 7 Stroud 33/11 33/11 5 5/8 6 0.95 2.5 2.6 2.7 2.8 2.9 0.36 7 For Public Release December 2015 Page 45 of 183

2.3.11.4 Subtransmission Single Diagram of Stroud area STROUD, HAWKS NEST AND MAITLAND Port Macquarie Gloucester TAREE P 96P STR4B6/2 STR4B5/2 Stratford Coal Wards River (note 1) STR4B6 STR4B5 963(T) Gresford 33 Reg 7J1 n.o. EE 33 Reg Martins Creek Thornton (Ausgrid) Dungog STR4B2/2 9C8 Brandy Hill (Ausgrid) Dual circuit 96F Tomago Booral 963(K) Stroud Road STROUD STR4B3 STR4B8 963(H1) n.o. Bulahdelah HAWKS NEST 7V1 7Y1 P Woodchip n.o. BLH4B4 7Y2 Tea Gardens 3803 3801 n.o. Notes Pacific Palms 1) Wards River is four pole mounted 33 reclosers. Salt Ash (Ausgrid) TransGrid s Essential Energy Zone s Transmission & Sub-transmission s 132/66/33 132/33 33/11 TransGrid Essential Energy 132 33 P Private 33 TransGrid owned Essential Energy operated For Public Release December 2015 Page 46 of 183

2.3.12 Hawks Nest Supply Area 2.3.12.1 Description of Hawks Nest area The Hawks Nest 132/33 subtransmission substation is owned by Essential Energy. It receives supply via a tee off the TransGrid Tomago to Taree 132 line (#963). Tea Gardens zone substation takes normal supply from the Hawks Nest 132/33 substation. Tea Gardens zone substation takes backup supply from a 33 subtransmission line that emanates from Ausgrid s Tomago network. A partial backup supply for Tea Gardens is via the 33 network emanating from the Stroud substation via Bulahdelah. HAWKS NEST Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.3.12.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 7Y1 33 7Y2 33 Feeder Origin Hawks Nest 132/33 STS Hawks Nest 132/33 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Tea Gardens ZS 7 4.2 4.2 4.2 4.2 4.2 12 4.2 4.2 4.2 4.2 4.2 Tea Gardens ZS 7 3.8 3.8 3.8 3.8 3.8 12 3.8 3.8 3.8 3.8 3.8 7V1 33 Ausgrid Salt Ash ZS Tee with 7Y1 7 0.0 0.0 0.0 0.0 0.0 12 0.0 0.0 0.0 0.0 0.0 2.3.12.3 STS and ZS load forecast SUMMER Hawks Nest Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Hawks Nest 132/33 132/33 50 0 0.99 7.6 7.7 7.7 7.8 7.9 0.00 2 Tea Gardens 33/11 10/16 10/16 17.6 1.00 7.4 7.5 7.6 7.6 7.7 1.67 2 WINTER Hawks Nest Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Hawks Nest 132/33 132/33 50 0 0.98 7.1 7.1 7.1 7.1 7.1 0.00 2 Tea Gardens 33/11 10/16 10/16 19.2 1.00 7.0 6.9 6.9 6.9 6.9 1.67 6 2.3.12.4 Subtransmission Single Diagram of Hawks Nest area See the Stroud diagram on Page 46. For Public Release December 2015 Page 47 of 183

2.4 Northern Region 2.4.1 Armidale Supply Area 2.4.1.1 Description of Armidale area The Armidale area subtransmission system is supplied from the TransGrid 330/132/66 subtransmission substation at Armidale. ARMIDALE Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.1.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 661/1 66 TransGrid Armidale 330/132/66 STS Hillgrove Tee 12 0.7 0.8 0.8 0.8 0.8 18 0.8 0.8 0.8 0.8 0.8 661/2 66 Hillgrove Tee Hillgrove ZS 9 0.3 0.3 0.3 0.3 0.3 15 0.4 0.4 0.4 0.4 0.4 661/3 66 Hillgrove Tee Oaky ZS 12 0.5 0.5 0.5 0.5 0.5 18 0.5 0.5 0.5 0.5 0.5 662/1 66 TransGrid Armidale 330/132/66 STS Uralla Tee 15 5.8 6.0 6.0 6.0 6.0 25 6.6 6.6 6.6 6.6 6.6 662/2 66 Uralla Tee Uralla ZS 9 2.0 2.0 2.0 2.0 2.0 15 3.2 3.2 3.1 3.1 3.1 662/3 66 Uralla Tee Walcha ZS 9 2.4 2.5 2.5 2.5 2.5 15 3.3 3.3 3.3 3.3 3.3 662/4 66 Walcha ZS Walcha South ZS 16 1.1 1.1 1.1 1.1 1.1 20 1.4 1.4 1.4 1.4 1.4 664 66 665 66 TransGrid Armidale 330/132/66 STS TransGrid Armidale 330/132/66 STS Galloway St ZS 28 12.0 12.4 12.4 12.4 12.4 34 19.3 19.3 19.3 19.3 19.3 Madgwick Dr ZS 21 8.3 8.6 8.6 8.6 8.6 39 12.4 12.4 12.4 12.4 12.4 66C 66 Miller St ZS Madgwick Dr ZS 21 1.5 1.6 1.6 1.6 1.6 39 3.0 3.0 3.0 3.0 3.0 66F 66 Galloway St ZS Miller St ZS 15 5.5 5.7 5.7 5.7 5.7 25 7.6 7.6 7.6 7.6 7.6 The 5MW hydro generation at Oaky is presently decommissioned after failure of the dam wall. For Public Release December 2015 Page 48 of 183

2.4.1.3 STS and ZS load forecast SUMMER Armidale Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Galloway St 66/11 12.5/16 10/12.5 13.75 0.99 6.5 6.4 6.4 6.4 6.4 1.95 1 Hillgrove 66/11 5/6.25 0 0.75 1.8 1.8 1.8 1.8 1.8 0.08 9 Madgwick Dr 66/11 10/12.5 10/16 13.75 0.99 5.3 5.3 5.3 5.3 5.3 1.22 3 Miller St 66/11 12.5/16 10/16 17.6 0.97 7.9 7.9 7.9 7.9 7.9 1.21 3 Oaky 66/11 3.5 3.5 3.85 0.97 0.3 0.3 0.3 0.3 0.3 0.07 1 Uralla 66/11 5 5 5.5 0.95 2.0 2.0 2.0 2.0 2.0 0.81 4 Walcha 66/11 3.125 3.125 3.4375 0.96 1.0 0.0 0.0 0.0 0.0 0.32 2 Walcha South 66/22 8 10 8.8 0.90 1.0 2.1 2.1 2.1 2.0 0.34 5 WINTER Armidale Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Galloway St 66/11 12.5/16 10/12.5 15 0.99 11.4 11.2 11.1 10.9 10.8 1.95 6 Hillgrove 66/11 5/6.25 0 0.77 1.3 1.3 1.3 1.3 1.3 0.08 5 Madgwick Dr 66/11 10/12.5 10/16 15 0.99 10.3 10.2 10.2 10.1 10.1 1.22 7 Miller St 66/11 12.5/16 10/16 19.2 0.98 10.9 10.9 10.9 10.9 10.9 1.21 4 Oaky 66/11 3.5 3.5 4.2 0.96 0.4 0.4 0.4 0.4 0.4 0.07 Uralla 66/11 5 5 6 0.95 3.2 3.2 3.1 3.1 3.1 0.81 2 Walcha 66/11 3.125 3.125 3.75 0.96 0.0 0.0 0.0 0.0 0.0 0.32 Walcha South 66/22 8 10 9.6 0.92 3.3 3.3 3.3 3.3 3.3 0.34 For Public Release December 2015 Page 49 of 183

2.4.1.4 Subtransmission Single Diagram of Armidale area ARMIDALE Inverell Lismore 96N Glen Innes 89 Madgwick Drive 665 66C Miller St 66F 664 Galloway St Uralla 662 96T/1 661 ARMIDALE Hillgrove 965 P Hillgrove Mine Koolkhan 966 96C/1 n.o G Oaky P.Stn. 85 Tamworth 86 Walcha Walcha South TransGrid s Essential Energy Zone s Transmission & Sub-trans. s 330/132/66 66/11 66/22/11 TransGrid Essential Energy G Generator 330 66 132 Private P Private 66 For Public Release December 2015 Page 50 of 183

2.4.2 Glen Innes Supply Area 2.4.2.1 Description of Glen Innes area The Glen Innes area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Glen Innes. GLEN INNES Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.2.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 886 66 887 66 Feeder Origin TransGrid Glen Innes 132/66 STS TransGrid Glen Innes 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Glen Innes ZS 70 4.2 4.2 4.2 4.2 4.2 78 5.6 5.6 5.6 5.6 5.6 Glen Innes ZS 19 5.0 5.0 5.0 5.0 5.0 33 6.6 6.6 6.6 6.6 6.6 6NY 66 Glen Innes ZS Guyra ZS 11 4.1 4.1 4.1 4.1 4.1 19 4.8 4.8 4.8 4.8 4.7 6NE 66 Glen Innes ZS Emmaville ZS 17 0.8 0.8 0.8 0.8 0.8 30 1.0 1.0 1.0 1.0 1.0 6AE/A 66 Pindari ZS Ashford ZS 17 0.0 0.0 0.0 0.0 0.0 30 0.0 0.0 0.0 0.0 0.0 6AE/E 66 Emmaville ZS Pindari ZS 17 0.3 0.3 0.3 0.3 0.3 30 0.3 0.3 0.3 0.3 0.3 A 5.5MW generator is located at Pindari Dam and is connected to the TransGrid Glen Innes 132/66 STS at 66 via feeders 6AE, 6NE, 886 and 887. 2.4.2.3 STS and ZS load forecast SUMMER Glen Innes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Emmaville 66/11 66/11 3 0 0.95 0.7 0.8 0.8 0.8 0.8 0.50 1 Emmaville 66/22 66/22 2.5 0 0.95 0.1 0.1 0.1 0.1 0.1 0.00 3 Glen Innes 66/11 15/20 15/20 22 0.90 6.0 6.0 6.1 6.1 6.1 1.77 7 Guyra 66/11/22 5 5 5.5 0.76 4.1 4.1 4.1 4.1 4.1 0.70 2 Pindari 66/22 0.3 0 0.98 0.1 0.1 0.1 0.1 0.1 0.01 WINTER Glen Innes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Emmaville 66/11 66/11 3 0 0.95 0.9 1.0 1.0 1.0 1.0 0.50 1 Emmaville 66/22 66/22 2.5 0 0.95 0.3 0.3 0.4 0.5 0.5 0.00 1 Glen Innes 66/11 15/20 15/20 24 0.98 7.6 7.5 7.4 7.4 7.3 1.77 6 Guyra 66/11/22 5 5 6 0.96 4.8 4.8 4.8 4.8 4.7 0.70 6 Pindari 66/22 0.3 0 0.98 0.1 0.1 0.1 0.1 0.1 0.01 For Public Release December 2015 Page 51 of 183

2.4.2.4 Subtransmission Single Diagram of Glen Innes area TABLELANDS Bulli Creek (Ergon) 7235 Waggamba (Ergon) Yelarbon (Qld) 33 regulator Inglewood Goondiwindi (EE, Qld) n.o n.o 3XG 6HG Texas (Qld) 96L Yallaroi 6FH 6AX Tenterfield TENTERFIELD 6FW Warialda 66 Reg Coolatai 6AF/F Wallangra 6AF/A 66 Reg Ashford 6AB n.o Pindari 6AE/A 6AE/E G Pindari Hydro Emmaville 96R Moree 9U2 6NE 6WK 6BW Borthwick St n.o. Wynne St (Redundant) 9U4 dual-circuit Bingara 6BC INVERELL (note 2) Glen Innes (note 1) G Copeton Dam P.Stn. Copeton 6BD 96N 6NY 96T Bundarra Guyra Notes 1) numbers TransGrid to Glen Innes zone :- 886 887 2) numbers TransGrid to Borthwick St :- 734 735 3) number Borthwick St to Wynne St zone :- 6BR Armidale TransGrid s Essential Energy Zone s Transmission & Sub-trans. s 132/66 132/22 22/11 66/22 TransGrid Essential Energy G 132/66/33 Generator 66/11 66/22/11 66/33/22 132 66 33 Connection For Public Release December 2015 Page 52 of 183

2.4.3 Inverell Supply Area 2.4.3.1 Description of Inverell area The Inverell area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Inverell. INVERELL Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.3.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 734 66 735 66 TransGrid Inverell 132/66 STS TransGrid Inverell 132/66 STS Borthwick St ZS 64 17.9 19.9 19.9 19.9 19.9 71 16.9 19.4 19.4 19.4 19.4 Borthwick St ZS 64 18.2 20.2 20.2 20.2 20.2 71 17.2 19.7 19.7 19.7 19.7 6AB 66 Borthwick St ZS Ashford ZS 17 6.5 7.3 7.3 7.3 7.3 30 5.0 5.7 5.7 5.7 5.7 6AF/A 66 Ashford ZS Wallangra ZS 11 0.9 1.0 1.0 1.0 1.0 19 0.9 1.0 1.0 1.0 1.0 6AF/F 66 Wallangra ZS Coolatai Sw Stn 11 0.7 0.8 0.8 0.8 0.8 19 0.8 0.9 0.9 0.9 0.9 6AX 66 Ashford ZS Texas ZS 9 5.4 6.1 6.1 6.1 6.1 15 3.4 3.9 3.9 3.9 3.9 6BC 66 Borthwick St ZS Copeton ZS 21 0.8 0.9 0.9 0.9 0.9 41 0.9 1.0 1.0 1.0 1.0 6BD 66 Borthwick St ZS Bundarra ZS 14 0.9 1.0 1.0 1.0 1.0 21 1.1 1.2 1.2 1.2 1.2 6BR 66 Borthwick St ZS Wynne St ZS 34 0.0 0.0 0.0 0.0 0.0 41 0.0 0.0 0.0 0.0 0.0 6BW 66 Borthwick St ZS Warialda ZS 15 7.2 8.0 8.0 8.0 8.0 25 5.9 6.8 6.8 6.8 6.8 6FH 66 Coolatai Sw Stn Yallaroi ZS 20 2.3 2.5 2.5 2.5 2.5 39 1.9 2.2 2.2 2.2 2.2 6FW 66 Warialda ZS Coolatai Sw Stn 11 1.7 1.9 1.9 1.9 1.9 19 1.2 1.3 1.3 1.3 1.3 6HG 66 Yallaroi ZS Goondiwindi ZS 20 0.0 0.0 0.0 0.0 0.0 39 0.0 0.0 0.0 0.0 0.0 6WK 66 Warialda ZS Bingara ZS 11 2.8 3.1 3.1 3.1 3.1 19 2.5 2.9 2.9 2.9 2.9 A 23MW generator is located at Copeton Dam and is connected to the TransGrid Inverell 132/66 STS at 66 via feeders 6BC, 734 and 735. For Public Release December 2015 Page 53 of 183

2.4.3.3 STS and ZS load forecast SUMMER Inverell Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Ashford 66/22 3 0 0.95 0.6 0.6 0.5 0.5 0.5 0.28 2 Bingara 66/22 3 7.5 3.3 0.95 2.1 2.1 2.1 2.1 2.0 0.46 4 Borthwick St 66/22 30 15/30 33 0.98 20.7 17.7 17.7 17.7 17.7 3.86 4 Bundarra 66/22 3 0 0.77 0.8 0.8 0.8 0.8 0.8 0.20 8 Copeton 66/22 1.5 1.5 1.65 0.98 0.7 0.7 0.7 0.7 0.7 0.00 Texas 66/22 66/22 5 5 5.5 0.95 2.6 2.5 2.5 2.5 2.5 0.21 2 Texas 66/33 66/33 7.5 5 5.5 0.95 2.0 2.0 2.0 2.0 1.9 0.00 3 Wallangra 66/22 1 0 0.90 0.5 0.4 0.4 0.4 0.3 0.05 1 Warialda 66/22 4 8 4.4 0.96 2.9 2.9 2.9 2.9 2.9 0.61 4 Yallaroi 66/22 5 0 0.95 1.7 1.7 1.7 1.7 1.7 0.37 2 WINTER Inverell Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Ashford 66/22 3 0 0.95 0.6 0.6 0.6 0.6 0.6 0.28 4 Bingara 66/22 3 7.5 3.6 0.98 2.1 2.1 2.1 2.1 2.1 0.46 Borthwick St 66/22 30 15/30 36 0.99 23.6 20.6 20.6 20.6 20.6 3.86 4 Bundarra 66/22 3 0 0.69 1.1 1.1 1.1 1.1 1.1 0.20 3 Copeton 66/22 1.5 1.5 1.8 0.95 0.9 0.9 0.9 0.9 0.9 0.00 8 Texas 66/22 66/22 5 5 6 0.95 2.1 2.1 2.2 2.2 2.2 0.21 2 Texas 66/33 66/33 7.5 5 6 0.95 1.2 1.3 1.4 1.4 1.4 0.00 1 Wallangra 66/22 1 0 0.90 0.6 0.6 0.6 0.6 0.6 0.05 2 Warialda 66/22 4 8 4.8 0.92 2.5 2.5 2.5 2.5 2.5 0.61 Yallaroi 66/22 5 0 0.95 1.6 1.6 1.6 1.6 1.7 0.37 7 2.4.3.4 Subtransmission Single Diagram of Inverell area See the Glen Innes diagram on Page 52. For Public Release December 2015 Page 54 of 183

2.4.4 Tenterfield Supply Area 2.4.4.1 Description of Tenterfield area The Tenterfield area is supplied at 22 and 11 from the TransGrid 132/22/11 subtransmission substation at Tenterfield. Essential Energy is responsible for the 22/11 substation area. TENTERFIELD Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.4.2 Subtransmission feeder load forecast There are no subtransmission feeders in the Tenterfield area. 2.4.4.3 STS and ZS load forecast SUMMER TransGrid 132/22 Total Tenterfield 22 Supply Tenterfield Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 5.1 5.1 5.1 5.1 5.1 0.00 Tenterfield 11 22/11 4 4 4.4 0.96 2.0 2.0 2.0 2.0 2.0 1.10 WINTER TransGrid 132/22 Total Tenterfield 22 Supply Tenterfield Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 6.1 6.1 6.1 6.1 6.1 0.00 Tenterfield 11 22/11 4 4 4.8 0.99 2.4 2.4 2.4 2.4 2.4 1.10 2.4.4.4 Subtransmission Single Diagram of Tenterfield area See the Glen Innes diagram on Page 52. For Public Release December 2015 Page 55 of 183

2.4.5 Waggamba (Ergon) Supply Area 2.4.5.1 Description of Waggamba area The Waggamba area subtransmission system is supplied from the Ergon 132/66/33 subtransmission substation at Goondiwindi. The 132/66/33 substation is supplied by a 132 network from Powerlink s Bulli Creek substation. Backup supply to Goondiwindi is limited to a maximum of 20MVA via 66 from Inverell. WAGGAMBA Identified System Limitations SYSTEM LIMITATION On loss of radial 132 supply to Goondiwindi from Ergon and single 132/66/33 transformer, limited backup supply from NSW Refer to DAPR Section Section 3.1 2.4.5.2 Subtransmission feeder load forecast There are no subtransmission feeders in the Waggamba area. 2.4.5.3 STS and ZS load forecast SUMMER Waggamba Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Goondiwindi 22 66/22 20 20/30 22 0.96 13.4 13.4 13.4 13.4 13.4 0.89 6 Goondiwindi 33 66/33 5 0 1.00 4.7 4.6 4.5 4.4 4.3 0.00 8 WINTER Waggamba Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Goondiwindi 22 66/22 20 20/30 24 0.99 14.1 13.8 13.5 13.3 13.1 0.89 7 Goondiwindi 33 66/33 5 0 0.99 4.1 4.0 3.9 3.8 3.7 0.00 5 2.4.5.4 Subtransmission Single Diagram of Waggamba area See the Glen Innes diagram on Page 52. For Public Release December 2015 Page 56 of 183

2.4.6 Moree Supply Area 2.4.6.1 Description of Moree area The Moree area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Moree. MOREE Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.6.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 87J 66 Feeder Origin TransGrid Moree 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Moree Solar Farm 140 1.0 55.0 55.0 55.0 55.0 157 55.1 55.1 55.1 55.1 55.1 876 66 Moree Solar Farm Bellata ZS 25 1.0 1.0 1.0 1.0 1.0 27 0.9 0.9 0.9 0.9 0.9 721 66 722 66 881 66 TransGrid Moree 132/66 STS TransGrid Moree 132/66 STS TransGrid Moree 132/66 STS Moree ZS 64 10.4 10.4 10.4 10.4 10.4 71 10.0 10.0 10.0 10.0 10.0 Moree ZS 64 11.0 11.0 11.0 11.0 11.0 71 10.6 10.6 10.6 10.6 10.6 Ashley ZS 10 2.9 2.9 2.9 2.9 2.9 16 12.2 12.2 12.2 12.2 12.2 6PU/1 66 Ashley ZS Mungindi ZS 10 1.9 1.9 1.9 1.9 1.9 16 5.8 5.8 5.8 5.8 5.8 723:WTR/1 66 TransGrid Moree 132/66 STS Wathagar ZS 12 2.4 2.4 2.4 2.4 2.4 19 5.6 5.6 5.6 5.6 5.6 723:WTR/2 66 Wathagar ZS Wenna ZS 15 0.8 0.8 0.8 0.8 0.8 25 0.9 0.9 0.9 0.9 0.9 2.4.6.3 STS and ZS load forecast SUMMER Moree Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Ashley 66/22 7.5 0 0.96 4.0 4.0 4.0 4.0 4.0 0.43 2 Bellata 66/11 2.8 2.5 2.75 0.93 1.0 1.0 1.0 1.0 1.0 0.33 9 Moree 66/22 15/30 24/30 33 0.99 18.7 18.6 18.5 18.4 18.3 3.95 11 Mungindi 66/22/33 10 7.5 8.25 0.95 1.9 1.9 1.9 1.8 1.8 0.41 3 Wathagar 66/22 5 0 0.95 1.5 1.5 1.6 1.6 1.6 0.14 1 Wenna 66/22 7.5 0 0.98 0.2 0.2 0.2 0.2 0.2 0.04 1 WINTER Moree Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Ashley 66/22 7.5 0 0.98 5.7 5.8 5.8 5.8 5.8 0.43 28 Bellata 66/11 2.8 2.5 3 0.99 0.8 0.8 0.8 0.8 0.8 0.33 4 Moree 66/22 15/30 24/30 36 1.00 20.3 20.3 20.4 20.4 20.5 3.95 9 Mungindi 66/22/33 10 7.5 9 0.95 5.3 5.2 5.2 5.2 5.2 0.41 1 Wathagar 66/22 5 0 0.95 5.2 5.3 5.3 5.3 5.3 0.14 31 Wenna 66/22 7.5 0 0.98 2.2 2.2 2.2 2.2 2.2 0.04 213 For Public Release December 2015 Page 57 of 183

2.4.6.4 Subtransmission Single Diagram of Moree area Limited 33 interconnection Qld/ Ergon WESTERN n.o. Mungindi 6PU Garah 66 Regulator Brewarrina Notes 890:BRE Lightning Ridge Walgett 895:LGR n.o. Merrywinebone 880/2 Burren Junction 861/2 1) numbers from TransGrid to Narrabri zone :- 833:NBI 834:NBI Wenna 885 880/1 723:WTR 66 Reg Wilga Park Wathagar Wee Waa 882 G Moree 96M 879 861/1 721 722 Narrabri Narrabri Coal P Boggabri Emerald Hill Sw Stn 876 Ashley 881 878/2 n.o. G 87J MOREE Bellata 878/3 878/1 Gunnedah Moree SF (Proposed 50MW) NARRABRI (note 1) 9U3 Vickey Mine / Shanon Habour P.Stn G 9U2 88K 877 88L 968 Keepit GUNNEDAH 969 Inverell TAMWORTH TransGrid s Essential Energy Zone s Transmission & Sub-transmission s 330/132 132/66 66/11 66/33/22 TransGrid Essential Energy 132 66 G Generator P Private sub 66/22 66/22/11 66 For Public Release December 2015 Page 58 of 183

2.4.7 Narrabri Supply Area 2.4.7.1 Description of Narrabri area The Narrabri area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Narrabri. NARRABRI Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.7.2 Subtransmission feeder load forecast Feeder # Feeder Voltage Feeder Origin Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 879 66 882 66 TransGrid Narrabri 132/66 STS TransGrid Narrabri 132/66 STS Wee Waa ZS 18 3.3 3.3 3.3 3.3 3.3 22 3.9 3.9 3.9 3.9 4.0 Wee Waa ZS 64 8.7 8.7 8.7 8.7 8.7 71 9.6 9.6 9.6 9.6 9.8 885 66 Burren Junction ZS Merrywinebone ZS 15 1.5 1.5 1.5 1.5 1.5 25 2.3 2.3 2.3 2.3 2.3 833:NBI 66 834:NBI 66 861/1 66 TransGrid Narrabri 132/66 STS TransGrid Narrabri 132/66 STS TransGrid Narrabri 132/66 STS Narrabri ZS 38 8.8 8.8 8.8 8.8 8.8 43 9.9 9.9 9.9 9.9 10.1 Narrabri ZS 38 8.8 8.8 8.8 8.8 8.8 43 9.9 9.9 9.9 9.9 10.1 Wilga Park ZS 64 11.0 11.0 11.0 11.0 11.0 71 10.2 10.2 10.2 10.2 10.4 861/2 66 Wilga Park ZS Walgett ZS 64 13.1 13.1 13.1 13.1 13.1 71 13.0 13.0 13.0 13.0 13.2 878/2 66 Narrabri Coal Tee Boggabri ZS 14 0.0 0.0 0.0 0.0 0.0 21 0.0 0.0 0.0 0.0 0.0 878/3 66 TransGrid Narrabri 132/66 STS Narrabri Coal Tee 61 12.0 12.0 12.0 12.0 12.0 68 12.4 12.4 12.4 12.4 12.6 880/1 66 Wee Waa ZS Burren Junction ZS 10 3.9 3.9 3.9 3.9 3.9 16 4.5 4.5 4.5 4.5 4.6 880/2 66 Burren Junction ZS Walgett ZS 10 0.0 0.0 0.0 0.0 0.0 16 0.0 0.0 0.0 0.0 0.0 890:BRE 66 Walgett ZS Brewarrina ZS 15 2.7 2.7 2.7 2.7 2.7 25 2.3 2.3 2.3 2.3 2.3 895:LGR 66 Walgett ZS Lightning Ridge ZS 15 3.2 3.2 3.2 3.2 3.2 25 3.0 3.0 3.0 3.0 3.1 A 10MW and 6MW generator located at Wilga Park is connected to the TransGrid Narrabri 132/66 STS at 66 via feeder 861. For Public Release December 2015 Page 59 of 183

2.4.7.3 STS and ZS load forecast SUMMER Narrabri Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Brewarrina 66/22 6.5/8 0 1.00 2.3 2.3 2.3 2.3 2.3 0.24 9 Burren Junction 66/22 5 5 5.5 1.00 2.2 2.2 2.2 2.2 2.2 0.28 5 Lightning Ridge 66/22 8 5 5.5 0.99 2.9 2.9 2.8 2.8 2.8 0.60 5 Merrywinebone 66/22 5 0 0.78 2.3 2.3 2.4 2.4 2.5 0.25 5 Narrabri 66/22/11 18/30 18/30 33 0.96 16.9 16.9 17.0 17.0 17.1 3.16 3 Walgett 66/22 10/16 10 11 1.00 4.8 4.8 4.8 4.8 4.8 0.83 3 Wee Waa 132/11, 66/11 10 10 11 0.92 8.1 8.1 8.1 8.1 8.2 0.98 4 WINTER Narrabri Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Brewarrina 66/22 6.5/8 0 0.96 2.1 2.1 2.1 2.1 2.1 0.24 5 Burren Junction 66/22 5 5 6 1.00 1.6 1.6 1.6 1.5 1.5 0.28 4 Lightning Ridge 66/22 8 5 6 1.00 2.6 2.6 2.5 2.5 2.5 0.60 5 Merrywinebone 66/22 5 0 1.00 2.9 2.9 2.9 2.9 3.0 0.25 2 Narrabri 66/22/11 18/30 18/30 36 0.98 19.3 19.4 19.4 19.4 19.4 3.16 20 Walgett 66/22 10/16 10 12 0.98 4.2 4.1 4.1 4.1 4.0 0.83 11 Wee Waa 132/11, 66/11 10 10 12 0.96 9.4 9.3 9.3 9.3 9.3 0.98 4 2.4.7.4 Subtransmission Single Diagram of Narrabri area See the Moree diagram on Page 58. For Public Release December 2015 Page 60 of 183

2.4.8 Gunnedah Supply Area 2.4.8.1 Description of Gunnedah area The Gunnedah area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Gunnedah. GUNNEDAH Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.8.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 877 66 Feeder Origin TransGrid Gunnedah 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Keepit Dam ZS 10 0.2 0.2 0.2 0.2 0.2 16 0.2 0.2 0.2 0.2 0.2 878/1 66 Gunnedah ZS Boggabri ZS 14 4.0 4.0 4.0 4.0 4.0 21 4.4 4.4 4.4 4.4 4.4 88K 66 88L 66 TransGrid Gunnedah 132/66 STS TransGrid Gunnedah 132/66 STS Gunnedah ZS 61 12.8 12.8 12.8 12.8 12.8 68 10.9 10.9 10.9 10.9 10.9 Gunnedah ZS 61 13.0 13.0 13.0 13.0 13.0 68 11.0 11.0 11.0 11.0 11.0 A 7MW generator is located at Lake Keepit and is connected to the TransGrid Gunnedah 132/66 STS at 66 via feeder 877. 2.4.8.3 STS and ZS load forecast SUMMER Gunnedah Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Boggabri 66/11 5/6.5 10 7.15 0.94 2.7 2.7 2.7 2.6 2.6 0.43 5 Gunnedah 22 66/22/11 18/30 18/30 33 1.00 20.4 20.4 20.4 20.4 20.4 2.71 17 Keepit Dam 66/11 1 0 0.91 0.2 0.2 0.3 0.3 0.3 0.00 5 WINTER Gunnedah Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Boggabri 66/11 5/6.5 10 7.8 0.98 2.9 2.9 3.0 3.0 3.1 0.43 16 Gunnedah 22 66/22/11 18/30 18/30 36 1.00 18.3 18.3 18.4 18.5 18.5 2.71 5 Keepit Dam 66/11 1 0 0.94 0.2 0.2 0.2 0.2 0.2 0.00 15 2.4.8.4 Subtransmission Single Diagram of Gunnedah area See the Moree diagram on Page 58. For Public Release December 2015 Page 61 of 183

2.4.9 Tamworth Supply Area 2.4.9.1 Description of Tamworth area The Tamworth area subtransmission system is supplied from the TransGrid 132/66 subtransmission substation at Tamworth. TAMWORTH Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.9.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 801 66 803 66 804 66 806 66 873 66 874 66 Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Oxley Vale ZS 63 12.9 13.0 13.0 13.2 13.3 70 11.8 11.8 11.9 11.9 12.0 South Tamworth ZS 70 24.3 24.5 24.5 24.7 24.9 78 21.8 21.8 22.1 22.1 22.3 Nundle ZS 8 1.8 1.8 1.8 1.8 1.8 13 1.2 1.2 1.2 1.2 1.3 Goddard Lane ZS 38 12.2 12.3 12.3 12.4 12.5 47 8.8 8.8 8.9 8.9 9.0 East Tamworth ZS 53 16.1 16.3 16.3 16.4 16.6 61 12.9 12.9 13.0 13.1 13.2 East Tamworth ZS 53 15.4 15.5 15.5 15.7 15.8 61 12.2 12.2 12.4 12.4 12.5 803/2 66 South Tamworth ZS Oxley Vale ZS 63 1.4 1.4 1.4 1.4 1.5 70 1.5 1.5 1.5 1.5 1.6 806/1 66 Goddard Lane ZS Attunga ZS 18 12.0 12.1 12.1 12.2 12.3 33 7.9 7.9 8.0 8.0 8.1 806/1 66 Attunga ZS Manilla ZS 18 8.4 8.5 8.5 8.6 8.6 33 5.7 5.7 5.8 5.8 5.8 806/2 66 Manilla ZS Upper Manilla ZS 18 3.0 3.0 3.0 3.1 3.1 33 2.6 2.6 2.6 2.6 2.6 806/4 66 Upper Manilla ZS Barraba ZS 15 2.3 2.3 2.3 2.3 2.3 25 2.1 2.1 2.1 2.1 2.1 80C 66 813:CLA 66 Transgrid Tamworth 132/66 STS Transgrid Tamworth 132/66 STS Goddard Lane ZS 61 11.0 11.1 11.1 11.3 11.3 68 8.0 8.0 8.1 8.1 8.2 Currububula ZS 28 16.8 17.0 17.0 17.1 17.3 34 13.6 13.6 13.7 13.7 13.9 813:QDI/1 66 Currububula ZS Werris Creek ZS 28 14.8 15.0 15.0 15.1 15.2 34 12.1 12.1 12.3 12.3 12.4 813:QDI/2 66 Werris Creek ZS Quirindi ZS 28 12.1 12.2 12.2 12.3 12.4 34 9.9 9.9 10.0 10.0 10.1 870:KTL/1 66 Transgrid Tamworth 132/66 STS Kootingal Tee 14 6.4 6.5 6.5 6.5 6.6 21 4.9 4.9 5.0 5.0 5.0 870:KTL/2 66 Kootingal Tee Kootingal ZS 12 5.8 5.8 5.8 5.9 5.9 20 4.3 4.3 4.3 4.3 4.4 870:KTL/3 66 Kootingal Tee Bendemeer ZS 13 0.7 0.7 0.7 0.7 0.7 21 0.7 0.7 0.7 0.7 0.7 798 33 Quirindi ZS Murrurundi ZS 4 2.6 2.7 2.7 2.7 2.7 6 2.4 2.4 2.4 2.4 2.4 799/1 33 Quirindi ZS Caroona Tee 6 3.0 3.0 3.0 3.1 3.1 10 2.3 2.3 2.3 2.3 2.3 799/2 33 Caroona Tee Caroona ZS 4 1.1 1.1 1.1 1.2 1.2 6 0.7 0.7 0.7 0.7 0.7 799/3 33 Caroona Tee Spring Ridge ZS 3 1.9 1.9 1.9 1.9 1.9 5 1.5 1.5 1.5 1.5 1.6 799/4 33 Spring Ridge ZS Colly Blue ZS 3 0.9 1.0 1.0 1.0 1.0 5 0.9 0.9 0.9 0.9 0.9 For Public Release December 2015 Page 62 of 183

2.4.9.3 STS and ZS load forecast SUMMER Tamworth Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Attunga 66/11 5 8 5.5 0.95 3.2 3.3 3.5 3.6 3.8 0.33 7 Barraba 66/11 5 5 5.5 0.96 2.1 2.1 2.1 2.1 2.1 0.52 5 Bendemeer 66/11 3 1 1.1 0.97 0.5 0.5 0.5 0.5 0.5 0.21 3 Caroona 33/11 2 2.5 2.2 0.82 0.9 0.9 0.9 0.9 0.9 0.04 9 Colly Blue 33/11 1.5 1.5 1.65 0.92 0.8 0.7 0.7 0.6 0.6 0.12 5 Currabubula 66/11 3 0 0.95 1.2 1.2 1.2 1.2 1.2 0.25 5 Goddard Lane 66/11 20/30 20/30 33 0.90 11.8 16.6 16.6 16.6 16.6 0.51 10 Kootingal 66/11 10/16 10/16 17.6 0.96 4.8 4.8 4.7 4.7 4.7 1.30 3 Manilla 66/11 5/6.25 5/6.25 6.875 0.90 4.4 4.4 4.4 4.4 4.4 0.65 9 Murrurundi 33/11 5/8 5/8 8.8 0.97 1.9 1.8 1.8 1.8 1.8 0.43 3 Nundle 66/11 2.5 2.5 2.75 0.93 1.2 1.1 1.1 1.1 1.0 0.33 2 Oxley Vale 66/11 20/30 20/30 33 1.00 16.0 16.0 16.0 16.0 16.0 2.22 1 Quirindi 66/11 66/33/11 10/13.3 10/13.3 14.63 0.96 5.6 5.6 5.6 5.6 5.6 0.74 4 Quirindi 66/33 66/33/11 8/10 8/10 11 0.96 3.8 3.8 3.7 3.7 3.6 0.00 5 Spring Ridge 33/11 1.5 0 0.95 0.5 0.5 0.5 0.5 0.5 0.10 1 Tamworth East 66/11 20/30 18/23 18/23 50.6 0.99 27.7 27.0 26.4 25.7 25.1 2.14 3 Tamworth South 66/11 20/30 20/30 33 0.95 21.4 21.2 21.1 21.0 20.9 2.77 35 Upper Manilla 66/11 1.5 0 0.94 0.5 0.5 0.5 0.5 0.5 0.02 6 Werris Creek 66/11 8 5/6.25 6.875 0.95 2.1 2.1 2.1 2.1 2.1 0.28 4 WINTER Tamworth Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Attunga 66/11 5 8 6 0.95 2.5 2.5 2.5 2.5 2.5 0.33 1 Barraba 66/11 5 5 6 0.99 1.9 1.9 1.8 1.8 1.7 0.52 2 Bendemeer 66/11 3 1 1.2 0.98 0.6 0.6 0.6 0.6 0.6 0.21 8 Caroona 33/11 2 2.5 2.4 0.88 0.5 0.5 0.5 0.5 0.4 0.04 16 Colly Blue 33/11 1.5 1.5 1.8 0.96 0.8 0.9 0.9 0.9 0.9 0.12 2 Currabubula 66/11 3 0 0.95 1.2 1.2 1.1 1.1 1.1 0.25 1 Goddard Lane 66/11 20/30 20/30 36 0.91 11.0 15.5 15.6 15.6 15.7 0.51 3 Kootingal 66/11 10/16 10/16 19.2 0.99 4.7 4.7 4.7 4.7 4.8 1.30 2 Manilla 66/11 5/6.25 5/6.25 7.5 0.90 3.3 3.3 3.3 3.3 3.3 0.65 7 Murrurundi 33/11 5/8 5/8 9.6 1.00 2.2 2.2 2.2 2.2 2.2 0.43 10 Nundle 66/11 2.5 2.5 3 0.94 1.4 1.4 1.4 1.4 1.4 0.33 1 Oxley Vale 66/11 20/30 20/30 36 1.00 14.3 14.3 14.2 14.2 14.2 2.22 11 Quirindi 66/11 66/33/11 10/13.3 10/13.3 15.96 1.00 4.7 4.7 4.6 4.6 4.6 0.74 4 Quirindi 66/33 66/33/11 8/10 8/10 12 0.99 3.8 3.8 3.8 3.8 3.7 0.00 8 Spring Ridge 33/11 1.5 0 0.97 0.4 0.4 0.4 0.4 0.4 0.10 6 Tamworth East 66/11 20/30 18/23 18/23 55.2 1.00 24.7 24.6 24.5 24.4 24.3 2.14 3 Tamworth South 66/11 20/30 20/30 36 0.99 20.8 20.6 20.5 20.3 20.2 2.77 8 Upper Manilla 66/11 1.5 0 0.95 0.3 0.3 0.3 0.3 0.3 0.02 2 Werris Creek 66/11 8 5/6.25 7.5 0.95 2.1 2.1 2.1 2.1 2.1 0.28 2 For Public Release December 2015 Page 63 of 183

2.4.9.4 Subtransmission Single Diagram of Tamworth area TAMWORTH Narrabri 968 Barraba 806/4 Crow Mtn Sw Stn Upper Manilla 806/2 Armidale 806/1 Manilla 86 85 Bendemeer Gunnedah 969 Attunga 806/1 Goddard Lane 80C Oxley Vale 806 803/2 Tamworth South 803Tamworth East 870:KTL Kootingal 813:CLA TAMWORTH Currabubula 804 66 Reg Werris Creek 813/1:QDI Nundle Colly Blue Caroona 88 84 799 Quirindi Spring Ridge 798 Murrurundi Muswellbrook and Liddell TransGrid s Essential Energy Zone s Transmission & Sub-trans. s 330/132 132/66 66/11 33/11 66/33/11 TransGrid 330 132 Essential Energy 66 33 For Public Release December 2015 Page 64 of 183

2.4.10 Beryl Supply Area 2.4.10.1 Description of Beryl area The Beryl area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation. The Mudgee substation is normally connected to the Essential Energy 132 teed line from the TransGrid Mt Piper to Beryl 132 transmission line with back up from the Beryl 66 system via Gulgong. BERYL Identified System Limitations SYSTEM LIMITATION Refer to DAPR Section Temporary loss of Mudgee ZS load for loss of 132 feeder 94M Section 3.1 Gulgong zone substation single 66/22 transformer with limited distribution backup Section 3.2 2.4.10.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 94M/4 132 851 66 Feeder Origin TransGrid 94M Mudgee Tee TransGrid Beryl 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Mudgee ZS 128 22.4 22.5 22.5 22.5 22.6 143 20.2 20.2 20.2 20.2 20.2 Gulgong ZS 28 3.8 3.8 3.7 3.7 3.7 32 4.7 4.7 4.7 4.8 4.8 851 66 Gulgong ZS Mudgee ZS 28 0.0 0.0 0.0 0.0 0.0 32 0.0 0.0 0.0 0.0 0.0 852 66 86J 66 TransGrid Beryl 132/66 STS TransGrid Beryl 132/66 STS Dunedoo ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 Dunedoo ZS 61 12.6 12.6 12.6 12.5 12.5 68 12.1 11.9 11.7 11.6 11.4 80L 66 Ulan Sw Stn Ulan Town ZS 15 1.6 1.6 1.6 1.6 1.6 25 1.8 1.8 1.8 1.8 1.8 80R 66 TransGrid Beryl 132/66 STS Ulan Sw Stn 64 25.7 27.7 32.6 33.4 34.1 71 26.8 32.9 33.7 34.6 35.4 80T 66 Ulan Sw Stn Moolarben Mine ZS 43 14.5 17.5 26.3 26.7 27.0 54 16.6 27.7 28.2 28.8 29.4 80T/2 66 Moolarben Mine ZS Wilpinjong Mine ZS 43 5.0 5.2 5.5 5.8 6.1 54 5.8 6.2 6.6 7.0 7.5 80U 66 TransGrid Beryl 132/66 STS Ulan Sw Stn 61 23.2 25.2 30.1 30.9 31.6 68 24.3 30.4 31.2 32.1 32.9 85A 66 Dunedoo ZS Coonabarabran ZS 11 8.3 8.2 8.1 8.1 8.0 19 7.8 7.6 7.4 7.2 7.1 As of 15 September 2015, the new Beryl to Dunedoo '86J' 66 transmission line was commissioned into service. The existing 852 is configured as the stand-by feeder; energised at Beryl with the 5B1 breaker open at Dunedoo. For Public Release December 2015 Page 65 of 183

2.4.10.3 STS and ZS load forecast SUMMER Beryl Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Coonabarabran 66/22 10 10 11 0.99 7.5 7.4 7.3 7.3 7.2 2.24 2 Dunedoo 66/22 7.5 7.5 8.25 1.00 4.3 4.4 4.4 4.5 4.6 0.79 3 Gulgong 66/22 5 0 0.96 3.8 3.8 3.7 3.7 3.7 0.41 3 Mudgee 132/22, 66/22 30 30 33 1.00 18.9 18.7 18.6 18.6 18.5 2.92 4 Ulan Town 66/11 2.5 0 0.95 1.6 1.6 1.6 1.6 1.6 0.34 2 WINTER Beryl Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Coonabarabran 66/22 10 10 12 1.00 7.0 6.8 6.6 6.4 6.3 2.24 3 Dunedoo 66/22 7.5 7.5 9 1.00 4.3 4.3 4.3 4.3 4.3 0.79 2 Gulgong 66/22 5 0 0.97 4.7 4.7 4.7 4.8 4.8 0.41 4 Mudgee 132/22, 66/22 30 30 36 1.00 21.2 21.3 21.3 21.4 21.4 2.92 2 Ulan Town 66/11 2.5 0 0.95 1.8 1.8 1.8 1.8 1.8 0.34 2 For Public Release December 2015 Page 66 of 183

Wollar Distribution Annual Planning Report - 2015 2.4.10.4 Subtransmission Single Diagram of Beryl area Coonabarabran BERYL Notes 1) West Gulgong planned ZS to be built in 2016/17. number from Beryl SS to West Gulgong ZS to be 806. 2) System Limitation Location See DAPR2015 Section 3.1 3) System Limitation Location See DAPR2015 Section 3.2 Merrygoen Regulator 85A 852 Dunedoo 86J Ulan Town Ulan Coal P No1 No2 80L Note 3 Moolarben P 80T 80U Dubbo - Geurie/Eulomogo 94F 813:GUE 94J WELLINGTON 330 79 806 BERYL 94B currently de-energized West Gulgong (Note 1) 851 851 80R Ulan Switching 80T/2 Station Wilpinjong P Note 2 Gulgong Parkes 94K 72 Wellington 132 TransGrid s 132/66 Private P 805 Mumbil 945/3 945/1 Molong 947/2 Co-located EE/TG ZS facilities G 330/132 Generator Mt Piper 947/1 Burrendong Hydro (19MW) 947/3 947 Mt Piper 947/4 Orange North 66 G Essential Energy Zone s 132/66/11 66/22 132/66/22 66 Switching Station 94M n.o. 94M/4 Mt Piper Note 2 Mudgee ILFORD Endeavour Energy Owned Transmission & Sub-trans. s Transgrid Essential Energy 330 132 132 66 For Public Release December 2015 Page 67 of 183

2.4.11 Wellington Supply Area 2.4.11.1 Description of Wellington area The Essential Energy Wellington 132/66/11 zone substation is normally connected to the Essential Energy 132 tee line #945/3 from TransGrid s Wellington to Molong 132 transmission line #945. The 66 supply for Mumbil is obtained from the Wellington 11 busbar via a step up 66/11 transformer. The backup supply for Wellington and Mumbil is via the 66 powerline #813 from Eulomogo. WELLINGTON Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section Nil 2.4.11.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 945/3 132 Feeder Origin TransGrid 945 Wellington 132 Tee Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Wellington 132 ZS 124 10.4 10.5 10.5 10.5 10.6 139 8.6 8.6 8.6 8.6 8.6 947/1 132 94F 132 94J 132 TransGrid 947 Burrendong Tee TransGrid Wellington 330/132 STS TransGrid Wellington 330/132 STS Burrendong Hydro 36 0.0 0.0 0.0 0.0 0.0 64 0.0 0.0 0.0 0.0 0.0 Dubbo 132/66 STS 173 90.0 90.2 90.5 90.8 91.0 194 77.3 77.5 77.6 77.7 77.8 Dubbo 132/66 STS 173 83.4 83.6 83.9 84.1 84.4 194 72.5 72.6 72.7 72.8 73.0 805 66 Wellington 132 ZS Mumbil ZS 11 1.3 1.3 1.3 1.3 1.3 19 1.0 1.0 1.0 1.0 1.0 813:GUE 66 Wellington 132 ZS Geurie Tee 12 0.0 0.0 0.0 0.0 0.0 18 0.0 0.0 0.0 0.0 0.0 2.4.11.3 STS and ZS load forecast SUMMER Wellington Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Mumbil 66/11 2.5 2.8 2.75 0.95 1.2 1.2 1.2 1.2 1.2 0.17 2 Wellington 11 66/11, 132/11 10 15 11 0.95 9.2 9.2 9.2 9.2 9.3 1.13 5 WINTER Wellington Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Mumbil 66/11 2.5 2.8 3 0.95 0.9 0.9 0.9 0.9 0.9 0.17 15 Wellington 11 66/11, 132/11 10 15 12 0.95 7.6 7.6 7.6 7.6 7.6 1.13 16 2.4.11.4 Subtransmission Single Diagram of Wellington area See the Beryl diagram on Page 67. For Public Release December 2015 Page 68 of 183

2.4.12 Dubbo Supply Area 2.4.12.1 Description of Dubbo area Essential Energy owns two 132 powerlines emanating from the TransGrid owned Wellington 330/132 STS that support the Dubbo 132/66 STS and Nyngan 132/66 STS supply areas. The Narromine zone substation is supplied from the Narromine South Switching station connected to the 943 Dubbo to Nyngan 132 line. The Nevertire zone substation is normally supplied from the 132 network via a tee, off the 94W Dubbo to Nyngan 132 line, with back up supply available from Nyngan 66 system via Nyngan Town. DUBBO Identified System Limitations SYSTEM LIMITATION Security of supply, voltage regulation and thermal constraint issues for all loads west of Wellington for loss of either 132 feeders 94F or 94J from Wellington Refer to DAPR Section Section 3.1 For Public Release December 2015 Page 69 of 183

2.4.12.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 943/1 132 94F Tee Dubbo South ZS 106 39.5 39.6 39.7 39.9 40.0 119 34.6 34.7 34.7 34.8 34.8 943/2 132 Dubbo South ZS Narromine South Sw Stn 106 25.2 25.3 25.4 25.4 25.5 119 22.3 22.3 22.3 22.4 22.4 94W/1 132 Dubbo 132/66 STS Nevertire Tee 128 37.4 37.5 37.7 37.8 37.9 143 33.5 33.6 33.6 33.7 33.7 94W/2 132 Nevertire Tee Nevertire ZS 124 5.3 5.3 5.4 5.4 5.4 139 8.9 9.0 9.1 9.3 9.4 94W/3 132 Nevertire Tee Nyngan 132/66 STS 128 30.3 30.4 30.5 30.6 30.7 143 25.8 25.8 25.8 25.9 25.9 9GP 132 9GR 132 Narromine South Sw Stn Narromine South Sw Stn Narromine ZS 124 11.8 11.8 11.8 11.8 11.8 139 11.8 11.7 11.7 11.7 11.7 Narromine ZS 124 0.0 0.0 0.0 0.0 0.0 139 0.0 0.0 0.0 0.0 0.0 9GT 132 Dubbo West ZS Narromine South Sw Stn 140 24.2 24.3 24.4 24.5 24.5 157 21.2 21.3 21.3 21.3 21.4 9GU 132 Narromine South Sw Stn Nyngan 132/66 STS 106 37.3 37.5 37.6 37.7 37.8 119 33.0 33.0 33.1 33.1 33.2 9GW 132 Dubbo 132/66 STS Dubbo West ZS 140 34.3 34.4 34.5 34.7 34.8 157 30.5 30.6 30.6 30.7 30.7 812 66 Yarrandale ZS Gilgandra ZS 15 5.9 5.9 5.9 5.9 6.0 25 5.5 5.5 5.5 5.5 5.6 815 66 Dubbo 132/66 STS Phillip St ZS 61 12.2 12.2 12.2 12.2 12.2 68 9.4 9.4 9.3 9.3 9.2 816 66 Dubbo 132/66 STS Phillip St ZS 61 12.2 12.2 12.2 12.2 12.2 68 9.4 9.4 9.3 9.3 9.2 813:EUL 66 Eulomogo ZS Geurie ZS 12 1.2 1.2 1.2 1.2 1.2 18 0.9 0.9 0.9 0.9 0.9 814/1 66 Gilgandra ZS Gulargambone ZS 11 6.9 6.8 6.8 6.8 6.7 19 5.8 5.8 5.8 5.7 5.7 814/2 66 Gulargambone ZS Coonamble ZS 11 5.5 5.5 5.4 5.4 5.4 19 4.5 4.5 4.5 4.4 4.4 81M 66 Dubbo 132/66 STS Eulomogo ZS 20 9.4 9.4 9.4 9.5 9.5 39 8.6 8.7 8.7 8.7 8.7 81P 66 Dubbo 132/66 STS Yarrandale ZS 61 10.0 10.1 10.1 10.1 10.2 68 9.6 9.7 9.7 9.7 9.7 81R 66 Dubbo 132/66 STS Eulomogo ZS 20 9.8 9.8 9.9 9.9 9.9 39 9.0 9.0 9.0 9.0 9.0 81X 66 Dubbo 132/66 STS Yarrandale ZS 28 11.0 11.0 11.0 11.1 11.1 34 10.4 10.5 10.5 10.5 10.5 81T 66 Yarrandale ZS Gilgandra ZS 61 5.9 5.9 5.9 5.9 6.0 68 5.5 5.5 5.5 5.5 5.6 For Public Release December 2015 Page 70 of 183

2.4.12.3 STS and ZS load forecast SUMMER Dubbo Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Coonamble 66/22 10 10 11 0.99 5.5 5.5 5.4 5.4 5.4 0.98 3 Dubbo 132/66 132/66 30/45 30/45 30/45 99 0.99 59.1 59.1 59.1 59.1 59.1 0.00 2 Dubbo Phillip St 66/11 20/30 20/30 33 0.91 24.4 24.4 24.4 24.4 24.4 1.45 17 Dubbo South 132/11 30 30 33 0.96 14.6 14.6 14.6 14.6 14.6 2.90 3 Dubbo West 132/11 15/23 15/23 25.3 0.95 13.0 13.1 13.2 13.2 13.3 2.49 3 Eulomogo 66/11 15/30 20/30 33 0.95 17.9 18.0 18.1 18.2 18.3 3.91 4 Geurie 66/11 5 0 0.95 1.2 1.2 1.2 1.2 1.2 0.32 8 Gilgandra 66/11 8/12 8/12 13.2 0.97 6.7 6.7 6.7 6.8 6.8 1.16 3 Gulargambone 66/22 3 0 0.95 1.5 1.5 1.5 1.5 1.5 0.20 4 Narromine 132/22 17/24 24 26.4 1.00 11.8 11.8 11.8 11.8 11.8 2.17 4 Nevertire 132/22, 66/22 10 17/24 11 0.99 5.3 5.3 5.4 5.4 5.4 1.04 2 Yarrandale 66/11 18/25 30 27.5 1.00 7.6 7.7 7.8 7.8 7.9 0.58 7 WINTER Dubbo Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Coonamble 66/22 10 10 12 1.00 4.5 4.5 4.5 4.4 4.4 0.98 5 Dubbo 132/66 132/66 30/45 30/45 30/45 108 1.00 45.9 45.9 45.9 45.9 45.9 0.00 7 Dubbo Phillip St 66/11 20/30 20/30 36 0.94 18.9 18.8 18.6 18.5 18.4 1.45 7 Dubbo South 132/11 30 30 36 0.99 13.3 13.4 13.6 13.7 13.9 2.90 3 Dubbo West 132/11 15/23 15/23 27.6 0.99 11.3 11.3 11.3 11.3 11.3 2.49 2 Eulomogo 66/11 15/30 20/30 36 0.99 17.7 17.7 17.7 17.7 17.6 3.91 2 Geurie 66/11 5 0 0.99 0.9 0.9 0.9 0.9 0.9 0.32 4 Gilgandra 66/11 8/12 8/12 14.4 0.99 6.2 6.2 6.3 6.4 6.4 1.16 2 Gulargambone 66/22 3 0 0.95 1.4 1.4 1.4 1.4 1.4 0.20 4 Narromine 132/22 17/24 24 28.8 1.00 11.8 11.7 11.7 11.7 11.7 2.17 6 Nevertire 132/22, 66/22 10 17/24 12 0.98 8.9 9.0 9.1 9.3 9.4 1.04 4 Yarrandale 66/11 18/25 30 30 0.90 7.6 7.7 7.7 7.8 7.8 0.58 3 For Public Release December 2015 Page 71 of 183

2.4.12.4 Subtransmission Single Diagram of Dubbo area Bourke 855/3 DUBBO - NYNGAN Coonamble Byrock Cobar Elura Coolibah Regulator 814/2 855/2 Gulargambone 94R Cobar CSA Cobar Town Cobar Peak 946/3 946/2 Proposed Regulator See Note 1 Scrubby Valley Sw Stn Tritton Mine Girilambone P 811 9UW 855/4 Solar Farm G 855/1 NYNGAN 132 See Note 2 9UT 9GU 854 Narromine South Sw Stn Nyngan Town 820/1:NYN 9GP n.o. 94W/3 Narromine 9GR 820:NVE n.o. Nevertire 94W/2 94W/1 Phillip St 816 815 Dubbo West 9GT 9GW 814/1 812 81X 943/1 n.o. Gilgandra 81P 81T Yarrandale DUBBO 132 (Wheelers Lane) 81R 81M 94J Notes 943/2 Dubbo South Eulomogo 94F 813:EUL Geurie n.o. WELLINGTON 330 813:GUE 1) System Limitation Location See DAPR2015 Section 3.1 2) System Limitation Location See DAPR2015 Section 3.2 TransGrid Subs 330/132 Essential Energy Zone s P G Generator Transmission & Sub-trans. s 132/66 132/11 132/22 132/66/22 132/66/11 Private 66/11 132 Switching Station 66/22 66/22/33 Wellington 132 TransGrid Essential Energy 132 132 66 For Public Release December 2015 Page 72 of 183

2.4.13 Nyngan Supply Area 2.4.13.1 Description of Nyngan area Essential Energy s Nyngan 132/66 substation is supplied from our Dubbo 132/66 subtransmission substation via two Essential Energy 132 transmission lines. The 94W Dubbo to Nyngan 132 line has a tee connection into Nevertire, with back up supply available from Nyngan 66 system via Nyngan Town and the 943 Dubbo to Nyngan 132 line via Narromine South Switching station. NYNGAN Identified System Limitations SYSTEM LIMITATION Voltage drops along the Nyngan to Cobar 66 #811 feeder (130km) are excessive at maximum load, and 150 spans need to be augmented to achieve a line design rating of 60 C Security of supply to the Nyngan and Cobar load for the loss of either 132 feeder 9GU from Narromine South Sw Stn or 94W feeder from Dubbo 132 Refer to DAPR Section Section 3.1 Section 3.1 2.4.13.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 9UT 132 Feeder Origin Nyngan 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Nyngan Solar Farm 106 57.9 57.6 57.3 57.0 56.8 119 62.3 61.8 61.4 61.0 60.7 9UW 132 Nyngan Solar Farm Scrubby Valley Sw Stn 106 35.4 35.4 35.4 35.4 35.4 119 33.0 33.3 33.5 33.8 33.9 946/2 132 946/3 132 Scrubby Valley Sw Stn Scrubby Valley Sw Stn Cobar CSA ZS 106 25.6 25.9 26.2 26.5 26.7 119 21.9 22.2 22.4 22.5 22.7 Cobar Peak ZS 102 17.8 17.8 17.8 17.8 17.8 114 16.7 17.0 17.3 17.5 17.7 94R 132 Cobar CSA ZS Cobar Elura ZS 128 9.4 9.4 9.4 9.4 9.4 143 8.0 8.0 8.0 8.0 8.0 811 66 854 66 Nyngan 132/66 STS Nyngan 132/66 STS Cobar Town ZS 10 6.9 7.0 7.1 7.2 7.3 16 7.4 7.4 7.4 7.4 7.4 Nyngan Town ZS 15 5.9 5.9 5.9 5.8 5.8 25 5.4 5.5 5.5 5.5 5.5 820/1:NYN 66 Nyngan Town ZS Nevertire Tee 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 820:NVE 66 855/1 66 Nyngan 132/66 STS Nyngan 132/66 STS Nevertire ZS 11 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 Girilambone Tee 28 15.4 15.6 15.9 16.1 16.4 34 15.7 15.8 16.0 16.1 16.3 855/1a 66 Girilambone Tee Girilambone ZS 24 11.2 11.5 11.9 12.3 12.7 29 10.6 10.9 11.1 11.4 11.7 855/2 66 Girilambone Tee Byrock ZS 15 8.0 8.0 7.9 7.9 7.9 25 9.0 8.9 8.8 8.7 8.7 855/3 66 Byrock ZS Bourke ZS 15 7.6 7.6 7.5 7.5 7.5 25 8.6 8.5 8.4 8.3 8.3 855/4 66 Girilambone ZS Tritton Mine ZS 24 10.4 10.8 11.1 11.5 11.9 29 9.9 10.1 10.4 10.7 10.9 For Public Release December 2015 Page 73 of 183

2.4.13.3 STS and ZS load forecast SUMMER Nyngan Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bourke 22 66/22-33 10 10 11 0.98 4.5 4.4 4.4 4.4 4.4 0.83 4 Bourke 33 66/22-33 5/8 0 0.38 4.0 4.0 4.0 3.9 3.9 0.00 2 Byrock 66/22 1 1 1.1 0.90 0.1 0.1 0.1 0.1 0.1 0.02 35 Cobar CSA 132/11 15 15 16.5 0.97 18.4 18.8 19.1 19.4 19.7 0.03 7 Cobar Elura 132/11 15 15 16.5 0.83 9.4 9.4 9.4 9.4 9.4 0.00 18 Cobar Peak 132/11 15/22 15/22 24.2 0.83 17.8 17.8 17.8 17.8 17.8 0.00 13 Cobar Town 66/22 10/13 10/13 14.3 0.95 5.9 6.0 6.1 6.2 6.3 1.17 7 Girilambone 66/11 10/12.5 0 0.85 1.6 1.6 1.6 1.6 1.6 0.00 30 Nyngan 132 132/66 18/30 30/45 33 1.00 28.3 28.6 28.9 29.1 29.3 0.00 10 Nyngan Town 66/22 10 10 11 0.96 5.9 5.9 5.9 5.8 5.8 0.82 4 WINTER Nyngan Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bourke 22 66/22-33 10 10 12 0.97 5.3 5.2 5.0 4.9 4.8 0.83 3 Bourke 33 66/22-33 5/8 0 0.39 4.2 4.3 4.3 4.4 4.4 0.00 26 Byrock 66/22 1 1 1.2 0.88 0.1 0.1 0.1 0.1 0.1 0.02 7 Cobar CSA 132/11 15 15 18 0.96 15.8 16.1 16.3 16.5 16.7 0.03 54 Cobar Elura 132/11 15 15 18 0.99 8.0 8.0 8.0 8.0 8.0 0.00 103 Cobar Peak 132/11 15/22 15/22 26.4 0.89 16.7 17.0 17.3 17.5 17.7 0.00 78 Cobar Town 66/22 10/13 10/13 15.6 0.95 6.4 6.4 6.4 6.4 6.4 1.17 4 Girilambone 66/11 10/12.5 0 0.85 1.5 1.5 1.5 1.5 1.5 0.00 2 Nyngan 132 132/66 18/30 30/45 36 1.00 28.1 28.4 28.6 28.8 29.0 0.00 10 Nyngan Town 66/22 10 10 12 0.99 5.4 5.5 5.5 5.5 5.5 0.82 2.4.13.4 Subtransmission Single Diagram of Nyngan area See the Dubbo diagram on Page 72. For Public Release December 2015 Page 74 of 183

2.4.14 Broken Hill Supply Area 2.4.14.1 Description of Broken Hill area The Broken Hill area is supplied from TransGrid s 220/22 substation. Essential Energy utilises two 22 lines and steps them up to 66 for supply to Mt Gipps and Sunset Strip from which 33 and other voltage levels are derived for specific purposes. BROKEN HILL Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.4.14.2 Subtransmission feeder load forecast Feeder # Feeder Voltage X4 220 Feeder Origin TransGrid Broken Hill 220/22 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Perilya Mine 213 22.7 23.0 23.4 23.7 24.0 238 22.9 23.2 23.5 23.9 24.2 5B1:PPL 66 Pinnacles Place ZS Mt Gipps ZS 19 8.1 8.1 8.1 8.1 8.2 33 7.3 7.4 7.4 7.4 7.5 5B1:MTG 66 Mt Gipps ZS Sunset Strip ZS 19 6.2 6.2 6.2 6.2 6.3 33 5.6 5.7 5.7 5.7 5.7 5B1:SUN 66 Sunset Strip ZS Menindee ZS 6 1.9 1.9 1.9 1.9 1.9 9 1.7 1.7 1.7 1.7 1.7 A 50MW generator is located at Broken Hill and is connected to the TransGrid Broken Hill 220/22 STS at 22. 2.4.14.3 STS and ZS load forecast SUMMER Broken Hill Supply Area POE50 Indicative Demand Forecast TransGrid 220/22 Total Broken Hill 22 Supply Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 38.1 38.2 38.3 38.5 38.6 5.84 Menindee 66/22 5 5 5.5 0.91 1.2 1.2 1.2 1.2 1.2 0.20 2 Mt Gipps 33 66/33 1.5 1.5 1.65 0.88 1.0 1.0 1.0 1.0 1.0 0.15 8 Mt Gipps 6.6 66/6.6 2 2 2.2 0.83 1.0 1.0 1.0 1.0 1.0 0.02 915 Pinnacles Place 22/66 15 15 16.5 1.00 6.1 6.2 6.3 6.3 6.4 0.00 7 Sunset Strip 22 66/22 5 0 1.00 1.0 1.0 1.0 0.9 0.9 0.04 2 Sunset Strip 33 66/33 4 4 4.4 0.95 3.0 3.0 3.0 3.0 3.0 0.03 Wilcannia 33/6.6 3.5 3.5 3.85 0.89 1.3 1.3 1.3 1.3 1.3 0.15 29 WINTER TransGrid 220/22 Total Broken Hill 22 Supply Broken Hill Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 34.7 34.9 35.0 35.1 35.3 5.84 Menindee 66/22 5 5 6 0.97 0.6 0.6 0.6 0.6 0.6 0.20 1 Mt Gipps 33 66/33 1.5 1.5 1.8 0.85 0.8 0.8 0.8 0.8 0.8 0.15 17 Mt Gipps 6.6 66/6.6 2 2 2.4 0.83 0.8 0.8 0.8 0.7 0.7 0.02 170 Pinnacles Place 22/66 15 15 18 0.94 5.9 5.9 5.9 5.9 5.9 0.00 6 Sunset Strip 22 66/22 5 0 0.97 0.6 0.6 0.5 0.5 0.5 0.04 9 Sunset Strip 33 66/33 4 4 4.8 0.90 2.7 2.7 2.7 2.7 2.7 0.03 Wilcannia 33/6.6 3.5 3.5 4.2 0.94 1.2 1.2 1.2 1.2 1.2 0.15 6 For Public Release December 2015 Page 75 of 183

2.4.14.4 Subtransmission Single Diagram of Broken Hill area Notes 1) Two gas turbine generators are located in Broken Hill ZSS connected to the 22 busbar. 2) Power fed from Broken Hill ZSS via 22 distribution network feeders BHL32 South and BHL82 Cockburn. 3) Pole mounted step-down transformer. 4) More SWER loads are connected on 33 lines than indicated. BROKEN HILL Tibooburra (note 3) MTG4B1 Shunt Station White Cliffs Shunt Station Shunt Station Packsaddle Regulator WLC4B1 BROKEN HILL (note 1) G BHL32 BHL82 Pinnacles Place (note 2) 5B1:PPL Mt Gipps 39km Kinalung Boost Pump Wilcannia X2 X4 P Perilya Mine 19km Kinalung Boost Pump 5B1:MTG Menindee Boost Pump SUN4B1 Sunset Strip 5B1:SUN SUN4B2 Buronga Lake Tandou Menindee Essential Energy Zone s 66/22 33/22 66/3.3 66/22/3.3 66/33/22 33/6.6 66/33/22/19.1SWER/6.6 TransGrid s 220/22 G Trans & Sub-trans s TransGrid 220 Essential Energy 220 66 22 33 Private Generator P Private SWER For Public Release December 2015 Page 76 of 183

2.5 South East Region 2.5.1 Bathurst Supply Area 2.5.1.1 Description of Bathurst area The Bathurst area subtransmission system is supplied from TransGrid s Panorama 132/66 subtransmission substation with the Bathurst town substations (Russell St, Raglan and Stewart) being supplied via 66 ring network. The Blayney and Mandurama substations are supplied by a radial 66 line from Panorama with a 66 back up supply from Orange if required. BATHURST Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.1.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 81H 66 81G 66 81F 66 Feeder Origin TransGrid Panorama 132/66 STS TransGrid Panorama 132/66 STS TransGrid Panorama 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Stewart ZS 62 6.7 6.7 6.7 6.7 6.7 69 6.8 6.8 6.8 6.8 6.8 Stewart ZS 64 11.2 11.2 11.2 11.2 11.2 71 11.3 11.3 11.3 11.3 11.3 Russell St ZS 64 26.6 26.6 26.6 26.6 26.6 71 27.9 27.9 27.9 27.9 27.9 81J 66 Raglan ZS Russell St ZS 64 5.1 5.1 5.1 5.1 5.1 71 6.1 6.1 6.1 6.1 6.1 81L 66 81C 66 TransGrid Panorama 132/66 STS TransGrid Panorama 132/66 STS Raglan ZS 64 15.7 15.7 15.7 15.7 15.7 71 16.7 16.7 16.7 16.7 16.7 Blayney ZS 19 11.6 11.6 11.6 11.6 11.6 22 11.4 11.4 11.4 11.4 11.4 66:MAN 66 Blayney ZS Mandurama ZS 9 1.5 1.5 1.5 1.4 1.4 15 1.8 1.8 1.8 1.8 1.8 A 10MW generator is located at Blayney wind farm and is connected to the TransGrid Panorama 132/66 STS at 66 via feeders 66:MAN and 81C. For Public Release December 2015 Page 77 of 183

2.5.1.3 STS and ZS load forecast SUMMER Bathurst Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Blayney 66/11 14/20 14/20 22 0.98 9.0 9.0 9.0 9.0 9.0 1.12 2 Mandurama 66/11 2.5 5 2.75 0.97 1.5 1.5 1.5 1.4 1.4 0.47 10 Raglan 66/11 18/30 30 33 0.97 18.1 18.4 18.6 18.8 19.0 2.41 27 Russell Street 66/11 20/30 20/30 20/30 66 0.90 22.2 22.2 22.2 22.2 22.2 2.09 Stewart 66/11 15/25 15/25 27.5 1.00 13.2 13.2 13.1 13.1 13.0 2.71 5 WINTER Bathurst Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Blayney 66/11 14/20 14/20 24 0.99 10.6 10.6 10.6 10.6 10.6 1.12 3 Mandurama 66/11 2.5 5 3 1.00 1.8 1.8 1.8 1.8 1.8 0.47 1 Raglan 66/11 18/30 30 36 0.98 21.2 21.0 20.9 20.8 20.6 2.41 8 Russell Street 66/11 20/30 20/30 20/30 72 0.96 21.0 21.0 21.0 21.0 21.0 2.09 Stewart 66/11 15/25 15/25 30 1.00 19.4 19.4 19.4 19.4 19.4 2.71 11 For Public Release December 2015 Page 78 of 183

2.5.1.4 Subtransmission Single Diagram of Bathurst area P Orange n.o. Browns Creek Mine (Abandoned) G 818/1 818/2 n.o. Orange Blayney 66:MAN Blayney Wind Farm (10MW) 81C 948 PANORAMA Stewart (Bathurst) 81H 81G 81F BATHURST Russell St (Bathurst) 81J Raglan (Bathurst) 81L 94X 94C 856 WALLERAWANG Orange Mt Piper 944 856/1 Lilyvale Pump 70/71 76/ 77 Endeavour Energy Region Sydney South P 1011/2 66:MAN Notes Mandurama 1) Oberon 11/33 ZSS fed from Oberon Town ZSS via 11KV distribution network on feeder: OBR42 Industrial. 2) Oberon Town ZSS and Oberon 132 ZSS distribution feeders are interconnected. Oberon 132 (note 2) OBR42 Oberon Town (note 2) Oberon 11/33 (note 1) P Tailings Dam 81B Burraga TransGrid Subs Essential Energy Zone s Transmission & Sub-trans. s 132/66 330/132/66 TransGrid Essential Energy Private 33 11 66/11 11/33 132/11 330 G Generator P Sub Station 132 132 66 For Public Release December 2015 Page 79 of 183

2.5.2 Oberon Supply Area 2.5.2.1 Description of Oberon area The zone substations at Oberon are supplied directly from Wallerawang via Essential Energy s 66 and 132 subtransmission lines respectively. OBERON Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.2.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 94C 132 856 66 Feeder Origin TransGrid Wallerawang 330/132/66 STS TransGrid Wallerawang 330/132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Oberon 132 ZS 128 24.1 24.1 24.1 24.1 24.1 143 24.3 24.3 24.3 24.3 24.3 Oberon Town ZS 28 4.6 4.6 4.6 4.6 4.6 32 6.2 6.2 6.2 6.2 6.2 81B 33 Oberon Town ZS Burraga ZS 8 0.5 0.5 0.5 0.5 0.5 13 0.6 0.6 0.6 0.6 0.6 2.5.2.3 STS and ZS load forecast SUMMER Oberon Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Burraga 33/11 2.5 0 0.73 0.5 0.5 0.5 0.5 0.5 0.00 2 Oberon 132 132/11 25/45 25/45 49.5 0.84 26.0 25.8 25.6 25.5 25.3 0.00 9 Oberon Town 66/11 10/15 10/15 16.5 0.93 4.0 3.9 3.8 3.7 3.6 1.09 29 WINTER Oberon Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Burraga 33/11 2.5 0 0.76 0.5 0.5 0.5 0.5 0.5 0.00 8 Oberon 132 132/11 25/45 25/45 54 0.84 26.0 25.8 25.7 25.6 25.5 0.00 8 Oberon Town 66/11 10/15 10/15 18 1.00 5.4 5.4 5.4 5.4 5.4 1.09 1 2.5.2.4 Subtransmission Single Diagram of Oberon area See the Bathurst diagram on Page 79. For Public Release December 2015 Page 80 of 183

2.5.3 Orange Supply Area 2.5.3.1 Description of Orange area The Orange area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation, with the Orange town substations (Industrial, North, South and West) being supplied via a 66 ring network. The Orange area provides a back-up 66 supply to Molong via Orange West which supplies Cumnock and Molong via a 66/11 transformer. ORANGE Identified System Limitations SYSTEM LIMITATION Refer to DAPR Section Thermal limitation on feeder 807 for loss of feeder 8C2 Section 3.1 2.5.3.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 94G 132 Feeder Origin TransGrid Orange 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 9MC 156 0.0 0.0 0.0 0.0 0.0 162 0.0 0.0 0.0 0.0 0.0 9MC 132 TransGrid Orange North 132 Sw Stn Cadia ZS 162 150 150 150 150 151 162 152 153 153 154 154 807 66 TransGrid Orange 132/66 STS Orange West & South Tee 27 10.8 10.8 10.8 10.8 10.8 30 13.9 13.9 13.9 13.9 13.9 807/2 66 Orange West & South Tee Orange South ZS 63 0.0 0.0 0.0 0.0 0.0 70 0.0 0.0 0.0 0.0 0.0 807/3 66 Orange West & South Tee Orange West ZS 62 10.8 10.8 10.8 10.8 10.8 69 13.9 13.9 13.9 13.9 13.9 818/1 66 8C2 66 8F1 66 8M1 66 8M2 66 TransGrid Orange 132/66 STS TransGrid Orange 132/66 STS TransGrid Orange 132/66 STS TransGrid Orange 132/66 STS TransGrid Orange 132/66 STS Blayney ZS 11 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 Orange West ZS 9 0.0 0.0 0.0 0.0 0.0 15 0.0 0.0 0.0 0.0 0.0 Orange South ZS 63 23.2 23.2 23.2 23.2 23.2 70 24.4 24.4 24.4 24.4 24.4 Orange Industrial ZS 11 3.2 3.2 3.2 3.2 3.3 19 3.9 3.9 3.9 3.9 3.9 Orange Industrial ZS 21 5.2 5.2 5.2 5.2 5.2 39 6.3 6.3 6.3 6.3 6.3 2.5.3.3 STS and ZS load forecast SUMMER Orange Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Orange Industrial 66/11 10 10 11 0.99 7.7 7.7 7.7 7.7 7.8 1.85 4 Orange North 66/11 20 15 15 33 0.94 12.2 12.1 12.1 12.1 12.1 1.28 9 Orange South 66/11 30 30 33 0.97 19.6 19.4 19.2 19.1 19.0 2.43 2 Orange West 66/11 30 30 33 0.99 8.3 8.3 8.3 8.2 8.2 2.23 3 WINTER Orange Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Orange Industrial 66/11 10 10 12 0.99 11.8 11.8 11.9 11.9 11.9 1.85 2 Orange North 66/11 20 15 15 36 0.98 14.3 14.3 14.3 14.4 14.4 1.28 10 Orange South 66/11 30 30 36 0.97 26.3 26.0 25.8 25.7 25.5 2.43 20 Orange West 66/11 30 30 36 0.99 14.4 14.4 14.5 14.5 14.5 2.23 2 For Public Release December 2015 Page 81 of 183

2.5.3.4 Subtransmission Single Diagram of Orange area Cumnock ORANGE Wellington 8C1 945/1 Wellington/ Burrendong Hydro See Note 3 Old Molong (decommissioned) Molong MOLONG 132 947/3 Parkes132 8C1/1 Manildra 94P 8C1/2 8C1/4 94T Orange West n.o. 807/3 Orange Industrial Orange 8C2 North See Note 2 807/2 Orange South 8M1 807 n.o. 94G n.o. 8F1 8M2 ORANGE 132 (note 1) ORANGE NORTH Sw Stn 949 Mt Piper 944 Wallerawang 948 Panorama 818/1 Notes 1) numbers from Orange North Sw Stn to Orange 132; No.1, No.2 and No.3 Tie s 9MC n.o. Blayney 2) System Limitation Location See DAPR2015 Section 3.1 3) System Limitation Location See DAPR2015 Section 3.2 P Cadia Mine TransGrid ZS EE Zone s Trans & Sub-trans s 132 Switching station 132/66 Co-located EE/TG ZSS facilities 132/11 66/11 Private P TransGrid 132 Connection Dual line Essential Energy 66 132 For Public Release December 2015 Page 82 of 183

2.5.4 Molong Supply Area 2.5.4.1 Description of Molong area The Molong 132/66/11 substation is a shared asset with TransGrid, whereby Essential Energy takes supply at 66 which supplies Cumnock and Molong via a 66/11 transformer, with back up supply from the Orange 66 network via Orange West. Manildra substation is also a shared asset with TransGrid and is supplied from TransGrid s Molong substation at 132. MOLONG Identified System Limitations SYSTEM LIMITATION Security of supply to the Molong load upon the loss of the single 66/11 transformer at the Molong 132/66/11 zone substation Refer to DAPR Section Section 3.2 2.5.4.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 8C1 66 8C1/4 66 Feeder Origin TransGrid Molong 132/66 STS Cumnock / Orange West Tee Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Cumnock ZS 9 1.3 1.4 1.4 1.4 1.4 15 1.3 1.3 1.3 1.3 1.3 Orange West ZS 9 0.0 0.0 0.0 0.0 0.0 15 0.0 0.0 0.0 0.0 0.0 2.5.4.3 STS and ZS load forecast SUMMER Molong Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Cumnock 66/11 2.5 2.5 2.75 1.00 1.3 1.4 1.4 1.4 1.4 0.54 3 Manildra 132/11 18/24 18/24 26.4 0.97 11.0 11.0 11.0 11.0 11.0 0.82 41 Molong 11 66/11 7.5 0 0.99 2.5 2.5 2.5 2.5 2.5 0.65 2 WINTER Molong Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Cumnock 66/11 2.5 2.5 3 1.00 1.3 1.3 1.3 1.3 1.3 0.54 2 Manildra 132/11 18/24 18/24 28.8 0.96 11.0 11.1 11.1 11.2 11.3 0.82 104 Molong 11 66/11 7.5 0 1.00 3.2 3.2 3.2 3.2 3.2 0.65 4 2.5.4.4 Subtransmission Single Diagram of Molong area See the Orange diagram on Page 82. For Public Release December 2015 Page 83 of 183

2.5.5 Moruya North Supply Area 2.5.5.1 Description of Moruya North area Essential Energy s Moruya North subtransmission substation is supplied via 2 x 132 transmission lines from Endeavour Energy s 132 transmission system that emanate from the Evans Lane switching station near Ulladulla. Essential Energy partly owns with Endeavour Energy both 132 transmission lines from Evans Lane switching station. MORUYA NORTH Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.5.2 Subtransmission feeder load forecast Feeder # Feeder Voltage Feeder Origin Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 98H 132 Endeavour Energy Evans Lane Sw Stn Moruya North 132/33 STS 180 13.5 13.3 13.0 12.8 12.7 202 18.6 18.6 18.6 18.6 18.6 98M 132 Endeavour Energy Evans Lane Sw Stn Batemans Bay ZS 70 17.0 16.7 16.4 16.1 15.9 78 23.3 23.3 23.3 23.3 23.3 98T 132 Batemans Bay ZS Moruya North 132/33 STS 70 3.1 3.0 2.9 2.9 2.9 78 4.6 4.6 4.6 4.6 4.6 7703 33 7704 33 7706 33 Moruya North 132/33 STS Moruya North 132/33 STS Moruya North 132/33 STS Moruya Town ZS 32 5.1 5.0 4.9 4.9 4.8 35 7.2 7.2 7.2 7.2 7.2 Moruya Town ZS 26 6.5 6.4 6.3 6.2 6.1 30 9.1 9.1 9.1 9.1 9.1 Mossy Point ZS 25 4.4 4.3 4.3 4.2 4.1 28 6.2 6.2 6.2 6.2 6.2 7712 33 Bodalla Tee Bodalla ZS 10 0.9 0.9 0.9 0.9 0.8 19 1.2 1.2 1.2 1.2 1.2 7713 33 Bodalla Tee Narooma ZS 21 0.0 0.0 0.0 0.0 0.0 27 0.0 0.0 0.0 0.0 0.0 7817 33 Narooma Tee Cobargo ZS 10 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 7711/1 33 Moruya Town ZS Tuross Tee 14 2.2 2.2 2.1 2.1 2.1 17 3.5 3.5 3.5 3.5 3.5 7711/2 33 Tuross Tee Tuross ZS 7 1.3 1.3 1.3 1.2 1.2 12 2.3 2.3 2.3 2.3 2.3 7711/3 33 Tuross Tee Bodalla Tee 21 0.9 0.9 0.9 0.8 0.8 27 1.2 1.2 1.2 1.2 1.2 7715/1 33 Moruya Town ZS Narooma Tee 30 4.4 4.3 4.2 4.1 4.1 34 6.6 6.6 6.6 6.6 6.6 7715/2 33 Narooma Tee Narooma ZS 10 4.1 4.0 4.0 3.9 3.9 19 6.2 6.2 6.2 6.2 6.2 For Public Release December 2015 Page 84 of 183

2.5.5.3 STS and ZS load forecast SUMMER Moruya North Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Batemans Bay 132/11 30/45 30/45 49.5 1.00 16.7 16.5 16.4 16.2 16.1 2.41 2 Bodalla 33/11 3/4 3 3.3 0.95 1.2 1.2 1.2 1.2 1.2 0.40 1 Moruya North 132/33 30 30/45 33 1.00 17.3 17.2 17.2 17.2 17.2 0.00 2 Moruya Town 33/11 16 16 17.6 0.97 5.7 5.6 5.5 5.4 5.3 1.36 7 Mossy Point 33/11 12.5 12.5 13.75 0.98 6.1 6.1 6.1 6.1 6.2 0.93 6 Narooma 33/11 10/16 10/12.5 13.75 0.98 5.9 5.9 6.0 6.0 6.1 1.53 2 Tuross 66/11 5/8 0 0.98 1.8 1.8 1.7 1.7 1.7 0.51 2 WINTER Moruya North Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Batemans Bay 132/11 30/45 30/45 54 1.00 19.2 19.1 19.0 18.9 18.8 2.41 8 Bodalla 33/11 3/4 3 3.6 0.98 1.2 1.2 1.2 1.3 1.3 0.40 2 Moruya North 132/33 30 30/45 36 1.00 24.6 24.6 24.7 24.8 24.8 0.00 1 Moruya Town 33/11 16 16 19.2 0.99 6.5 6.4 6.3 6.2 6.1 1.36 8 Mossy Point 33/11 12.5 12.5 15 0.99 6.5 6.5 6.6 6.6 6.6 0.93 1 Narooma 33/11 10/16 10/12.5 15 0.99 6.9 6.8 6.8 6.7 6.7 1.53 5 Tuross 66/11 5/8 0 0.99 2.2 2.2 2.2 2.2 2.2 0.51 1 For Public Release December 2015 Page 85 of 183

2.5.5.4 Subtransmission Single Diagram of Moruya North area MORUYA NORTH EVANS LANE Ulladulla (Endeavour Energy) 98H 98M 98T Batemans Bay Mossy Point MORUYA NORTH 7706 7703 7704 Moruya Town 7715 7711 (Moruya Town to Bodalla T) Tuross Bodalla 7712 7713 (Bodalla T to Narooma) 7715 n.o. Narooma Olsen s CK R3710 n.o. 7817 Cobargo Essential Energy Zone s Sub-trans. s 33/11 132/11 132/33 33 132 For Public Release December 2015 Page 86 of 183

2.5.6 Bega Supply Area 2.5.6.1 Description of Bega area Essential Energy s Bega subtransmission substation is supplied from TransGrid s Cooma 132/66 subtransmission substation via the Essential Energy 132 transmission line. BEGA Identified System Limitations SYSTEM LIMITATION Refer to DAPR Section Unsatisfactory voltage at Pambula ZS for loss of 66 feeder 84G Bega STS to Pambula ZS Section 3.1 2.5.6.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 84G 66 Bega 132/66 STS Eden South ZS 61 7.6 7.6 7.6 7.6 7.6 70 9.3 9.3 9.3 9.3 9.3 84H 66 Eden South ZS Edrom ZS 38 2.1 2.1 2.1 2.1 2.1 43 1.7 1.8 1.9 2.0 2.0 84M 66 Bega 132/66 STS Maher St ZS 61 10.4 10.4 10.4 10.4 10.4 68 10.6 10.6 10.6 10.6 10.6 89A 66 Bega 132/66 Pambula ZS 38 11.6 11.6 11.6 11.6 11.6 43 14.4 14.4 14.4 14.4 14.4 89B 66 Boundary St 66/33 STS Maher St ZS 39 4.3 4.3 4.3 4.3 4.3 43 4.0 4.0 4.0 4.0 4.0 89C 66 Bega 132/66 STS Boundary St 66/33 STS 39 10.4 10.4 10.4 10.4 10.4 43 10.7 10.7 10.7 10.7 10.7 89F 66 Pambula ZS Eden South ZS 16 1.3 1.3 1.3 1.3 1.3 26 1.8 1.8 1.8 1.8 1.8 S839 66 7802/1 33 Boundary St 66/33 STS Boundary St 66/33 STS Quira ZS 21 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 Brogo ZS 12 4.5 4.5 4.5 4.5 4.5 24 5.3 5.3 5.3 5.3 5.3 7802/2 33 Brogo ZS Cobargo ZS 10 3.9 3.9 3.9 3.9 3.9 19 4.4 4.4 4.4 4.4 4.4 7803 33 Boundary St 66/33 STS Quira ZS 6 0.0 0.0 0.0 0.0 0.0 9 0.0 0.0 0.0 0.0 0.0 7814 33 Cobargo ZS Bermagui ZS 5 2.3 2.3 2.3 2.3 2.3 9 2.7 2.7 2.7 2.7 2.7 For Public Release December 2015 Page 87 of 183

2.5.6.3 STS and ZS load forecast SUMMER Bega Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bega 132 132/66 35/60 35/60 66 1.00 32.2 32.0 31.9 31.9 31.8 0.00 3 Bermagui 33/11 5 5 5.5 1.00 2.3 2.3 2.3 2.3 2.3 0.60 3 Boundary Street 66/33 15 7.5 8.25 0.95 4.2 4.2 4.2 4.2 4.2 0.00 5 Brogo 33/11 3 0 0.90 0.6 0.6 0.6 0.6 0.6 0.16 5 Cobargo 33/11 3 2.5 2.75 0.94 1.3 1.3 1.3 1.3 1.3 0.63 3 Eden South 66/11 10/16 10/16 17.6 0.96 4.5 4.4 4.4 4.4 4.4 0.91 5 Edrom 66/11 5 5 5.5 0.90 2.1 2.1 2.1 2.1 2.1 0.00 1 Maher Street 66/11 24/30 24/30 33 0.96 15.2 15.1 14.9 14.8 14.7 2.68 3 Pambula 66/11 10/13/16 10/13/16 17.6 1.00 9.6 9.5 9.4 9.3 9.2 2.69 3 WINTER Bega Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bega 132 132/66 35/60 35/60 72 0.99 40.7 40.7 40.7 40.7 40.8 0.00 8 Bermagui 33/11 5 5 6 1.00 2.7 2.7 2.7 2.7 2.7 0.60 2 Boundary Street 66/33 15 7.5 9 0.95 4.6 4.6 4.5 4.5 4.5 0.00 2 Brogo 33/11 3 0 0.95 0.5 0.5 0.5 0.5 0.5 0.16 Cobargo 33/11 3 2.5 3 0.98 1.3 1.3 1.3 1.3 1.3 0.63 14 Eden South 66/11 10/16 10/16 19.2 0.97 4.7 4.6 4.6 4.6 4.6 0.91 16 Edrom 66/11 5 5 6 0.96 1.7 1.8 1.9 2.0 2.0 0.00 1 Maher Street 66/11 24/30 24/30 36 0.98 15.3 15.5 15.6 15.7 15.8 2.68 7 Pambula 66/11 10/13/16 10/13/16 19.2 1.00 15.2 15.2 15.2 15.2 15.2 2.69 1 For Public Release December 2015 Page 88 of 183

2.5.6.4 Subtransmission Single Diagram of Bega area Williamsdale 978 97D BEGA Olsen s Ck R3710 97K/1 Snowy Adit NORTH COOMA COOMA n.o. 7817 97R 974 Cobargo 7802 n.o. 7814 Bermagui Brogo 97R Boco Rock Wind Farm G 97C Bombala 810/4 STEEPLE FLAT 974 G Brown Mountain Hydro (5MW) 97R Quira S839 89B n.o. 7802 Maher St See Note 1 84M (Under Construction) Boundary St BEGA 84G 89A See Note 2 Pambula Notes 1) System Limitation Location See DAPR2015 Section 3.1 2) System Limitation Location See DAPR2015 Section 3.2 Essential Energy Sub-trans s 89F 84G 66 132 33 Dual line TransGrid Essential Energy s Eden South Edrom 132/66/11 132 66/11 66/33 66/22 33/11 132/66 132/66/22 84H For Public Release December 2015 Page 89 of 183

2.5.7 Cooma Supply Area 2.5.7.1 Description of Cooma area The Cooma area subtransmission system is supplied from TransGrid s subtransmission substation at Cooma. TransGrid also supplies Essential Energy at 11 to supply the Cooma township. COOMA Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.7.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 974 132 TransGrid Cooma 132/66/11 STS Bega 132/66 STS 128 19.8 19.9 19.9 19.9 19.9 143 22.1 22.1 22.1 22.1 22.1 97R 132 TransGrid Cooma 132/66/11 STS Steeple Flat 132/66 STS 140 78.6 78.6 78.6 78.6 78.6 157 75.8 75.8 75.8 75.8 75.8 82D 66 82J/1 66 TransGrid Cooma 132/66/11 STS Snowy Adit 132/66/11 ZS Jindabyne East ZS 20 5.1 5.1 5.1 5.1 5.1 39 17.1 17.1 17.1 17.1 17.1 Snowy Lookout Sw Stn 12 0.0 0.0 0.0 0.0 0.0 20 0.0 0.0 0.0 0.0 0.0 82J/2 66 Jindabyne ZS Snowy Lookout Sw Stn 12 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 82R 66 Jindabyne East ZS Jindabyne ZS 20 2.3 2.3 2.3 2.3 2.3 39 12.5 12.5 12.5 12.5 12.5 888/1 66 TransGrid Cooma 132/66/11 STS Rhine Falls Sw Stn 16 2.1 2.1 2.1 2.1 2.1 25 3.8 3.8 3.8 3.8 3.8 888/3 66 Rhine Falls Sw Stn Adaminaby ZS 16 1.9 1.9 1.9 1.9 1.9 25 3.6 3.6 3.6 3.6 3.6 888/4 66 Rhine Falls Sw Stn Eucumbene Tee 15 0.2 0.2 0.2 0.2 0.2 25 0.4 0.4 0.4 0.4 0.4 888/6 66 Eucumbene Tee Eucumbene ZS 15 0.2 0.2 0.2 0.2 0.2 25 0.2 0.2 0.2 0.2 0.2 888/7 66 Eucumbene Tee Snowy Adit 132/66/11 ZS 20 0.0 0.0 0.0 0.0 0.0 39 0.0 0.0 0.0 0.0 0.0 849/1 33 Adaminaby ZS Providence Portal ZS 7 0.9 0.9 0.9 0.9 0.9 12 2.2 2.2 2.2 2.2 2.2 849/2 33 Providence Portal ZS Cabramurra ZS 7 0.8 0.8 0.8 0.8 0.8 12 1.9 1.9 1.9 1.9 1.9 A 5MW generator is located at Brown Mountain Hydro and is connected to Steeple Flat 132/66 STS at 66 via feeder 810. A 114MW generator is located at Boco Rock wind farm and is connected to the Steeple Flat 132/66 STS which is connected to TransGrid s Cooma 132/66 STS at 132 via the feeder 97R. A 1MW generator is located at Jindabyne Dam and is connected to the Jindabyne ZS 11 busbar via feeder JIN22. For Public Release December 2015 Page 90 of 183

2.5.7.3 STS and ZS load forecast SUMMER Cooma Supply Area POE50 Indicative Demand Forecast TransGrid Total Cooma Town 11 Supply Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 7.2 7.2 7.1 7.1 7.0 1.84 58 Adaminaby 11 66/33/11 8 5 5.5 0.98 0.5 0.5 0.5 0.5 0.5 0.10 3 Adaminaby 33 66/33/11 5 5.5 1.00 1.0 1.0 1.0 1.0 1.0 0.00 2 Eucumbene 66/11 0.6 0 0.95 0.1 0.1 0.1 0.1 0.1 0.03 2 Jindabyne 11 66/33/11 15/30 15/30 33 0.96 2.8 2.8 2.8 2.7 2.7 0.72 2 Jindabyne 33 66/33/11 15 0 1.00 0.2 0.2 0.2 0.2 0.3 0.00 4 Jindabyne East 66/11 8/10 8/10 11 0.98 1.4 1.4 1.4 1.4 1.4 0.39 4 Providence Portal 33/11 0.5 0 0.95 0.2 0.2 0.2 0.2 0.2 0.00 WINTER TransGrid Total Cooma Town 11 Supply Cooma Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 12.4 12.3 12.3 12.3 12.2 1.84 26 Adaminaby 11 66/33/11 8 5 6 0.99 1.0 1.0 1.0 1.0 1.0 0.10 5 Adaminaby 33 66/33/11 5 6 1.00 2.3 2.3 2.3 2.3 2.3 0.00 1 Eucumbene 66/11 0.6 0 0.94 0.1 0.1 0.1 0.1 0.1 0.03 5 Jindabyne 11 66/33/11 15/30 15/30 36 0.98 11.8 11.8 11.8 11.9 11.9 0.72 8 Jindabyne 33 66/33/11 15 0 0.98 0.7 0.7 0.7 0.7 0.7 0.00 1 Jindabyne East 66/11 8/10 8/10 12 0.98 3.7 3.7 3.8 3.8 3.9 0.39 6 Providence Portal 33/11 0.5 0 0.95 0.3 0.3 0.3 0.3 0.3 0.00 For Public Release December 2015 Page 91 of 183

2.5.7.4 Subtransmission Single Diagram of Cooma area Mt Selwyn 849 Providence Portal Cabramurra 849 COOMA Adaminaby 888/3 Eucumbene GUTHEGA Snowy Adit 888/6 888/1 Geehi Dam/ Murray Switching Station 97G/3 Guthega Power Station (60MW) G N.O. 888/7 97L 888/4 N.O. MUNYANG 82J/1 P Jindabyne Pumping Station 97K/2 82D Blue Cow MCC1 57A 57B Bullocks Portal MCC2 56 Perisher 60 Smiggin N.O. JIN2442 G Jindabyne 82R Jindabyne East Jindabyne Dam (1.1MW) Bullocks Flat 58 Thredbo 59 TransGrid ZSS s Essential Energy Zone s Private Assets 132/66/11 132/33/11 66/11 33/11 33 Switching Station 132 SwStn 132/66 132/66/11 66/33/11 33/415V G P Generator Customer Williamsdale 978 97D 97K/1 NORTH COOMA COOMA 974 97R Steeple Flat Bega Transmission & Sub-trans. s TransGrid 132 Essential Energy 33 66 132 For Public Release December 2015 Page 92 of 183

2.5.8 Steeple Flat Supply Area 2.5.8.1 Description of Steeple Flat area The Steeple Flat 132/66/22/ substation is owned by Essential Energy. It receives supply via a tee off the Essential Energy Cooma Bega 132 line (#97R). The 132/66/11 transformer provides supply for the 66 network to Bombala 66/22 zone substation and connection for the Brown Mountain Generation (Green State Power). An 11/22 transformer at Steeple Flat provides 22 supply for local distribution load. Steeple Flat also provides connection for the Boco Rock wind farm to the 132 network. STEEPLE FLAT Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.8.2 Subtransmission feeder load forecast Feeder # Feeder Voltage Feeder Origin Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 97R 132 810/3 66 810/4 66 Steeple Flat 132/66 STS Steeple Flat 132/66 STS Steeple Flat 132/66 STS Bega 132/66 STS 140 20.4 20.4 20.4 20.4 20.4 194 23.0 23.0 23.0 23.0 23.0 Brown Mountain Hydro 70 5.3 5.3 5.3 5.3 5.3 78 5.3 5.3 5.3 5.3 5.3 Bombala ZS 21 4.6 4.6 4.6 4.6 4.6 25 4.7 4.7 4.7 4.7 4.7 S839 66 Brown Mountain Hydro Quira ZS 70 1.2 1.2 1.2 1.2 1.2 78 0.9 0.9 0.8 0.8 0.8 97C 66 Steeple Flat 132/66 STS Boco Rock Wind Farm 140 113.9 113.9 113.9 113.9 113.9 157 113.9 113.9 113.9 113.9 113.9 2.5.8.3 STS and ZS load forecast SUMMER Steeple Flat Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bombala 66/22 10/16 10/13 14.3 1.00 4.6 4.6 4.6 4.6 4.6 0.36 3 Steeple Flat 132/66 132/66/22 30 0 0.99 4.7 4.7 4.7 4.7 4.7 0.00 2 Steeple Flat 22 11/22 5 0 0.96 0.5 0.5 0.5 0.5 0.5 0.14 3 Quira 66/11 5 0 0.93 1.2 1.2 1.2 1.2 1.2 0.23 WINTER Steeple Flat Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bombala 66/22 10/16 10/13 15.6 1.00 4.7 4.7 4.7 4.7 4.7 0.36 9 Steeple Flat 132/66 132/66/22 30 0 0.99 5.0 5.0 5.0 5.0 5.0 0.00 1 Steeple Flat 22 11/22 5 0 0.97 0.7 0.7 0.7 0.7 0.7 0.14 5 Quira 66/11 5 0 0.94 0.9 0.9 0.8 0.8 0.8 0.23 2.5.8.4 Subtransmission Single Diagram of Steeple Flat area See the Bega diagram on Page 89. For Public Release December 2015 Page 93 of 183

2.5.9 Munyang Supply Area 2.5.9.1 Description of Munyang area The Munyang area subtransmission system is supplied from TransGrid s subtransmission substation at Munyang. The majority of the Snowy Mountains winter ski resorts are supplied from the Munyang subtransmission substation. Essential Energy takes supply at 11 from Snowy Mountains Hydro at the Murray transmission substation to supply the Khancoban township. MUNYANG Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.9.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 56 33 Smiggin Sw Stn Perisher ZS 20 2.2 2.2 2.2 2.2 2.2 20 14.4 14.4 14.4 14.4 14.4 57A 33 Smiggin Sw Stn Perisher ZS 20 1.7 1.7 1.7 1.7 1.7 20 11.0 11.0 11.0 11.0 11.0 57B 33 Smiggin Sw Stn Perisher ZS 20 1.7 1.7 1.7 1.7 1.7 20 11.0 11.0 11.0 11.0 11.0 No.1 Perisher 33 TransGrid Munyang 132/33 STS Smiggin Sw Stn 38 2.7 2.7 2.7 2.7 2.7 41 18.9 18.9 18.9 18.9 18.9 No.2 Perisher 33 TransGrid Munyang 132/33 STS Blue Cow Tee 38 2.8 2.8 2.8 2.8 2.8 49 19.7 19.7 19.7 19.7 19.7 No.2 Perisher 33 Blue Cow Tee Smiggin Sw Stn 38 2.6 2.6 2.6 2.6 2.6 49 18.0 18.0 18.0 18.0 18.0 60/2 33 Bullocks Portal ZS Bullocks Flat ZS 7 2.5 2.5 2.5 2.5 2.5 17 19.5 19.5 19.5 19.5 19.5 58 33 Bullocks Flat ZS Thredbo ZS 6 2.0 2.0 2.0 2.0 2.0 14 6.7 6.7 6.7 6.7 6.7 59 33 Bullocks Flat ZS Thredbo ZS 6 0.2 0.2 0.2 0.2 0.2 14 12.1 12.1 12.1 12.1 12.1 Bullocks Portal 33 Perisher ZS Bullocks Portal ZS 20 2.9 2.9 2.9 2.9 2.9 20 20.9 20.9 20.9 20.9 20.9 For Public Release December 2015 Page 94 of 183

2.5.9.3 STS and ZS load forecast SUMMER Munyang Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Blue Cow 33/11 5/8 0 0.92 0.1 0.1 0.1 0.1 0.1 0.01 Bullocks Flat 33/11 5/6.25 0 1.00 0.2 0.2 0.2 0.2 0.2 0.03 5 Bullocks Portal 33/11 5/6.25 0 0.80 0.5 0.5 0.5 0.5 0.5 0.00 21 Perisher 33/11 8/10 8/10 11 0.95 2.9 2.9 2.9 2.9 2.9 0.01 3 Snowy Adit 11 132/66/11 10 0 0.65 0.2 0.2 0.2 0.2 0.2 0.00 2 Snowy Adit 66 132/66/11 30 0 0.85 9.0 9.0 9.1 9.1 9.2 0.00 9 Thredbo 33/11 16 16 17.6 0.97 2.1 2.0 2.0 2.0 1.9 0.00 2 WINTER Munyang Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Blue Cow 33/11 5/8 0 0.87 4.4 4.4 4.4 4.4 4.4 0.01 5 Bullocks Flat 33/11 5/6.25 0 0.99 0.7 0.7 0.7 0.8 0.8 0.03 2 Bullocks Portal 33/11 5/6.25 0 0.99 0.9 0.9 0.9 1.0 1.0 0.00 3 Perisher 33/11 8/10 8/10 12 0.95 9.7 9.5 9.4 9.3 9.2 0.01 9 Snowy Adit 11 132/66/11 10 0 0.77 0.1 0.1 0.1 0.1 0.1 0.00 1 Snowy Adit 66 132/66/11 30 0 0.93 11.5 11.6 11.7 11.7 11.8 0.00 2 Thredbo 33/11 16 16 19.2 0.97 15.0 15.0 15.0 15.1 15.1 0.00 7 2.5.9.4 Subtransmission Single Diagram of Munyang area See the Cooma diagram on Page 92. For Public Release December 2015 Page 95 of 183

2.5.10 Queanbeyan Supply Area 2.5.10.1 Description of Queanbeyan area The Queanbeyan area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation. QUEANBEYAN Identified System Limitations SYSTEM LIMITATION Sutton ZS - Single transformer substation with insufficient backup support via the 11 from Bungendore for loss of the transformer Refer to DAPR Section Section 3.2 2.5.10.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 82A 66 82B 66 82F 66 82G 66 Feeder Origin TransGrid Queanbeyan 132/66 STS TransGrid Queanbeyan 132/66 STS TransGrid Queanbeyan 132/66 STS TransGrid Queanbeyan 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Queanbeyan South ZS 30 3.0 3.0 3.0 3.0 3.0 37 5.1 5.1 5.1 5.1 5.1 Queanbeyan South ZS 30 18.4 18.4 18.4 18.5 18.5 37 23.4 23.4 23.4 23.4 23.4 Oaks Estate ZS 49 0.0 0.0 0.0 0.0 0.0 49 0.0 0.0 0.0 0.0 0.0 Captains Flat ZS 12 2.1 2.1 2.1 2.1 2.1 19 2.7 2.7 2.7 2.7 2.7 82K/1 66 TransGrid Queanbeyan 132/66 STS Sutton / Bungendore Tee 15 7.8 7.8 7.8 7.8 7.8 25 10.8 10.8 10.8 10.8 10.8 82K/1 66 Sutton / Bungendore Tee Bungendore ZS 15 4.9 4.9 4.9 5.0 5.0 25 7.1 7.1 7.1 7.1 7.1 82K/3 66 Sutton / Bungendore Tee Sutton ZS 15 2.8 2.8 2.8 2.8 2.8 25 3.5 3.6 3.6 3.6 3.6 82M 66 TransGrid Queanbeyan 132/66 STS Oaks Estate ZS 20 13.0 13.0 13.0 13.0 13.0 20 13.9 13.9 13.9 13.9 13.9 830:QSH 66 Queanbeyan South ZS Googong Dam ZS 15 3.0 3.0 3.0 3.0 3.0 25 5.1 5.1 5.1 5.1 5.1 2.5.10.3 STS and ZS load forecast SUMMER Queanbeyan Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bungendore 66/11 7.5/10 7.5/10 11 1.00 4.8 4.7 4.7 4.7 4.6 2.11 2 Captains Flat 66/22 5 5 5.5 1.00 1.9 1.9 1.8 1.8 1.8 0.57 3 Googong Dam 66/11 10/12.5 7.5/10 11 1.00 2.5 2.5 2.5 2.5 2.5 1.40 2 Googong Town 132/11 30 0 0.95 0.0 8.6 9.6 10.6 11.6 0.00 Oaks Estate 66/11 30 20/30 33 0.92 15.2 15.3 15.3 15.3 15.3 1.77 3 Queanbeyan South 66/11 20/25/30 20/25/30 33 0.97 18.1 18.0 18.0 17.9 17.9 2.98 12 Sutton 66/11 8 0 0.97 2.5 2.5 2.5 2.5 2.5 1.22 2 WINTER Queanbeyan Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bungendore 66/11 7.5/10 7.5/10 12 0.99 8.4 8.4 8.4 8.5 8.5 2.11 10 Captains Flat 66/22 5 5 6 1.00 3.2 3.2 3.2 3.2 3.2 0.57 1 Googong Dam 66/11 10/12.5 7.5/10 12 0.99 5.5 5.5 5.5 5.5 5.5 1.40 2 Googong Town 132/11 30 0 0.95 0.0 7.8 8.8 9.8 10.8 0.00 Oaks Estate 66/11 30 20/30 36 0.97 17.2 17.3 17.4 17.5 17.6 1.77 13 Queanbeyan South 66/11 20/25/30 20/25/30 36 0.99 25.7 25.8 25.8 25.8 25.8 2.98 4 Sutton 66/11 8 0 1.00 3.6 3.6 3.6 3.6 3.7 1.22 4 For Public Release December 2015 Page 96 of 183

2.5.10.4 Subtransmission Single Diagram of Queanbeyan area Yass 976/2(Y) Murrumbateman QUEANBEYAN Spring Flat 976/2(M) 976/2 Notes 1) System Limitation Location See DAPR2015 Section 3.2 n.o. n.o. 977/1 976/1(C) 976/1(Q) 977/3 6 Note 1 Sutton Capital Wind Farm (141MW) / Kangaroo Valley P.S. Yass Upper Tumut Lower Tumut Wallaroo 9 (Future) 7 1 CANBERRA A-3 Gold Creek (ACTEW) A-2 Latham (ACTEW) A-1 Woden (ACTEW) 82K/3 82K/1 82K/1 Woodlawn/ Goulburn 82K/2 n.o. Bungendore Oaks Estate 3C 82M/82F QUEANBEYAN 82A 82B Theodore (ACTEW) Gilmore 97H (ACTEW) 97F 975 Queanbeyan South Future Googong Town (Near Completion) 830:QSH Googong Dam 82G n.o. WILLIAMSDALE 978 97D TransGrid s 132/66 330/132 Cooma Co-located EE/TG ZS facilities 330 Switching Station Essential Energy Zone s 66/11 66/22 132/22 Transmission & Sub-trans. s Transgrid 330 132 Essential Energy 132 66 Captains Flat Dual line For Public Release December 2015 Page 97 of 183

2.5.11 Goulburn Supply Area 2.5.11.1 Description of Goulburn area Essential Energy s Goulburn (Rocky Hill) 132/66/33 substation is supplied via Essential Energy s 132 transmission lines from TransGrid s subtransmission substations at Marulan and Yass respectively. GOULBURN Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.11.2 Subtransmission feeder load forecast Feeder # Feeder Voltage Feeder Origin Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 972 132 TransGrid Marulan 330/132 STS Goulburn 132/66/33 STS 180 48.7 48.7 48.7 48.7 48.8 202 50.0 50.0 50.0 50.0 50.0 9UR 132 TransGrid Marulan 330/132 STS Taralga Wind Farm 140 102.0 102.0 102.0 102.0 102.0 157 102.0 102.0 102.0 102.0 102.0 843 66 Clinton St ZS Goulburn North ZS 46 0.0 0.0 0.0 0.0 0.0 52 0.0 0.0 0.0 0.0 0.0 82K/2 66 Woodlawn ZS Bungendore ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 840:GOU 66 Goulburn 132/66/33 STS Goulburn North ZS 61 12.2 12.2 12.2 12.2 12.3 68 13.3 13.4 13.4 13.4 13.4 841:GBN 66 Goulburn North ZS Crookwell ZS 9 5.1 5.1 5.1 5.1 5.1 13 6.1 6.1 6.1 6.1 6.1 850/2 66 Clinton St Tee Clinton St ZS 17 0.0 0.0 0.0 0.0 0.0 30 0.0 0.0 0.0 0.0 0.0 850:GOU 66 860/1 66 Goulburn 132/66/33 STS Goulburn 132/66/33 STS Woodlawn ZS 15 4.9 4.9 4.9 4.9 4.9 25 4.7 4.7 4.7 4.7 4.7 Marulan North Tee 12 5.6 5.6 5.6 5.6 5.6 19 5.9 5.9 5.9 5.9 5.9 860/2 66 Marulan North Tee Marulan South ZS 12 4.2 4.2 4.2 4.2 4.2 19 4.0 4.0 4.0 4.0 4.0 86L 66 Marulan North Tee Marulan North ZS 12 2.0 2.0 2.0 2.0 2.0 19 2.1 2.1 2.1 2.1 2.1 870:GOU 66 GOU12 33 Goulburn 132/66/33 STS Goulburn 132/66/33 STS Clinton St ZS 34 18.5 18.5 18.5 18.5 18.5 41 17.9 17.9 17.9 17.9 17.9 Brisbane Grove ZS 7 2.0 2.0 2.0 2.0 2.0 12 2.3 2.3 2.3 2.3 2.3 A 6MW generator is located at Woodlawn Bioreactor and is connected to the Woodlawn 66/11 ZS at 11 via feeder WOO8642. A 5MW generator is located at Crookwell wind farm and is connected to the Goulburn 132/66 STS at 66 via feeders 841:GBN and 840:GOU. A 107MW generator is located at Taralga wind farm and is connected to the TransGrid Marulan 330/132 STS at 132 via feeder 9UR. For Public Release December 2015 Page 98 of 183

2.5.11.3 STS and ZS load forecast SUMMER Goulburn Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Brisbane Grove 33/22 2.5 2.5 2.75 0.97 1.4 1.4 1.4 1.4 1.4 0.72 2 Clinton Street 66/11 15/19 20/23/30 20.9 0.93 13.8 13.9 14.0 14.0 14.1 1.50 15 Crookwell 66/11 7.5/10 7.5/10 11 0.99 3.3 3.3 3.2 3.2 3.2 1.20 3 Goulburn 132/33 132/33 15/22.5/30 15/22.5/30 33 1.00 7.6 7.7 7.7 7.7 7.7 0.81 3 Goulburn 132/66 132/66 35/60 35/60 66 0.96 27.1 27.2 27.4 27.5 27.6 0.00 8 Goulburn North 66/11 15/19 12.5/16 17.6 0.95 6.2 6.3 6.4 6.5 6.6 1.27 1 Marulan North 66/22 12.5/15 12.5/15 16.5 0.95 4.3 8.4 8.4 8.4 8.4 0.67 2 Marulan South 33 66/33 15 0 0.90 7.8 8.3 8.8 9.3 9.6 0.00 2 Woodlawn 66/11 5 0 1.00 5.0 5.0 5.0 5.0 5.0 0.28 46 WINTER Goulburn Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Brisbane Grove 33/22 2.5 2.5 3 1.00 2.0 2.1 2.2 2.2 2.3 0.72 3 Clinton Street 66/11 15/19 20/23/30 22.8 0.97 14.8 14.9 14.9 15.0 15.0 1.50 16 Crookwell 66/11 7.5/10 7.5/10 12 0.99 4.5 4.5 4.5 4.5 4.4 1.20 12 Goulburn 132/33 132/33 15/22.5/30 15/22.5/30 36 0.99 9.4 9.5 9.6 9.7 9.8 0.81 4 Goulburn 132/66 132/66 35/60 35/60 72 0.98 35.1 35.3 35.4 35.6 35.7 0.00 5 Goulburn North 66/11 15/19 12.5/16 19.2 1.00 7.2 7.5 7.8 8.0 8.3 1.27 2 Marulan North 66/22 12.5/15 12.5/15 18 0.95 7.0 7.7 8.5 8.5 8.5 0.67 5 Marulan South 33 66/33 15 0 0.89 8.8 9.3 9.8 10.3 10.7 0.00 2 Woodlawn 66/11 5 0 1.00 5.7 5.7 5.7 5.7 5.7 0.28 1 For Public Release December 2015 Page 99 of 183

2.5.11.4 Subtransmission Single Diagram of Goulburn area GOULBURN Crookwell Taralga Wind Farm (107MW) G 9UR Bannaby Crookwell Wind Farm G (5MW) MARULAN N.O. N.C. 843 841 N.O. North Goulburn 840 972 36 35 4 Yass 5 8 16 Dapto Avon Clinton Street (Goulburn) N.O. 850/2 870 N.O. N.C. 860 GOULBURN (Rocky Hill) 86L North Marulan Marulan P Quarry Brisbane Grove (Goulburn) N.O. N.C. 850/1 Yass 971/4 723 850/3 Woodlawn 82K/2 G Bioreactor (5MW) (note 1) N.O. Bungendore Notes 1) Power fed to Woodlawn ZSS via distribution feeder WOO8642 TransGrid Subs 330/132 Private P G Generator Essential Energy Zone s 66/11 66/22 132/66/33 33/22 66/33/11 Transmission & Sub-trans. s TransGrid 330 Co-located lines Essential Energy 132 33 66 33 UG For Public Release December 2015 Page 100 of 183

2.5.12 Murrumburrah Supply Area 2.5.12.1 Description of Murrumburrah area The Harden-Murrumburrah area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation at Murrumburrah. MURRUMBURRAH Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.12.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 836 66 Feeder Origin TransGrid Murrumburrah 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Cootamundra ZS 12 10.2 10.2 10.2 10.2 10.2 18 7.4 7.3 7.3 7.2 7.2 837 66 847 66 TransGrid Murrumburrah 132/66 STS TransGrid Murrumburrah 132/66 STS Jugiong ZS 12 2.1 2.1 2.1 2.1 2.1 18 1.6 1.6 1.6 1.6 1.6 Boorowa ZS 10 4.7 4.7 4.7 4.7 4.7 17 3.9 3.9 3.9 3.9 3.9 823/3 66 Bogalara Sw Stn Marilba ZS 12 0.0 0.0 0.0 0.0 0.0 18 0.0 0.0 0.0 0.0 0.0 830/1:PCR 66 Bogalara Sw Stn Parsons Creek ZS 11 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 838/3 66 Jugiong ZS Bogalara Sw Stn 12 0.0 0.0 0.0 0.0 0.0 20 0.0 0.0 0.0 0.0 0.0 83A 66 83D 66 890:YOU 66 TransGrid Murrumburrah 132/66 STS TransGrid Murrumburrah 132/66 STS TransGrid Murrumburrah 132/66 STS Murrumburrah ZS 15 4.6 4.6 4.7 4.7 4.8 25 4.5 4.6 4.6 4.6 4.7 Murrumburrah ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 Young ZS 27 16.8 16.8 16.8 16.8 16.8 30 15.1 15.1 15.0 15.0 14.9 2.5.12.3 STS and ZS load forecast SUMMER Harden - Murrumburrah Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Boorowa 66/11 5 5 5.5 0.95 3.1 3.1 3.1 3.1 3.1 0.83 8 Cootamundra 66/11 15/19 15/19 20.9 0.92 10.2 10.2 10.2 10.2 10.2 1.83 8 Jugiong 66/11 5.9/6.25 5.9/6.5 6.875 0.88 2.1 2.1 2.1 2.1 2.1 0.11 29 Murrumburrah 66/11 8/10 8/10 11 0.95 4.6 4.6 4.7 4.7 4.8 1.06 5 Young 66/11 24/30 30 33 0.91 16.8 16.8 16.8 16.8 16.8 2.65 9 WINTER Harden - Murrumburrah Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Boorowa 66/11 5 5 6 0.98 3.0 3.1 3.1 3.1 3.2 0.83 14 Cootamundra 66/11 15/19 15/19 22.8 0.95 7.4 7.3 7.3 7.2 7.2 1.83 Jugiong 66/11 5.9/6.25 5.9/6.5 7.5 0.96 1.6 1.6 1.6 1.6 1.6 0.11 5 Murrumburrah 66/11 8/10 8/10 12 0.98 4.5 4.6 4.6 4.6 4.7 1.06 5 Young 66/11 24/30 30 36 1.00 15.1 15.1 15.0 15.0 14.9 2.65 12 For Public Release December 2015 Page 101 of 183

2.5.12.4 Subtransmission Single Diagram of Murrumburrah area HARDEN-MURRUMBURRAH 891/6 Cowra n.o. Young 890:YOU Boorowa MURRUMBURRAH 132 (note 1) 836 847 Murrumburrah 847 Bethungra P Barnu Galong Mine Cootamundra n.o. 991 99M Wagga North 837 Yass Jugiong Notes 1) 66KV feeder line numbers between TransGrid and Essential Energy Murrumburrah ZSS are 83D and 83A. 838/3 830/1:PCR n.o. Marilba 823/3 Bogalara Sw Stn 823/1 Parsons Ck/ Gundagai n.o. TransGrid s Essential Energy Zone s Transmission & Sub-trans. s P 132/66 Private 66/11 TransGrid Essential Energy 132 66 For Public Release December 2015 Page 102 of 183

2.5.13 Tumut Supply Area 2.5.13.1 Description of Tumut area The Tumut area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation. TUMUT Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.13.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 827 66 828 66 829 66 Feeder Origin TransGrid Tumut 132/66 STS TransGrid Tumut 132/66 STS TransGrid Tumut 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Tumut ZS 28 18.0 18.0 18.0 18.0 18.0 34 15.8 15.8 15.8 15.8 15.8 Gundagai South ZS 11 7.7 7.7 7.7 7.7 7.7 19 5.8 5.8 5.8 5.8 5.8 Tumut ZS 28 0.0 0.0 0.0 0.0 0.0 34 0.0 0.0 0.0 0.0 0.0 831 66 Gundagai South ZS Nangus ZS 11 1.4 1.4 1.4 1.4 1.4 19 0.6 0.6 0.6 0.6 0.6 848 66 Adelong Tee Adelong ZS 12 1.7 1.7 1.7 1.7 1.7 19 1.4 1.4 1.4 1.4 1.4 830/2:GUN 66 Gundagai South ZS Parsons Creek ZS 12 0.3 0.3 0.3 0.3 0.3 18 0.3 0.3 0.3 0.3 0.3 848/1 66 Adelong Tee Batlow ZS 21 10.4 10.4 10.4 10.4 10.4 25 10.7 10.7 10.7 10.7 10.7 848/2 66 Batlow ZS Tumbarumba ZS 22 8.3 8.3 8.3 8.3 8.3 26 8.4 8.4 8.4 8.4 8.4 848/3 66 850:TAL 66 TransGrid Tumut 132/66 STS TransGrid Tumut 132/66 STS Adelong Tee 21 12.1 12.1 12.1 12.1 12.1 25 12.1 12.1 12.1 12.1 12.1 Talbingo ZS 18 1.4 1.4 1.4 1.4 1.4 22 1.5 1.5 1.5 1.5 1.5 A 15MW generator is located at Jounama Dam and is connected to the TransGrid Tumut 132/66 STS at 66 via feeder 850:TAL. For Public Release December 2015 Page 103 of 183

2.5.13.3 STS and ZS load forecast SUMMER Tumut Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Adelong 66/11 3 2.5 2.75 0.97 1.5 1.5 1.5 1.5 1.5 0.33 6 Batlow 66/11 5 5 5.5 0.87 2.1 2.1 2.1 2.1 2.1 0.41 6 Gundagai South 66/11 8 8 8.8 0.98 5.6 5.6 5.6 5.6 5.6 0.94 4 Nangus 66/11 1 2.8 1.1 0.89 0.9 0.9 0.9 0.9 0.9 0.17 5 Parsons Creek 66/11 3 0 1.00 0.1 0.1 0.1 0.1 0.1 0.02 2 Talbingo 66/11 5 0 0.83 1.3 1.4 1.4 1.4 1.5 0.08 2 Tumbarumba 66/22 10/12.5 10/12.5 18/30 27.5 0.98 8.2 8.2 8.3 8.3 8.3 1.19 18 Tumut 66/11 18/30 10/12.5 10/12.5 27.5 0.92 17.3 17.5 17.8 18.0 18.3 1.66 2 WINTER Tumut Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Adelong 66/11 3 2.5 3 1.00 1.4 1.4 1.4 1.4 1.4 0.33 1 Batlow 66/11 5 5 6 0.96 1.9 1.9 1.9 1.9 1.9 0.41 1 Gundagai South 66/11 8 8 9.6 0.99 4.4 4.4 4.4 4.4 4.5 0.94 Nangus 66/11 1 2.8 1.2 0.98 0.5 0.5 0.4 0.4 0.4 0.17 2 Parsons Creek 66/11 3 0 1.00 0.1 0.1 0.1 0.1 0.1 0.02 2 Talbingo 66/11 5 0 0.86 1.4 1.4 1.5 1.5 1.6 0.08 1 Tumbarumba 66/22 10/12.5 10/12.5 18/30 30 0.99 7.8 7.9 7.9 7.9 7.9 1.19 10 Tumut 66/11 18/30 10/12.5 10/12.5 30 0.95 17.2 17.2 17.3 17.4 17.4 1.66 11 For Public Release December 2015 Page 104 of 183

2.5.13.4 Subtransmission Single Diagram of Tumut area TUMUT Yass Nangus 831 830/2:GUN Parsons Creek n.o. 830/1:PCR n.o. Bogolara Sw Stn Gundagai South 03 Burrinjuck Wagga 828 992 Wagga Gadara 993 TUMUT 827 99P 829 Adelong 848/3 848 097B 051 848/1 G 850:TAL Batlow Tumut 66 07 Canberra Blowering Dam (80MW) G Jounama Dam (14.4MW) 848/2 Lower Tumut (note 1) Talbingo Tumbarumba 66 Murray 64 Upper Tumut Notes 1) Connection into the Talbingo ZS via TG owned 11 feeder TAL No.2. TransGrid s EE Zone s Trans & Sub-trans. s 132/66 Co-located EE/TG ZS facilities 132/11 Essential Energy 66/22 330 Switching Station G 66/11 Private Generator 66 TransGrid 330 132 11 For Public Release December 2015 Page 105 of 183

2.5.14 Yass Supply Area 2.5.14.1 Description of Yass area The Yass area subtransmission system is supplied from TransGrid s 330/132/66 subtransmission substation. YASS Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.5.14.2 Subtransmission feeder load forecast Feeder # Feeder Voltage Feeder Origin 971(1) 132 Cullerin Range Wind Farm 971(2) 132 TransGrid Yass 330/132/66 STS Feeder Destination Goulburn 132/66/33 STS Cullerin Range Wind Farm Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 106 0.0 0.0 0.0 0.0 0.0 119 0.0 0.0 0.0 0.0 0.0 106 76.5 76.5 76.5 76.5 76.5 119 76.5 76.5 76.5 76.5 76.5 971(3) 132 Cullerin Range Wind Farm Gunning Wind Farm 128 46.5 46.5 46.5 46.5 46.5 143 46.5 46.5 46.5 46.5 46.5 976/2 (M) 132 TransGrid 132 976/2(Y) / Murrumbateman Tee Murrumbateman ZS 42 5.0 5.1 5.1 5.1 5.1 82 5.9 5.9 5.9 5.9 5.9 824 66 TransGrid Yass 330/132/66 STS Yass ZS 20 12.5 12.5 12.5 12.6 12.6 24 12.3 12.3 12.3 12.3 12.3 823/5 66 Yass ZS Marilba ZS 12 1.3 1.3 1.3 1.3 1.3 18 1.4 1.4 1.4 1.4 1.4 A 30MW generator is located at Cullerin Range wind farm and is connected to the TransGrid Yass 330/132/66 STS at 132 via feeder 971. A 47MW generator is located at Gunning wind farm and is also connected to the TransGrid Yass 330/132/66 STS at 132 via feeder 971. 2.5.14.3 STS and ZS load forecast SUMMER Yass Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Marilba 66/11 3 1 1.1 0.98 1.1 1.1 1.0 1.0 1.0 0.41 11 Murrumbateman 132/22 10/12.5 0 0.98 4.9 4.9 5.0 5.0 5.0 1.70 4 Yass 66/22 10 10 11 0.96 10.5 10.5 10.5 10.5 10.5 2.10 7 WINTER Yass Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Marilba 66/11 3 1 1.2 0.99 1.2 1.2 1.2 1.2 1.2 0.41 12 Murrumbateman 132/22 10/12.5 0 1.00 6.4 6.5 6.5 6.5 6.5 1.70 7 Yass 66/22 10 10 12 0.97 11.4 11.3 11.3 11.2 11.2 2.10 11 There are multiple load transfer points in the Yass area to other Zone s that can be utilised with the loss of a single Yass transformer. For Public Release December 2015 Page 106 of 183

2.5.14.4 Subtransmission Single Diagram of Yass area YASS Cowra Harden - Murrumburrah 99M 973 999 Marilba 823/5 n.o. Yass 823/3 824 Jugiong YASS 838/3 3 Bogolara Sw Stn 970 838/1 990 Wagga Wagga 823/1 Lower Tumut Sw. Stn Parsons Ck/ Gundagai 830/1 n.o. 830/2 Tumut 992 Isolated BURRINJUCK Upper Tumut Sw Stn 2 9 Canberra 976/2(Y) 976/2(M) Murrumbateman TransGrid Subs Essential Energy Zone s 330/132/66 132/66 66/22 132/22 Private Generator 66 Switching Station G Dual line Bannaby G Gunning Wind Farm (47MW) 61 971(3) 971(1) Goulburn 971(2) 4 5 Cullerin Range Wind Farm (30MW) G n.o. Marulan 330 976/2 n.o. Canberra/ Queanbeyan Transmission & Sub-trans. s TransGrid Essential Energy 330 66 132 132 For Public Release December 2015 Page 107 of 183

2.6 Southern Region 2.6.1 Parkes Supply Area 2.6.1.1 Description of Parkes area The Parkes area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation via a 66 89L/89G ring to the Parkes Town with a feed to Peak Hill and Tomingley Mine s. PARKES Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.1.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 300 132 898 66 Feeder Origin TransGrid Parkes 132/66 STS TransGrid Parkes 132/66 STS Feeder Destination North Parkes Mine ZS Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 95 32.2 32.2 32.2 32.2 32.2 117 32.3 32.3 32.3 32.3 32.3 Trundle ZS 11 2.6 2.6 2.6 2.6 2.6 17 2.3 2.3 2.3 2.3 2.3 899 66 Parkes Town ZS Peak Hill ZS 13 6.0 6.0 6.0 6.0 6.0 20 5.5 5.5 5.5 5.5 5.5 89G 66 89L 66 TransGrid Parkes 132/66 STS TransGrid Parkes 132/66 STS Parkes Town ZS 68 11.6 11.6 11.6 11.7 11.7 76 8.9 8.9 8.9 8.9 9.0 Parkes Town ZS 38 11.4 11.4 11.4 11.4 11.5 43 8.8 8.8 8.8 8.8 8.8 89M 66 Peak Hill ZS Tomingley Mine ZS 17 5.1 5.1 5.1 5.1 5.1 28 5.1 5.1 5.1 5.1 5.1 2.6.1.3 STS and ZS load forecast SUMMER Parkes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Parkes Town 66/11 30 30 33 0.95 17.6 17.6 17.5 17.5 17.5 3.63 5 Peak Hill 66/11 5 5 5.5 0.96 1.6 1.6 1.6 1.6 1.6 0.58 5 Trundle 66/22 5 5 5.5 0.98 2.1 2.1 2.1 2.1 2.1 0.81 8 WINTER Parkes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Parkes Town 66/11 30 30 36 0.98 14.8 14.9 14.9 15.0 15.1 3.63 5 Peak Hill 66/11 5 5 6 0.99 1.5 1.5 1.4 1.4 1.4 0.58 2 Trundle 66/22 5 5 6 1.00 1.6 1.6 1.6 1.5 1.5 0.81 4 For Public Release December 2015 Page 108 of 183

2.6.1.4 Subtransmission Single Diagram of Parkes area 894:CDN Solar Thermal G Lake Cargelligo Notes 1. Voltage regulator located in ZS. TransGrid Subs 132/66 PARKES, FORBES Tomingley Mine P Peak Hill 89M Trundle Goonumbla North Parkes Mine P 94K Wellington 300 899 898 Condoblin 89L Manildra (Note 1) PARKES Parkes Town 89G 897:CDN 94U (Note 1) West Jemalong G Solar Thermal (under construction) 89H 896:WJL 858 Forbes Town 859 998 FORBES 893/5 Paytens Bridge n.o. Cowra Essential Energy Zone s Transmission & Sub-trans. s 66/22 66/11 P G Private Generator TransGrid Essential Energy 132 132 66 22 11 For Public Release December 2015 Page 109 of 183

2.6.2 Forbes Supply Area 2.6.2.1 Description of Forbes area The Forbes area subtransmission system is supplied from TransGrid s Forbes 132/66 subtransmission substation. FORBES Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.2.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 858 66 859 66 893/5 66 Feeder Origin TransGrid Forbes 132/66 STS TransGrid Forbes 132/66 STS TransGrid Forbes 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Forbes Town ZS 28 16.3 16.4 16.4 16.5 16.5 34 10.1 10.1 10.1 10.2 10.2 Forbes Town ZS 28 0.0 0.0 0.0 0.0 0.0 34 0.0 0.0 0.0 0.0 0.0 Payten's Bridge ZS 12 2.7 2.7 2.7 2.7 2.7 18 2.0 2.0 2.0 2.0 2.0 894:CDN 66 Condobolin ZS Lake Cargelligo ZS 15 3.9 3.9 3.9 3.9 3.9 25 3.5 3.5 3.5 3.5 3.5 896:WJL 66 TransGrid Forbes 132/66 STS West Jemalong ZS 11 5.4 5.4 5.4 5.5 5.5 18 4.7 4.7 4.7 4.7 4.7 897:CDN 66 West Jemalong ZS Condobolin ZS 20 12.3 12.3 12.4 12.4 12.4 24 11.4 11.4 11.5 11.5 11.5 89H 66 TransGrid Forbes 132/66 STS West Jemalong ZS 43 9.8 9.8 9.8 9.9 9.9 54 8.4 8.4 8.4 8.5 8.5 2.6.2.3 STS and ZS load forecast SUMMER Forbes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Condobolin 66/22 10 10 11 0.99 8.6 8.7 8.8 8.9 8.9 1.64 5 Forbes Town 66/11 18/30 15/30 33 0.99 13.4 13.4 13.4 13.4 13.4 2.14 8 Lake Cargelligo 66/22 8 5 5.5 0.99 3.5 3.5 3.5 3.5 3.6 0.81 9 Paytens Bridge 66/11 5 5 5.5 0.94 3.0 3.0 3.0 3.0 3.0 0.32 3 West Jemalong 66/11 4 4 4.4 0.94 1.9 1.9 1.9 1.9 1.9 0.14 9 WINTER Forbes Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Condobolin 66/22 10 10 12 0.93 7.1 7.1 7.1 7.1 7.1 1.64 25 Forbes Town 66/11 18/30 15/30 36 0.99 10.6 10.6 10.6 10.6 10.6 2.14 5 Lake Cargelligo 66/22 8 5 6 0.93 2.8 2.8 2.8 2.8 2.8 0.81 8 Paytens Bridge 66/11 5 5 6 0.97 1.8 1.8 1.8 1.8 1.8 0.32 13 West Jemalong 66/11 4 4 4.8 0.97 1.5 1.5 1.6 1.6 1.6 0.14 2 2.6.2.4 Subtransmission Single Diagram of Forbes area See the Parkes diagram on Page 109. For Public Release December 2015 Page 110 of 183

2.6.3 Cowra Supply Area 2.6.3.1 Description of Cowra area The Cowra area subtransmission system is supplied from TransGrid s Cowra 132/66 subtransmission substation. Normal 66 system operation supplies from Cowra to Young open point and includes Bendick Murrell, Monteagle and connection to Wyangala Power Station. COWRA Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.3.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 865 66 863:CWD 66 866:COW 66 891/1 66 Feeder Origin TransGrid Cowra 132/66 STS TransGrid Cowra 132/66 STS TransGrid Cowra 132/66 STS TransGrid Cowra 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Cowra Town ZS 15 9.8 9.8 9.8 9.8 9.8 25 7.5 7.5 7.5 7.5 7.5 Canowindra ZS 9 5.6 5.6 5.6 5.6 5.6 15 3.5 3.5 3.5 3.5 3.5 Cowra Town ZS 15 8.7 8.7 8.7 8.7 8.7 25 6.7 6.7 6.7 6.7 6.7 Wyangala Dam Tee 20 2.0 2.0 2.0 2.0 2.0 24 1.7 1.7 1.7 1.7 1.7 891/2 66 Wyangala Dam Tee Wyangala Dam 19 0.0 0.0 0.0 0.0 0.0 33 0.0 0.0 0.0 0.0 0.0 891/5 66 Monteagle Tee Monteagle ZS 13 0.8 0.8 0.8 0.8 0.8 22 0.7 0.7 0.7 0.7 0.7 891/6 66 Monteagle Tee Young ZS 19 0.0 0.0 0.0 0.0 0.0 33 0.0 0.0 0.0 0.0 0.0 891/7 66 Bendick Murrell Tee Bendick Murrell ZS 19 1.7 1.7 1.7 1.7 1.7 33 1.1 1.1 1.1 1.1 1.1 891:BMU 66 Wyangala Dam Tee Bendick Murrell Tee 19 2.3 2.3 2.3 2.3 2.3 33 1.7 1.7 1.7 1.7 1.7 891:BMU 66 Bendick Murrell Tee Monteagle Tee 19 0.7 0.7 0.7 0.7 0.7 33 0.6 0.6 0.6 0.6 0.6 893/1 66 TransGrid Cowra 132/66 STS Grenfell Tee 12 4.2 4.2 4.2 4.2 4.2 18 3.6 3.6 3.6 3.6 3.6 893/4 66 Grenfell Tee Payten'sBridge ZS 12 0.0 0.0 0.0 0.0 0.0 18 0.0 0.0 0.0 0.0 0.0 893/6 66 Grenfell Tee Grenfell ZS 12 4.3 4.3 4.3 4.3 4.3 18 3.7 3.7 3.7 3.7 3.7 A 23MW generator is located at Wyangala Dam and is connected to the TransGrid Cowra 132/66 STS at 66 via feeder 891. For Public Release December 2015 Page 111 of 183

2.6.3.3 STS and ZS load forecast SUMMER Cowra Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bendick Murrell 66/11 2.8 0 0.89 1.5 1.6 1.6 1.6 1.6 0.35 2 Canowindra 66/11 5 8 5.5 0.94 5.6 5.6 5.6 5.6 5.6 1.06 4 Cowra 66/11 15/30 15/30 33 0.99 19.3 19.3 19.3 19.3 19.3 2.25 6 Grenfell 66/11 8 5 5.5 0.95 4.7 5.0 5.4 5.7 6.0 0.89 5 Monteagle 66/11 1 0 0.85 0.9 0.9 0.9 0.9 1.0 0.23 8 WINTER Cowra Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bendick Murrell 66/11 2.8 0 0.93 1.2 1.2 1.1 1.1 1.1 0.35 4 Canowindra 66/11 5 8 6 0.99 4.2 4.2 4.2 4.2 4.3 1.06 7 Cowra 66/11 15/30 15/30 36 1.00 13.5 13.5 13.5 13.5 13.6 2.25 2 Grenfell 66/11 8 5 6 0.95 4.4 4.5 4.5 4.5 4.6 0.89 12 Monteagle 66/11 1 0 0.95 0.8 0.8 0.9 0.9 0.9 0.23 4 For Public Release December 2015 Page 112 of 183

2.6.3.4 Subtransmission Single Diagram of Cowra area Forbes132 Paytens Bridge,Forbes COWRA Canowindra 998 893/4 863:CWD n.o. 893/4 COWRA Cowra Town (note 1) Grenfell 893/1 891/1 893/6 891/2 Wyangala Dam (22.5MW) G 891:BMU 891/7 999 973 Bendick Murrell Monteagle 891/5 891:BMU 891/6 n.o. Young Notes 1) 66KV feeder line numbers between TG Cowra SS and Cowra Town ZS are 865 and 866:COW. Yass TransGrid Subs EE Zone s Trans & Sub-trans s G 132/66 Private Generator 66/11 TransGrid Essential Energy 132 66 For Public Release December 2015 Page 113 of 183

2.6.4 Temora Supply Area 2.6.4.1 Description of Temora area Essential Energy s Temora 132/66 subtransmission substation is supplied from TransGrid s Wagga Wagga North 132/66 subtransmission substation via an Essential Energy 132 transmission line. TEMORA Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.4.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 901 132 Temora 132/66 STS Lake Cowal 128 32.1 32.2 32.3 32.3 32.4 143 32.1 32.1 32.1 32.2 32.2 4 66 Temora 132/66 STS Temora Town ZS 15 6.5 6.4 6.3 6.2 6.2 25 5.9 5.9 5.9 5.8 5.8 5 66 Temora 132/66 STS Ariah Park Tee 21 14.1 11.6 11.6 11.6 11.6 25 12.0 9.8 9.8 9.8 9.8 6 66 Temora 132/66 STS Temora Town ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 20-60 66 Ariah Park Tee West Wyalong ZS 21 11.9 9.8 9.8 9.8 9.8 25 9.8 7.9 7.9 7.9 7.9 60-70 66 West Wyalong ZS Anona ZS 7 1.4 1.4 1.4 1.4 1.4 12 1.0 1.0 1.0 1.0 1.0 80-140 66 Ariah Park Tee Ariah Park ZS 15 2.3 1.9 1.9 1.9 1.9 25 2.4 1.9 1.9 1.9 1.9 80-140 66 Ariah Park ZS Ardlethan ZS 11 0.6 0.6 0.7 0.7 0.7 19 0.6 0.6 0.5 0.5 0.5 835/J 66 Junee Reefs ZS Junee ZS 12 0.0 0.0 0.0 0.0 0.0 18 0.0 0.0 0.0 0.0 0.0 835/T 66 Temora 132/66 STS Junee Reefs ZS 12 0.2 0.2 0.2 0.2 0.2 18 0.2 0.2 0.2 0.2 0.2 For Public Release December 2015 Page 114 of 183

2.6.4.3 STS and ZS load forecast SUMMER Temora Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Anona 66/22 3 2.5 2.75 1.00 1.4 1.4 1.4 1.4 1.4 0.30 19 Ardlethan 66/11 2.5 3 2.75 0.96 0.6 0.6 0.7 0.7 0.7 0.18 5 Ariah Park 66/11 3 3 3.3 0.98 0.8 0.8 0.8 0.8 0.8 0.22 17 Junee Reefs 66/11 3 0 0.90 0.2 0.2 0.2 0.2 0.2 0.04 2 Temora 132/66 132/66 35/60 35/60 66 1.00 16.9 16.6 16.3 16.0 15.8 0.00 3 Temora 66/11 66/11 6.75/10 10/12.5 11 0.96 6.5 6.4 6.3 6.2 6.2 1.47 5 West Wyalong 66/22 10/12.5 10/12.5 13.75 0.96 8.2 8.2 8.2 8.2 8.2 1.28 10 WINTER Temora Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Anona 66/22 3 2.5 3 0.98 1.0 1.0 1.0 1.0 1.0 0.30 6 Ardlethan 66/11 2.5 3 3 0.99 0.6 0.6 0.5 0.5 0.5 0.18 2 Ariah Park 66/11 3 3 3.6 1.00 0.7 0.7 0.7 0.7 0.7 0.22 3 Junee Reefs 66/11 3 0 0.97 0.2 0.2 0.2 0.2 0.2 0.04 4 Temora 132/66 132/66 35/60 35/60 72 1.00 14.4 14.3 14.2 14.2 14.1 0.00 7 Temora 66/11 66/11 6.75/10 10/12.5 12 0.99 5.9 5.9 5.9 5.8 5.8 1.47 9 West Wyalong 66/22 10/12.5 10/12.5 15 0.97 5.7 5.6 5.6 5.5 5.4 1.28 5 For Public Release December 2015 Page 115 of 183

2.6.4.4 Subtransmission Single Diagram of Temora area WAGGA TEMORA Temora 132 Project 20-60 901 Anona 60-70 West Wyalong P Lake Cowal Temora 835/T TEMORA 9J5 Junee Reefs Coolamon 30-90 835/J Bethungra 834 Junee 99U 9J5 20-60 901 WAGGA North 991 Ardlethan 80-140 9R6 9R5 Ariah Park Temora Town Coolamon #5 #4 #6 30-90 99U TEMORA 132/66 835/T 83F Junee Reefs Cootamundra n.o 850:BET 835/J Bethungra n.o 834:JUN Junee 991 Harden- Murrumburrah WAGGA North 990 Yass For Wagga Wagga City see separate diagram P Darlington Point Yanco TransGrid SS EE Zone s Trans & Sub-trans s 132/66 330/132 132 Sw Stn Private 63 994 99F WAGGA (Copland St) 9R1 URANQUINTY G 99A Uranquinty Gas fired Finley Power Station (664MW) 9R2 9R6 99W 62 Jindera 132/66 66/22 66/11 99X 996 9R5 WAGGA 330 (Gregadoo) ANM Albury Morven 132/66/11 051 TransGrid 993 330 132 Gadara (Tumut) Lower Tumut Switching Station Essential Energy 132 66 For Public Release December 2015 Page 116 of 183

2.6.5 Wagga North Supply Area 2.6.5.1 Description of Wagga North area The Wagga Wagga area subtransmission system is supplied from two separate TransGrid 132/66 subtransmission substations at Wagga Wagga (Copland St) and Wagga North. The transmission system emanating from Wagga North supplies many smaller outlying areas. WAGGA NORTH Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.5.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 99U 132 9J5 132 Feeder Origin TransGrid Wagga North 132/66 STS TransGrid Wagga North 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Temora 132/66 STS 128 60.4 30.8 31.0 31.0 31.0 143 54.8 28.3 28.3 28.3 28.3 Junee 132/66/11 ZS 140 0.0 29.4 29.4 29.4 29.4 157 0.0 26.5 26.5 26.5 26.5 9J5 132 Junee 132/66/11 ZS Temora 132/66 STS 140 11.6 17.9 17.9 17.9 17.9 157 9.6 16.6 16.6 16.6 16.6 30-90 66 Junee ZS Coolamon ZS 6 5.3 5.4 5.4 5.4 5.4 9 3.7 3.7 3.7 3.7 3.7 834:JUN 66 Junee ZS Bethungra ZS 11 1.2 1.2 1.2 1.2 1.2 19 1.0 1.0 1.0 1.0 1.0 83C 66 TransGrid Wagga North 132/66 STS Oura ZS 24 4.3 4.4 4.4 4.4 4.5 28 3.3 3.3 3.3 3.2 3.2 83C 66 Oura ZS Forest Hill ZS 34 0.0 0.0 0.0 0.0 0.0 39 0.0 0.0 0.0 0.0 0.0 83G 66 TransGrid Wagga North 132/66 STS Bomen ZS 34 23.1 23.2 23.3 23.5 23.6 39 17.0 17.1 17.1 17.2 17.2 83J 66 Bomen ZS Cartwrights Hill ZS 34 7.6 7.7 7.8 7.9 8.0 39 5.8 5.9 6.0 6.0 6.1 850:BET 66 Bethungra ZS Cootamundra ZS 12 0.0 0.0 0.0 0.0 0.0 18 0.0 0.0 0.0 0.0 0.0 CHI2527 33 Cartwrights Hill ZS Euberta ZS 4 2.2 2.1 2.1 2.1 2.1 6 1.1 1.1 1.1 1.1 1.1 CHI2527 33 Euberta ZS Ganmurra ZS 4 0.5 0.4 0.4 0.4 0.4 6 0.4 0.4 0.4 0.4 0.4 Mates Gully 33 Oura ZS Mates Gully ZS 3 1.5 1.5 1.5 1.5 1.5 6 1.3 1.3 1.3 1.3 1.3 Mates Gully 33 Mates Gully ZS Tarcutta ZS 4 0.9 0.9 0.9 0.9 0.9 7 0.9 0.9 0.9 0.9 0.9 For Public Release December 2015 Page 117 of 183

2.6.5.3 STS and ZS load forecast SUMMER Wagga North Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Bethungra 66/11 3 3 3.3 0.94 0.9 0.9 0.9 0.9 0.9 0.07 4 Bomen 66/11 20/30 20/30 33 1.00 10.9 11.0 11.1 11.3 11.3 0.11 55 Cartwrights Hill 11 66/11 6.75/10 6.75/10 11 0.96 7.4 7.5 7.6 7.7 7.8 0.51 5 Cartwrights Hill 33 11/33 5 4 4.4 0.96 1.9 1.9 1.9 1.9 1.9 0.00 2 Coolamon 66/11 8 8 8.8 0.93 5.0 5.1 5.1 5.1 5.1 0.00 Euberta 33/11 4 1 1.1 0.90 1.7 1.7 1.7 1.7 1.7 0.26 3 Ganmurra 33/11 2.5 0 0.96 0.4 0.4 0.4 0.3 0.3 0.10 2 Junee 66/11 10/12.5 10/12.5 13.75 0.96 6.5 6.5 6.5 6.5 6.5 1.04 12 Mates Gully 33/11 1 0 0.93 0.5 0.5 0.5 0.5 0.5 0.07 1 Oura 11/33 11/33 4 2 2.2 0.90 1.3 1.3 1.3 1.3 1.3 0.00 2 Oura 66/11 66/11 5/6.9 5/6.9 7.59 0.93 4.2 4.3 4.3 4.3 4.4 0.22 4 Tarcutta 33/11 1 1 1.1 0.90 0.9 0.9 0.9 0.9 0.9 0.32 3 WINTER Wagga North Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Bethungra 66/11 3 3 3.6 0.96 0.7 0.7 0.7 0.7 0.7 0.07 Bomen 66/11 20/30 20/30 36 0.92 11.0 11.1 11.2 11.3 11.4 0.11 4 Cartwrights Hill 11 66/11 6.75/10 6.75/10 12 0.99 5.6 5.7 5.8 5.8 5.9 0.51 4 Cartwrights Hill 33 11/33 5 4 4.8 1.00 1.1 1.1 1.1 1.1 1.1 0.00 3 Coolamon 66/11 8 8 9.6 1.00 3.4 3.4 3.4 3.4 3.4 0.00 3 Euberta 33/11 4 1 1.2 0.95 0.7 0.7 0.7 0.7 0.7 0.26 2 Ganmurra 33/11 2.5 0 0.99 0.4 0.4 0.4 0.4 0.4 0.10 1 Junee 66/11 10/12.5 10/12.5 15 0.99 5.9 5.9 5.8 5.8 5.8 1.04 9 Mates Gully 33/11 1 0 0.98 0.3 0.3 0.3 0.3 0.3 0.07 2 Oura 11/33 11/33 4 2 2.4 0.90 1.3 1.3 1.4 1.4 1.4 0.00 4 Oura 66/11 66/11 5/6.9 5/6.9 8.28 0.99 3.2 3.2 3.2 3.1 3.1 0.22 6 Tarcutta 33/11 1 1 1.2 0.90 0.9 0.9 0.9 0.9 0.9 0.32 2 For Public Release December 2015 Page 118 of 183

2.6.5.4 Subtransmission Single Diagram of Wagga North area Ganmurra Euberta Future Arrangement (Near Completion) Hammond Ave WAGGA WAGGA CITY CHI2527 Cartwrights Hill n.o. 83J Coolamon 30-90 Bomen n.o. Cootamundra TEMORA 850:BET 83G Junee WAGGA North 83C Bethungra 834:JUN (Under Construction) Copland St Kywong/ Narrandera 840/3 n.o. 8WG 8WJ Kooringal Lockhart Tee Regulator Station Re-energized Ex-Tenandra Forest Hill 840/1 843/5 Ashmont 843/3 843/6 Note 1 Morrow Street 8WM #4 Note 1 83L Hammond Ave De-energized Ex-Tenandra De-energized Ex Junee Note 1#2 Forest Hill 83C n.o. Oura 840/2 Lockhart Bulgary Bourkelands 8W0 83M Note 1 845/4 83M Note 1 n.o. Kooringal n.o. WAGGA (Copland St) Forest Hill Mates Gully Uranquinty 83M/1 Tarcutta Henty 83M/2 Culcairn ANM Albury 83M/3 Morven 996 Holbrook Wagga 330 Notes 1. System Limitation Location See DAPR2015 Section 3.1 TransGrid ZSS EE Zone s Trans & Sub-trans. s 132/66 66/11/33 66/11 TransGrid Essential Energy 132 66/22 33/11 132 66 132/66 33 For Public Release December 2015 Page 119 of 183

2.6.6 Wagga Wagga (Copland St) Supply Area 2.6.6.1 Description of Wagga Wagga area The Wagga Wagga area subtransmission system is supplied from two separate TransGrid 132/66 subtransmission substations at Wagga Wagga (Copland St) and Wagga North. The transmission system emanating from Wagga Wagga (Copland St) supplies the majority of the Wagga Wagga city load as well as supplying the areas as far south as Holbrook and as far west as Lockhart. WAGGA WAGGA Identified System Limitations SYSTEM LIMITATION Refer to DAPR Section Compromised protection and reliability involving tee to Hammond Ave ZS Section 3.1 Compromised protection and reliability involving tee 1 to Kooringal ZS Section 3.1 Compromised protection and reliability involving tee 2 to Kooringal ZS Section 3.1 Thermal limitation on 845/4 Copland St to Bourkelands ZS line Section 3.1 Total loss of supply at Morrow ZS for loss of feeder 8WM Section 3.1 2.6.6.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 83L 66 Hammond Ave ZS Bomen ZS 54 0.0 0.0 0.0 0.0 0.0 62 0.0 0.0 0.0 0.0 0.0 83M 66 840/1 66 TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) Uranquinty ZS 28 7.3 7.3 7.3 7.3 7.3 34 7.9 7.9 7.9 7.9 7.9 Bulgary ZS 15 4.1 4.1 4.1 4.1 4.1 24 4.2 4.2 4.2 4.2 4.2 840/2 66 Bulgary ZS Lockhart ZS 15 4.1 4.1 4.1 4.1 4.1 25 4.0 4.0 4.0 4.0 4.0 840/3 66 Lockhart Tee Kywong ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 8W5 66 Uranquinty ZS Henty ZS 15 2.6 2.6 2.6 2.6 2.6 25 3.1 3.1 3.1 3.1 3.1 8W6 66 Henty ZS Culcairn ZS 15 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 8W9 66 8WF 66 TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) Ashmont ZS 34 20.1 20.1 20.1 20.1 20.1 39 19.4 19.4 19.4 19.4 19.4 Bourkelands ZS 34 11.5 11.5 11.5 11.5 11.5 39 11.7 11.7 11.7 11.7 11.7 8WM 66 Hammond Ave ZS Morrow St ZS 34 13.0 13.0 13.0 13.0 13.0 39 12.3 12.3 12.3 12.3 12.3 8WO 66 Ashmont ZS Bourkelands ZS 34 0.5 0.5 0.5 0.5 0.5 39 1.0 1.0 1.0 1.0 1.0 8WP 66 Morrow St ZS Cartwrights Hill ZS 34 0.0 0.0 0.0 0.0 0.0 39 0.0 0.0 0.0 0.0 0.0 8WR 66 8WT 66 8WG 66 8WH 66 8WJ 66 TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) TransGrid Wagga 132/66 STS (Copland St) Hammond Ave ZS 52 15.0 15.0 15.0 15.0 15.0 60 14.9 14.9 14.9 14.9 14.9 Hammond Ave ZS 52 14.9 14.9 14.9 14.9 14.9 60 14.7 14.7 14.7 14.7 14.7 Kooringal ZS 34 16.8 16.8 8.4 8.4 8.4 39 17.0 8.4 8.4 8.4 8.4 Kooringal ZS 34 0.0 0.0 8.7 8.7 8.7 39 0.0 8.6 8.6 8.6 8.6 Forest Hill ZS 34 6.8 6.8 6.8 6.8 6.8 39 6.6 6.6 6.6 6.6 6.6 For Public Release December 2015 Page 120 of 183

2.6.6.3 STS and ZS load forecast SUMMER Wagga (Copland St) Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Ashmont 66/11 20/30 20/30 33 0.94 20.8 21.3 21.7 22.1 22.4 2.00 7 Bourkelands 66/11 10/13 10/13 14.3 0.97 12.0 12.3 12.6 12.9 13.2 1.92 12 Bulgary 66/22 2.5 0 0.98 0.2 0.2 0.2 0.2 0.2 0.00 9 Forest Hill 66/11 5/6.9 10/14 7.59 0.93 5.2 5.1 5.0 4.9 4.9 0.48 11 Hammond Ave 66/11 24/30 24/30 33 0.91 19.0 19.1 19.1 19.1 19.1 1.16 16 Henty 66/11 5 5 5.5 0.96 2.1 2.1 2.1 2.1 2.1 0.78 4 Kooringal 66/11 18/25 18/25 27.5 0.96 16.8 16.7 16.6 16.5 16.4 2.63 4 Lockhart 66/22 8 2.5 2.5 5.5 1.00 2.7 2.6 2.5 2.4 2.4 0.93 2 Morrow St 66/11 20 20 22 0.92 13.6 13.5 13.4 13.3 13.2 0.55 9 Uranquinty 66/22 10/16 10/16 17.6 0.99 4.3 4.3 4.3 4.3 4.3 1.17 3 WINTER Wagga (Copland St) Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Ashmont 66/11 20/30 20/30 36 0.97 15.2 15.4 15.7 15.9 16.1 2.00 27 Bourkelands 66/11 10/13 10/13 15.6 0.99 9.6 9.8 10.0 10.1 10.3 1.92 10 Bulgary 66/22 2.5 0 0.98 0.1 0.1 0.1 0.1 0.1 0.00 4 Forest Hill 66/11 5/6.9 10/14 8.28 0.94 5.5 5.5 5.5 5.5 5.5 0.48 8 Hammond Ave 66/11 24/30 24/30 36 0.95 14.9 14.8 14.8 14.7 14.7 1.16 5 Henty 66/11 5 5 6 0.99 1.8 1.8 1.8 1.8 1.8 0.78 7 Kooringal 66/11 18/25 18/25 30 0.98 13.8 13.8 13.8 13.8 13.8 2.63 5 Lockhart 66/22 8 2.5 2.5 6 0.98 2.4 2.4 2.3 2.3 2.2 0.93 6 Morrow St 66/11 20 20 24 0.95 7.9 7.9 7.9 7.9 7.9 0.55 32 Uranquinty 66/22 10/16 10/16 19.2 1.00 4.0 4.0 4.0 4.0 4.0 1.17 12 2.6.6.4 Subtransmission Single Diagram of Wagga Wagga area See the Wagga North diagram on Page 119. For Public Release December 2015 Page 121 of 183

2.6.7 Morven Supply Area 2.6.7.1 Description of Morven area The Morven 132/66 substation is owned by Essential Energy. It receives supply via a tee off the TransGrid Wagga Wagga 330 (Gregadoo) Albury (ANM) 132 line (#996). Culcairn 66/11 and Holbrook 66/22 zone substations take normal 66 supply from Morven and backup 66 supply from TransGrid s Wagga Wagga 132/66 substation (Copland St) on the Essential Energy 66 line (#83M) via Uranquinty and Holbrook. MORVEN Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.7.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 996/1 132 Feeder Origin TransGrid 132 996 Tee Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Morven 132/66 STS 45 8.3 8.3 8.3 8.3 8.3 86 7.1 7.1 7.1 7.1 7.1 8WC 66 Morven 132/66 STS Culcairn ZS 15 3.6 3.6 3.6 3.6 3.6 25 3.6 3.6 3.6 3.6 3.6 8W7 66 Morven 132/66 STS Holbrook ZS 15 2.9 2.9 2.9 2.9 2.9 25 2.8 2.8 2.8 2.8 2.8 2.6.7.3 STS and ZS load forecast SUMMER Morven Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Culcairn 66/11 5/7 8 7.7 0.96 3.6 3.6 3.6 3.6 3.6 1.26 3 Holbrook 66/22 5/7 5/7 7.7 0.98 2.9 2.9 2.9 2.9 2.9 0.98 6 Morven 132/66 30 0 0.98 6.3 6.3 6.3 6.3 6.3 0.00 5 WINTER Morven Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Culcairn 66/11 5/7 8 8.4 0.98 3.6 3.6 3.6 3.6 3.6 1.26 17 Holbrook 66/22 5/7 5/7 8.4 1.00 2.8 2.8 2.8 2.8 2.8 0.98 7 Morven 132/66 30 0 1.00 6.1 6.1 6.1 6.1 6.1 0.00 7 2.6.7.4 Subtransmission Single Diagram of Morven area See the Wagga North diagram on Page 119. For Public Release December 2015 Page 122 of 183

2.6.8 Albury Supply Area 2.6.8.1 Description of Albury area The Albury area 132 subtransmission system is supplied from TransGrid s Jindera 330/132 subtransmission substation with backup via TransGrid s 132 line from ANM substation Ettamogah. The Essential Energy substation of Corowa and Mulwala are supplied at 132 from the Essential Energy 132 powerlines connecting the Union Road substation to TransGrid s Finley 132/66 subtransmission substation. ALBURY Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.8.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 997/1 132 Union Rd ZS Corowa ZS 128 31.1 31.2 31.3 31.4 31.6 143 22.6 22.6 22.7 22.7 22.8 997/2 132 Corowa ZS Mulwala ZS 128 13.4 13.4 13.5 13.5 13.6 143 9.0 9.0 9.0 9.0 9.0 99E 132 Union Rd ZS Jelbart ZS 148 20.9 21.0 21.1 21.2 21.2 164 16.3 16.2 16.1 16.0 15.9 99G 132 Union Rd ZS Jelbart ZS 148 20.9 21.0 21.1 21.2 21.2 164 16.3 16.2 16.1 16.0 15.9 2.6.8.3 STS and ZS load forecast SUMMER Albury Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Corowa 132/22 30 27/30 33 0.94 16.5 16.5 16.6 16.6 16.6 5.07 8 Jelbart 132/22 30/44 30/44 48.4 1.00 41.8 42.0 42.2 42.3 42.5 3.35 8 Mulwala 132/22 30 30 33 0.97 13.5 13.5 13.5 13.5 13.5 2.06 10 Union Rd 132/22 15/35 30/44 30/44 86.9 1.00 41.1 40.2 39.3 38.4 37.6 8.89 7 WINTER Albury Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Corowa 132/22 30 27/30 36 0.98 14.1 14.1 14.1 14.1 14.1 5.07 15 Jelbart 132/22 30/44 30/44 52.8 1.00 32.7 32.4 32.2 32.0 31.8 3.35 22 Mulwala 132/22 30 30 36 0.98 8.9 8.9 8.9 8.9 8.9 2.06 7 Union Rd 132/22 15/35 30/44 30/44 94.8 1.00 35.3 35.2 35.2 35.2 35.2 8.89 5 For Public Release December 2015 Page 123 of 183

2.6.8.4 Subtransmission Single Diagram of Albury area Finley Mulwala TransGrid Subs 330/132 Private P G Generator ALBURY Wagga 62 JINDERA 996 060 99H 9R4 99B 997/2 997/1 P 99Z Mill (Private) Corowa Union Road 99G Jelbart (Albury) 99E 995 G Hume Weir Hydro (58MW) Wodonga (SP AusNet) Wodonga (Powercor) EE Zone s Transmission & Sub-trans. s TransGrid Essential Energy Victorian Utilities 132/22 330 132 330 SP AusNet 132 66 66 Powercor For Public Release December 2015 Page 124 of 183

2.6.9 Finley Supply Area 2.6.9.1 Description of Finley area The Finley area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation. FINLEY Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.9.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 9R4 132 84A 66 84B 66 84C 66 Feeder Origin TransGrid Finley 132/66 STS TransGrid Finley 132/66 STS TransGrid Finley 132/66 STS TransGrid Finley 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Mulwala ZS 140 15.9 16.0 16.0 16.0 16.0 157 15.3 15.3 15.3 15.3 15.3 Jerilderie ZS 15 4.1 4.1 4.1 4.1 4.1 25 5.4 5.4 5.4 5.4 5.4 Finley ZS 61 9.5 9.5 9.5 9.5 9.5 70 7.1 7.1 7.1 7.1 7.1 Finley ZS 61 6.9 6.9 6.9 6.9 6.9 70 5.2 5.2 5.2 5.2 5.2 2.6.9.3 STS and ZS load forecast SUMMER Finley Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Finley Town 66/22 24/30 24/30 33 0.96 14.5 14.5 14.6 14.6 14.7 3.26 2 Jerilderie 66/22 8.8/10 8.8/10 11 0.99 3.8 3.8 3.8 3.8 3.8 0.89 5 WINTER Finley Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Finley Town 66/22 24/30 24/30 36 0.99 10.1 10.1 10.1 10.1 10.1 3.26 4 Jerilderie 66/22 8.8/10 8.8/10 12 0.97 6.6 6.9 7.1 7.2 7.4 0.89 9 A 2.5MW generator is located at The Drop and is connected to the Finley 66/22 ZS at 22 via feeder FIN42. For Public Release December 2015 Page 125 of 183

2.6.9.4 Subtransmission Single Diagram of Finley area MM61 Koraleigh TransGrid Subs 132/66 FINLEY, DENILIQUIN Coleambally Moulamein 822/2 Murgha 99L Jerilderie 822/1 n.o. Deniliquin 84A Barham 844 845 n.o. DENILIQUIN 821 9R3 FINLEY n.o. n.o. 84C 84B 99A Uranquinty Switching Station Finley G 9R4 The Drop (2.5MW) 84Y Mulwala No.6 Moama Moama Essential Energy Zone s Transmission & Sub-trans. s 66/22 G Dual line Generator TransGrid Essential Energy 66 132 22 132 For Public Release December 2015 Page 126 of 183

2.6.10 Deniliquin Supply Area 2.6.10.1 Description of Deniliquin area The Deniliquin area subtransmission system is supplied from TransGrid s 132/66 subtransmission substation. DENILIQUIN Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.10.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 844 66 845 66 822/1 66 Feeder Origin TransGrid Deniliquin 132/66 STS TransGrid Deniliquin 132/66 STS TransGrid Deniliquin 132/66 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Barham ZS 11 5.6 5.7 5.7 5.7 5.7 19 4.6 4.6 4.6 4.6 4.6 Deniliquin ZS 38 21.5 21.5 21.6 21.7 21.7 43 17.5 17.5 17.5 17.5 17.5 Murgha ZS 11 7.4 7.4 7.4 7.4 7.4 19 6.5 6.5 6.5 6.5 6.5 822/2 66 Murgha ZS Moulamein ZS 11 6.2 6.2 6.2 6.2 6.3 19 5.6 5.6 5.6 5.6 5.6 84Y 66 TransGrid Deniliquin 132/66 STS Moama ZS 20 8.3 8.3 8.4 8.4 8.4 38 4.4 4.4 4.4 4.4 4.4 MM61 66 Moulamein ZS Koraleigh ZS 15 4.1 4.1 4.1 4.1 4.1 25 2.6 2.6 2.6 2.6 2.6 No.6 Moama 66 TransGrid Deniliquin 132/66 STS Moama ZS 34 5.8 5.8 5.8 5.8 5.9 39 3.1 3.1 3.1 3.1 3.1 2.6.10.3 STS and ZS load forecast SUMMER Deniliquin Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Barham 66/22 10/16 10 11 0.96 5.5 5.4 5.4 5.3 5.3 1.46 3 Deniliquin 66/22 18/30 18/30 33 0.94 22.4 22.2 21.9 21.7 21.6 3.05 7 Koraleigh 66/22 5 5 5.5 0.96 3.6 3.5 3.5 3.4 3.4 0.83 3 Moama 66/22 24/30 24/30 33 0.97 14.2 14.2 14.2 14.2 14.2 1.93 7 Moulamein 66/22 5 5 5.5 0.97 2.0 2.0 2.0 2.0 2.0 0.49 4 Murgha 66/22 1 0 0.86 0.6 0.6 0.6 0.6 0.6 0.00 5 WINTER Deniliquin Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Barham 66/22 10/16 10 12 0.97 5.0 5.0 5.0 5.0 5.0 1.46 3 Deniliquin 66/22 18/30 18/30 36 0.95 16.5 16.5 16.4 16.4 16.3 3.05 3 Koraleigh 66/22 5 5 6 0.98 2.8 2.8 2.7 2.7 2.7 0.83 3 Moama 66/22 24/30 24/30 36 0.97 8.6 8.6 8.6 8.6 8.6 1.93 15 Moulamein 66/22 5 5 6 1.00 3.7 4.0 4.3 4.5 4.7 0.49 7 Murgha 66/22 1 0 0.89 0.4 0.4 0.4 0.4 0.4 0.00 3 2.6.10.4 Subtransmission Single Diagram of Deniliquin area See the Finley diagram on Page 126. For Public Release December 2015 Page 127 of 183

2.6.11 Coleambally Supply Area 2.6.11.1 Description of Coleambally area Essential Energy s Coleambally 132/33 subtransmission substation is supplied from TransGrid s 132 transmission powerlines #99L from Deniliquin and #99T from Darlington Point system. COLEAMBALLY Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.11.2 Subtransmission feeder load forecast Feeder # Feeder Voltage CLY1526 33 Feeder Origin Coleambally 132/33 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Coleambally Tee 10 3.9 3.9 3.9 3.9 3.9 19 2.7 2.7 2.7 2.7 2.7 CLY1526 33 Coleambally Tee Coleambally ZS 10 2.2 2.2 2.2 2.2 2.2 19 1.5 1.5 1.5 1.5 1.5 CLY1526 33 Coleambally Tee Egansford ZS 8 0.9 0.9 0.9 0.9 0.9 13 0.6 0.6 0.6 0.6 0.6 CLY1530 33 Coleambally 132/33 STS Ringwood Rd ZS 8 5.8 5.8 5.8 5.8 5.8 13 4.0 4.0 4.0 4.0 4.0 CLY1530 33 Ringwood Rd ZS Darlington Point ZS 8 2.7 2.7 2.7 2.7 2.7 13 1.9 1.9 1.9 1.9 1.9 2.6.11.3 STS and ZS load forecast SUMMER Coleambally Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Coleambally 132 132/33 17.5/25 17.5/25 27.5 0.92 11.1 11.1 11.1 11.1 11.1 0.14 26 Coleambally 33/11 33/11 7.5 7.5 8.25 0.87 3.4 3.4 3.4 3.4 3.3 0.29 3 Darlington Point 33/11 10/12.5 10/14 13.75 0.80 3.9 3.9 3.9 3.9 3.9 0.42 10 Egansford 33/11 2.5 5 2.75 0.85 1.2 1.2 1.2 1.2 1.2 0.04 3 Ringwood Road 33/11 5 0 0.83 2.5 2.4 2.4 2.4 2.3 0.03 8 WINTER Coleambally Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Coleambally 132 132/33 17.5/25 17.5/25 30 0.93 8.1 8.1 8.1 8.0 8.0 0.14 5 Coleambally 33/11 33/11 7.5 7.5 9 0.94 3.0 2.9 2.9 2.8 2.8 0.29 2 Darlington Point 33/11 10/12.5 10/14 15 0.85 2.5 2.5 2.5 2.5 2.5 0.42 1 Egansford 33/11 2.5 5 3 0.89 1.2 1.2 1.2 1.2 1.2 0.04 9 Ringwood Road 33/11 5 0 0.80 1.7 1.7 1.6 1.6 1.6 0.03 8 For Public Release December 2015 Page 128 of 183

2.6.11.4 Subtransmission Single Diagram of Coleambally area Ivanhoe HIL1117 HAT42 HAT22 HAY Hay HAT32 Balranald TransGrid Subs Essential Energy Zone s Transmission & Sub-trans. s 330/132 33/11 132/33 DARLINGTON POINT HILLSTON 79P HIL1111 n.o. Darlington Point Regulator 99N DPR1100 DPR1097 n.o. CLY1530 Carrathool 99R Ringwood Road CLY1523 99T COLEAMBALLY X5/1 CLY1526 99L Coleambally Deniliquin132 TransGrid 330 33/19.1 SWER/11 220 132 Griffith132 79C 99K Darlington Point DARLINGTON POINT 99D Yanco 63 Dallas Regulator Wagga n.o. Whitton / Yanco Egansford Essential Energy 132 33 For Public Release December 2015 Page 129 of 183

2.6.12 Darlington Point Supply Area 2.6.12.1 Description of Darlington Point area The Darlington Point area 132 subtransmission system is supplied from TransGrid s 330/132 subtransmission substation. Essential Energy owns the 132 transmission lines supplying Hay and Hillston substations. The 33 subtransmission originates from these substations. DARLINGTON POINT Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.12.2 Subtransmission feeder load forecast Feeder # Feeder Voltage 99N 132 99R 132 Feeder Origin TransGrid Darlington Point 330/132 STS TransGrid Darlington Point 330/132 STS Feeder Destination Summer Forecast MVA Winter Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 Hillston ZS 128 11.0 11.1 11.2 11.4 11.5 143 8.1 8.1 8.1 8.1 8.1 Hay 132 ZS 128 8.4 8.4 8.5 8.6 8.7 143 5.9 5.9 5.9 5.9 5.9 HAT 22 33 Hay 132 ZS Hay ZS 8 5.7 5.8 5.9 5.9 6.0 13 4.1 4.1 4.1 4.1 4.1 HAT 32 33 Hay 132 ZS Hay ZS 8 1.0 1.0 1.0 1.0 1.1 13 0.8 0.8 0.8 0.8 0.8 HAT 42 33 Hay 132 ZS Carrathool ZS 7 1.9 1.9 1.9 1.9 1.9 12 1.2 1.2 1.2 1.2 1.2 HIL1117 33 Hillston ZS Ivanhoe ZS 6 3.1 3.1 3.1 3.1 3.2 9 2.7 2.7 2.7 2.7 2.7 2.6.12.3 STS and ZS load forecast SUMMER Darlington Point Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Carathool 33/11 1.5 1.5 1.65 0.89 0.6 0.6 0.6 0.6 0.6 0.04 2 Hay 132 132/33 24/30 24/30 33 0.97 8.3 8.3 8.3 8.3 8.3 0.31 11 Hay Town 33/11 6.5 8/10 7.15 0.94 4.8 4.8 4.8 4.7 4.7 0.64 11 Hillston 132/33 30 12/16 17.6 1.00 8.9 8.8 8.7 8.6 8.5 0.75 4 Ivanhoe 33/11 1 1 1.1 0.97 0.9 0.9 0.9 0.9 0.9 0.05 28 WINTER Darlington Point Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Carathool 33/11 1.5 1.5 1.8 0.93 0.3 0.3 0.3 0.3 0.3 0.04 Hay 132 132/33 24/30 24/30 36 0.96 10.4 10.4 10.4 10.4 10.4 0.31 6 Hay Town 33/11 6.5 8/10 7.8 0.98 5.9 5.9 5.9 5.9 5.9 0.64 1 Hillston 132/33 30 12/16 19.2 0.99 6.9 7.0 7.2 7.3 7.4 0.75 5 Ivanhoe 33/11 1 1 1.2 0.98 0.7 0.7 0.7 0.7 0.7 0.05 2 2.6.12.4 Subtransmission Single Diagram of Darlington Point area See the Coleambally diagram on Page 129. For Public Release December 2015 Page 130 of 183

2.6.13 Griffith Supply Area 2.6.13.1 Description of Griffith area The Griffith area subtransmission system is supplied from TransGrid s 132/33 subtransmission substation. GRIFFITH Identified System Limitations SYSTEM LIMITATION Thermal and voltage regulation limitation on either feeder 79P or 79R for loss of the other feeder Refer to DAPR Section Section 3.1 2.6.13.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 79C/1 33 TransGrid Griffith 132/33 STS Widgelli / Willbriggie Tee 10 5.8 5.9 6.0 6.0 6.1 19 5.5 5.5 5.7 5.8 5.8 79C/2 33 Widgelli / Willbriggie Tee Widgelli ZS 10 1.1 1.1 1.1 1.1 1.1 19 0.9 0.9 1.0 1.0 1.0 79C/3 33 Widgelli / Willbriggie Tee Willbriggie Tee 10 4.7 4.8 4.8 4.9 4.9 19 4.5 4.6 4.7 4.8 4.8 79C/4 33 Willbriggie Tee Willbriggie ZS 10 4.2 4.2 4.3 4.3 4.3 19 4.0 4.0 4.1 4.2 4.2 79C/5 33 Willbriggie Tee 79C / 79P Tee 10 0.5 0.5 0.5 0.5 0.5 19 0.5 0.5 0.5 0.5 0.5 79F 33 TransGrid Griffith 132/33 STS Yenda ZS 22 11.4 11.6 11.7 11.7 11.9 27 8.1 8.1 8.4 8.5 8.6 79G 33 Beelbangera ZS Griffith ZS 10 0.0 0.0 0.0 0.0 0.0 19 0.0 0.0 0.0 0.0 0.0 79J 33 79L 33 79M 33 79P/1 33 TransGrid Griffith 132/33 STS TransGrid Griffith 132/33 STS TransGrid Griffith 132/33 STS TransGrid Griffith 132/33 STS Griffith ZS 51 0.0 0.0 0.0 0.0 0.0 56 0.0 0.0 0.0 0.0 0.0 Beelbangera ZS 10 12.7 12.9 13.0 13.1 13.3 19 7.7 7.7 8.0 8.1 8.2 Hanwood ZS 22 10.4 10.6 10.7 10.7 10.8 27 7.4 7.4 7.7 7.8 7.9 Warrawidgee Tee 22 9.0 9.1 9.2 9.3 9.4 27 7.2 7.2 7.5 7.6 7.6 79P/2 33 Warrawidgee Tee Warrawidgee ZS 22 2.1 2.1 2.1 2.1 2.2 27 1.6 1.6 1.7 1.7 1.7 79P/3 33 Warrawidgee Tee Nericon Tee 6 6.3 6.4 6.4 6.5 6.5 9 5.1 5.1 5.3 5.4 5.4 79P/4 33 Nericon Tee Nericon ZS 6 2.8 2.8 2.8 2.9 2.9 9 1.8 1.8 1.8 1.9 1.9 79R 33 79U 33 TransGrid Griffith 132/33 STS TransGrid Griffith 132/33 STS Tharbogang ZS 10 16.5 16.7 16.9 16.9 17.2 19 9.5 9.5 9.8 10.0 10.1 Griffith ZS 51 27.7 28.2 28.4 28.5 28.9 56 18.5 18.5 19.2 19.5 19.6 For Public Release December 2015 Page 131 of 183

2.6.13.3 STS and ZS load forecast SUMMER Griffith Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Beelbangera 33/11 10/12.5 10/12.5 13.75 0.93 8.9 8.9 9.0 9.0 9.0 1.10 5 Griffith 33/11 50 50 55 0.95 24.7 24.6 24.5 24.5 24.4 2.82 5 Hanwood 33/11 25 25 27.5 0.85 12.5 12.7 12.8 13.0 13.1 0.34 15 Nericon 33/11 8 0 0.91 1.4 1.4 1.4 1.4 1.4 0.10 1 Tharbogang 33/11 25 25 27.5 1.00 15.3 15.4 15.6 15.7 15.8 1.39 7 Warrawidgee 33/11 2.5 3 2.75 0.83 1.4 1.4 1.4 1.4 1.4 0.03 15 Widgelli 33/11 1 0 0.79 0.4 0.4 0.4 0.4 0.4 0.00 9 Willbriggie 33/11 8 0 0.98 1.3 1.3 1.3 1.3 1.3 0.08 5 Yenda 33/11 9.5 9.5 10.45 1.00 6.7 6.8 6.8 6.8 6.8 0.64 1 WINTER Griffith Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Beelbangera 33/11 10/12.5 10/12.5 15 0.97 5.9 6.0 6.1 6.2 6.3 1.10 4 Griffith 33/11 50 50 60 0.98 17.4 17.4 17.5 17.5 17.5 2.82 9 Hanwood 33/11 25 25 30 0.92 9.1 9.3 9.4 9.6 9.8 0.34 3 Nericon 33/11 8 0 0.89 0.3 0.3 0.3 0.3 0.3 0.10 1 Tharbogang 33/11 25 25 30 1.00 8.9 8.9 8.9 8.9 9.0 1.39 6 Warrawidgee 33/11 2.5 3 3 0.87 0.8 0.8 0.8 0.8 0.8 0.03 35 Widgelli 33/11 1 0 0.99 0.3 0.3 0.3 0.3 0.3 0.00 26 Willbriggie 33/11 8 0 0.99 0.6 0.6 0.6 0.6 0.6 0.08 8 Yenda 33/11 9.5 9.5 11.4 0.99 5.3 5.4 5.4 5.5 5.6 0.64 4 For Public Release December 2015 Page 132 of 183

2.6.13.4 Subtransmission Single Diagram of Griffith area Hillston HIL1111 n.o. GRIFFITH Goolgowi Regulator 79P Nericon Hillston Road Regulator Beelbangra Yenda n.o. Warrawidgee 79P Tharbogang n.o. Griffith 79R n.o. 79G n.o. 79J 79U 79L GRIFFITH 79F Note 1 79P 79C n.o. Hanwood 79M Widgelli n.o. 79C 99J Wilbriggie 79C 99K Darlington Point Yanco Notes 1. System Limitation Location See DAPR2015 Section 3.1 Darlington Point Regulator Station TransGrid Subs EE Zone s Trans & Sub-trans s 132/33 33/11 TransGrid Essential Energy 132 33 Dual line For Public Release December 2015 Page 133 of 183

2.6.14 Yanco Supply Area 2.6.14.1 Description of Yanco area The Yanco area subtransmission system is supplied from TransGrid s 132/33/66 subtransmission substation. The 66 subtransmission system originates from TransGrid s 132/33/66 subtransmission substation via an Essential Energy 33/66 transformer. YANCO Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.14.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 840/3 66 Kywong ZS Lockhart Tee 16 0.0 0.0 0.0 0.0 0.0 25 0.0 0.0 0.0 0.0 0.0 840/4 66 Narrandra ZS Kywong ZS 16 0.4 0.4 0.4 0.4 0.4 25 0.4 0.4 0.4 0.4 0.4 841:YNC 66 YNC102 33 TransGrid Yanco 132/66 STS TransGrid Yanco 132/66 STS Narrandra ZS 15 10.3 10.3 10.3 10.3 10.3 25 7.7 7.7 7.7 7.7 7.7 Cudgel ZS 8 0.9 0.9 0.9 0.9 0.9 13 0.9 0.9 0.9 0.9 0.9 YNC52 33 TransGrid Yanco 132/66 STS Whitton / Murrami Tee 8 4.3 4.3 4.3 4.3 4.3 13 3.5 3.5 3.5 3.5 3.5 YNC52 33 Whitton / Murrami Tee Whitton ZS 8 3.8 3.8 3.8 3.8 3.8 13 2.9 2.9 2.9 2.9 2.9 YNC52 33 Whitton / Murrami Tee Murrami ZS 8 0.3 0.3 0.3 0.3 0.3 13 0.3 0.3 0.3 0.3 0.3 YNC72 33 TransGrid Yanco 132/66 STS Yanco ZS 8 8.9 8.9 8.9 8.9 8.9 13 8.1 8.1 8.1 8.1 8.1 YNC72 33 Yanco ZS Leeton ZS 6 6.5 6.5 6.5 6.5 6.5 9 6.1 6.1 6.1 6.1 6.1 YNC72 33 Leeton ZS Murrami ZS 6 1.1 1.1 1.1 1.1 1.1 9 1.4 1.4 1.4 1.4 1.4 YNC92 33 TransGrid Yanco 132/66 STS Leeton ZS 22 14.5 14.5 14.5 14.5 14.5 27 12.5 12.5 12.5 12.6 12.6 For Public Release December 2015 Page 134 of 183

2.6.14.3 STS and ZS load forecast SUMMER Yanco Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 Cudgel 33/11 1 0 0.83 0.5 0.5 0.5 0.5 0.5 0.00 1 Kywong 66/11 2.5 0 0.91 0.3 0.3 0.3 0.3 0.3 0.02 1 Leeton 33/11 15/20/25 15/20/25 27.5 0.91 20.8 20.7 20.7 20.7 20.7 1.83 12 Murrami 33/11 5 5 5.5 0.86 0.8 0.8 0.8 0.8 0.8 0.26 3 Narrandera 66/11 10/16 10/16 17.6 0.97 9.3 9.1 9.0 8.8 8.7 1.20 16 Whitton 33/11 5/6.25 5/6.25 6.875 0.88 4.9 4.8 4.8 4.8 4.8 0.45 6 Yanco 33/11 33/11 5 0 0.93 2.1 2.1 2.2 2.2 2.2 0.35 5 Yanco 33/66 33/66 15 0 0.98 12.0 12.2 12.3 12.4 12.4 0.22 11 WINTER Yanco Supply Area POE50 Indicative Demand Forecast Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 Cudgel 33/11 1 0 0.83 0.4 0.4 0.4 0.4 0.4 0.00 1 Kywong 66/11 2.5 0 0.90 0.1 0.1 0.1 0.1 0.1 0.02 6 Leeton 33/11 15/20/25 15/20/25 30 0.97 16.1 16.1 16.1 16.1 16.1 1.83 3 Murrami 33/11 5 5 6 0.86 1.1 1.1 1.1 1.1 1.1 0.26 1 Narrandera 66/11 10/16 10/16 19.2 1.00 7.1 7.1 7.0 6.9 6.9 1.20 3 Whitton 33/11 5/6.25 5/6.25 7.5 0.87 1.9 1.9 1.9 1.9 1.9 0.45 4 Yanco 33/11 33/11 5 0 0.94 1.8 1.8 1.8 1.8 1.8 0.35 15 Yanco 33/66 33/66 15 0 0.99 7.3 7.3 7.3 7.2 7.2 0.22 2 For Public Release December 2015 Page 135 of 183

2.6.14.4 Subtransmission Single Diagram of Yanco area YANCO Griffith Murrami 99J YNC52 n.o. YNC72 Leeton Whitton YNC92 YNC52 Gogelderie Reg YNC72 Yanco 33/11 Egansford Dallas Reg 99D YANCO132 Yanco 33/66 n.o. YNC102 Cudgel Darlington Point 994 841:YNC 99F Narrandera 840/4 Kywong 840/3:KYW Lockhart Reg Wagga 330 TransGrid SS EE Zone s Trans & Sub-trans s TransGrid Essential Energy 132/33 Co-located EE/TG ZSS facilities 33/11 66/11 33/66 132 Uranquinty 66 33 For Public Release December 2015 Page 136 of 183

2.6.15 Buronga Supply Area 2.6.15.1 Description of Buronga area Supply to the Dareton, Wentworth and Buronga areas originates from the Powercor 66 subtransmission substations at Merbein and Mildura in Victoria, which is in turn supplied from the Red Cliffs Victoria 220/66 subtransmission substation south east of Mildura. The Balranald area is supplied from TransGrid s 220/22 substation. Backup supply is seasonal limited via Moulamein 22 system. BURONGA Identified System Limitations SYSTEM LIMITATION Nil Refer to DAPR Section 2.6.15.2 Subtransmission feeder load forecast Summer Winter Feeder # Feeder Voltage Feeder Origin Feeder Destination Forecast MVA Forecast MVA MVA 15/16 16/17 17/18 18/19 19/20 MVA 2016 2017 2018 2019 2020 83G 66 Dareton ZS Ellerslie ZS 67 11.0 11.1 11.2 11.3 11.4 78 11.7 11.8 11.9 12.0 12.0 83H 66 Ellerslie ZS Ginkgo Snapper Tee 45 10.2 10.3 10.4 10.5 10.5 56 11.2 11.3 11.4 11.5 11.5 83H 66 Ginkgo Snapper Tee Ginkgo ZS 20 6.2 6.2 6.1 6.1 6.1 39 6.2 6.2 6.3 6.4 6.4 83H 66 Ginkgo Snapper Tee Snapper ZS 12 4.7 4.7 4.7 4.7 4.7 19 4.8 4.7 4.7 4.6 4.6 83U 66 Powercor Mildura ZS (NSW Border) Buronga ZS 22 7.1 7.0 6.9 6.8 6.8 43 5.3 5.5 5.7 5.9 6.0 83W 66 Buronga ZS Dareton ZS 22 0.0 0.0 0.0 0.0 0.0 43 0.0 0.0 0.0 0.0 0.0 Merbein - Dareton 66 Powercor Mildura ZS (NSW Border) Dareton ZS 49 24.9 25.2 25.4 25.6 25.8 61 17.8 18.0 18.1 18.3 18.4 2.6.15.3 STS and ZS load forecast SUMMER Buronga Supply Area POE50 Indicative Demand Forecast Powercor Robinvale 22 Euston Distribution Supply TransGrid 220/22 Total Balranald 22 Supply Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 15/16 16/17 17/18 18/19 19/20 4.3 4.3 4.3 4.2 4.2 0.09 3.6 3.6 3.6 3.6 3.6 0.22 Buronga Town 66/22 30 30 33 0.94 7.7 7.8 7.9 8.0 8.1 0.79 8 Dareton 66/22 24/30 24/30 33 0.92 14.9 14.3 13.8 13.4 13.0 0.72 16 Ellerslie 66/22 5 0 0.98 2.6 2.6 2.6 2.6 2.6 0.10 4 Ginkgo 66/22 12.5/16 0 0.91 6.2 6.2 6.1 6.1 6.1 0.00 17 Snapper 66/22 10/16 0 0.97 4.7 4.7 4.7 4.7 4.7 0.00 52 WINTER Buronga Supply Area POE50 Indicative Demand Forecast Powercor Robinvale 22 Euston Distribution Supply TransGrid 220/22 Total Balranald 22 Supply Transformer Dynamic Forecast Forecast Tx.1 Tx.2 Tx.3 2016 2017 2018 2019 2020 1.5 1.5 1.6 1.6 1.6 0.09 2.5 2.5 2.5 2.5 2.5 0.22 Buronga Town 66/22 30 30 36 0.99 4.6 4.4 4.3 4.2 4.1 0.79 5 Dareton 66/22 24/30 24/30 36 0.96 9.6 9.6 9.6 9.6 9.6 0.72 6 Ellerslie 66/22 5 0 0.90 1.3 1.3 1.3 1.3 1.3 0.10 1 Ginkgo 66/22 12.5/16 0 0.93 6.2 6.2 6.3 6.4 6.4 0.00 37 Snapper 66/22 10/16 0 0.97 4.8 4.7 4.7 4.6 4.6 0.00 40 For Public Release December 2015 Page 137 of 183

2.6.15.4 Subtransmission Single Diagram of Buronga area BURONGA Notes 1) A 22 distribution feeder supplies NSW town of Euston. Broken Hill X2 Ginkgo Snapper Dareton Ellerslie BURONGA 83W 0X1 X5/3 Buronga 83U Redcliffs BALRANALD X5/1 Merbein Mildura Hattah Robinvale (note 1) Darlington Point Essential Energy Zone s Trans & Sub-trans s 66/22 Powercor Zone s TransGrid 220 Powercor 66 66/22 220/66/22 TransGrid s Essential Energy 220 66 220/22 220 Switching Station For Public Release December 2015 Page 138 of 183

2.7 Future Connection Points There are no Future Connection Points that have been identified for Essential Energy. For Public Release December 2015 Page 139 of 183

2.8 Transmission Distribution Connection Point Forecast The Transmission Distribution connection point forecasts are shown for three areas (North, Central and South and Far West) that don t match the planning or operational regions of Essential Energy. The embedded generation includes all major generation capacity but excludes the rooftop PV solar cell generation (which is shown against the individual zone substation forecasts). 2.8.1 Transmission - Distribution Connection Point load forecast North NORTH Connection Point Transmission Distribution Connection Point Forecast Forecast PF Summer Forecast Forecast Winter Forecast PF 15/16 16/17 17/18 18/19 19/20 2016 2017 2018 2019 2020 Armidale 0.96 26.0 26.9 26.9 26.9 26.9 0.99 38.5 38.5 38.5 38.5 38.5 0 Boambee South 0.98 21.4 21.4 21.4 21.4 21.4 0.99 21.2 21.2 21.2 21.2 21.2 Casino 0.98 27.5 27.5 27.5 27.5 27.5 0.98 22.4 22.4 22.4 22.4 22.4 Coffs Harbour 0.99 53.8 54.7 54.7 54.7 54.9 0.99 51.4 51.4 51.4 51.4 52.3 Dorrigo 0.95 3.2 3.2 3.2 3.2 3.2 0.95 3.2 3.2 3.2 3.2 3.2 Dunoon 0.98 5.1 5.1 5.1 5.1 5.1 0.99 6.1 6.1 6.1 6.1 6.1 Glen Innes 0.98 9.2 9.2 9.2 9.2 9.2 0.99 12.2 12.2 12.2 12.2 12.2 5 Gunnedah 66 1.00 26.1 26.1 26.1 26.1 26.1 1.00 22.1 22.1 22.1 22.1 22.1 7 Hawks Nest 0.99 8.1 8.1 8.1 8.1 8.1 0.99 8.1 8.1 8.1 8.1 8.1 Herons Ck 0.95 9.5 9.5 9.5 9.5 9.5 0.98 10.2 10.2 10.2 10.2 10.2 Inverell 1.00 36.1 40.1 40.1 40.1 40.1 1.00 34.1 39.1 39.1 39.1 39.1 22.5 Kempsey 33 0.98 25.5 25.5 26.5 26.5 26.5 0.98 27.5 27.5 27.5 28.4 28.4 Koolkhan 1.00 49.2 49.2 49.2 49.2 49.2 1.00 47.0 47.0 47.0 47.0 47.0 2 Lismore 132/66 0.99 73.7 73.7 74.8 74.8 74.8 0.99 75.4 75.4 76.4 76.4 76.4 30 Macksville 0.97 8.2 8.2 8.2 8.2 8.2 0.98 9.2 9.2 9.2 9.2 9.2 Moree 1.00 27.1 27.1 27.1 27.1 27.1 0.99 39.2 39.2 39.2 39.2 39.2 56 Mullumbimby 0.99 43.3 43.3 44.3 44.3 44.3 1.00 50.2 50.2 50.2 50.2 51.2 Nambucca 0.99 6.1 6.1 6.1 6.1 6.1 0.99 9.1 9.1 9.1 9.1 9.1 Narrabri 0.99 49.4 49.4 49.4 49.4 49.4 0.99 50.6 50.6 50.6 50.6 51.6 16 Port Macquarie 0.99 59.8 60.8 60.8 60.8 61.8 0.99 66.5 67.5 67.5 67.5 68.5 Raleigh 0.97 8.2 8.2 8.2 8.2 8.2 0.98 10.2 10.2 10.2 10.2 10.2 Stroud 1.00 30.0 30.0 30.0 30.0 30.0 0.98 27.5 27.5 27.5 27.5 27.5 Tamworth 0.99 116.7 117.7 117.7 118.9 119.9 0.99 95.2 95.2 96.2 96.3 97.3 Taree 33 0.97 23.8 23.8 23.8 23.8 24.7 0.99 23.3 23.3 23.3 23.3 23.3 Taree 66 0.97 49.5 49.5 50.4 50.4 50.4 0.99 49.5 49.5 50.5 50.5 50.5 Tenterfield 0.98 5.1 5.1 5.1 5.1 5.1 0.99 6.1 6.1 6.1 6.1 6.1 Terranora 1.00 78.2 79.2 79.2 80.2 80.2 1.00 80.2 81.2 81.2 82.2 82.2 30 Major Generation (MW) For Public Release December 2015 Page 140 of 183

2.8.2 Transmission - Distribution Connection Point load forecast Central CENTRAL Connection Point Transmission Distribution Connection Point Forecast Forecast PF Summer Forecast Forecast Winter Forecast PF 15/16 16/17 17/18 18/19 19/20 2016 2017 2018 2019 2020 Beryl 0.94 66.1 68.6 73.6 73.8 74.0 0.96 65.2 73.1 73.1 73.3 73.4 Cowra (Includes Generation) 0.99 30.3 30.3 30.3 30.3 30.3 1.00 22.8 22.8 22.8 22.8 22.8 22.5 Forbes 1.00 32.7 32.8 32.9 32.9 33.0 0.98 24.8 24.8 24.8 24.9 24.9 4 Manildra 0.95 10.9 10.9 10.9 10.9 10.9 0.95 10.6 10.6 10.6 10.6 10.6 Molong 1.00 4.8 4.8 4.8 4.8 4.8 0.99 4.8 4.8 4.8 4.8 4.8 Mudgee 0.99 22.4 22.5 22.5 22.5 22.6 1.00 20.2 20.2 20.2 20.2 20.2 Orange 66 0.93 54.4 54.4 54.5 54.5 54.5 0.97 62.5 62.5 62.5 62.5 62.5 Orange 132 0.98 150.4 150.4 150.4 150.5 150.8 0.97 152.5 152.8 153.1 153.5 153.9 Panorama (Includes Generation) 0.95 72.0 72.0 72.0 72.0 72.0 0.97 74.3 74.3 74.3 74.3 74.3 9.9 Parkes 66 0.98 25.5 25.5 25.5 25.5 25.6 1.00 20.0 20.0 20.0 20.0 20.0 Parkes 132 0.92 32.2 32.2 32.2 32.2 32.2 0.92 32.3 32.3 32.3 32.3 32.3 Wallerawang 66 0.94 4.6 4.6 4.6 4.6 4.6 0.99 6.2 6.2 6.2 6.2 6.2 Wallerawang 132 0.85 24.1 24.1 24.1 24.1 24.1 0.87 24.3 24.3 24.3 24.3 24.3 Wellington Town 1.00 10.4 10.5 10.5 10.5 10.6 1.00 8.6 8.6 8.6 8.6 8.6 Major Generation (MW) Wellington 132 0.99 173.4 174.0 174.5 175.0 175.5 1.00 149.6 149.8 150.0 150.3 150.5 103.05 For Public Release December 2015 Page 141 of 183

2.8.3 Transmission - Distribution Connection Point load forecast South and Far West SOUTH & FAR WEST Connection Point Transmission Distribution Connection Point Forecast Forecast PF Summer Forecast Forecast Winter Forecast PF 15/16 16/17 17/18 18/19 19/20 2016 2017 2018 2019 2020 Albury (Union Rd + Jelbart) 0.99 92.1 92.1 92.1 92.1 92.1 1.00 64.8 64.8 64.9 64.9 64.9 Albury (Corowa) 0.94 17.7 17.8 17.8 17.9 18.0 0.97 13.5 13.6 13.6 13.7 13.7 Albury (Mulwala) 0.96 13.4 13.4 13.5 13.5 13.6 0.98 9.0 9.0 9.0 9.0 9.0 Balranald 1.00 3.6 3.6 3.6 3.6 3.6 0.99 2.5 2.5 2.5 2.5 2.5 Broken Hill 22 0.95 38.1 38.2 38.3 38.5 38.6 0.99 34.7 34.9 35.0 35.1 35.3 50 Coleambally 0.89 12.4 12.4 12.4 12.4 12.4 0.89 8.7 8.7 8.7 8.7 8.7 Cooma 11 0.98 9.9 9.9 9.9 9.9 9.9 0.99 12.8 12.8 12.8 12.8 12.8 Cooma 66 (Includes Generation) 0.99 7.1 7.1 7.1 7.1 7.1 1.00 21.0 21.0 21.0 21.0 21.0 6.45 Cooma 132 0.99 44.2 44.2 44.2 44.3 44.3 1.00 50.2 50.2 50.2 50.2 50.2 113.9 Darlington Point 0.97 19.0 19.2 19.4 19.6 19.8 0.99 13.9 13.9 13.9 13.9 13.9 Deniliquin 0.96 48.2 48.4 48.5 48.6 48.8 0.98 35.6 35.6 35.6 35.6 35.6 Finley 132-0.0 0.0 0.0 0.0 0.0-0.0 0.0 0.0 0.0 0.0 Finley 66 (Includes Generation) 0.97 19.9 20.0 20.0 20.0 20.0 0.98 17.4 17.4 17.4 17.4 17.4 2.5 Griffith 0.97 87.0 88.4 89.1 89.5 90.6 0.97 59.1 59.3 61.4 62.5 62.8 Major Generation (MW) Marulan (Includes Crookwell & Woodlawn Generation) 0.97 48.7 48.7 48.7 48.7 48.8 0.99 50.0 50.0 50.0 50.0 50.0 112.8 Morven 0.97 8.3 8.3 8.3 8.3 8.3 1.00 7.1 7.1 7.1 7.1 7.1 Munyang 0.64 5.5 5.5 5.5 5.5 5.5 0.75 38.5 38.5 38.5 38.5 38.5 Murrumbateman 0.99 5.0 5.1 5.1 5.1 5.1 1.00 5.9 5.9 5.9 5.9 5.9 Murrumburrah 0.95 40.1 40.1 40.1 40.2 40.2 0.97 30.9 31.0 31.0 31.0 31.0 Queanbeyan 66 0.98 42.9 42.9 42.9 43.0 43.0 0.99 54.4 54.4 54.4 54.4 54.5 0.05 Queanbeyan 132 (F) 0.93 7.5 8.5 9.4 10.3 13.6 0.96 8.6 9.5 10.5 11.6 14.7 Snowy Adit - 0.0 0.0 0.0 0.0 0.0-0.0 0.0 0.0 0.0 0.0 Tumut (Includes Generation) 0.93 37.7 37.7 37.7 37.8 37.8 0.98 34.1 34.1 34.1 34.1 34.1 14 Wagga 66 0.94 96.0 96.0 96.0 96.0 96.0 0.98 65.2 65.2 65.2 65.2 65.2 Wagga North 132 1.00 60.4 60.4 60.4 60.4 60.4 1.00 54.8 54.8 54.8 54.8 54.8 Wagga North 66 0.93 26.1 26.2 26.4 26.5 26.7 0.97 19.8 19.9 19.9 20.0 20.0 Yanco 0.99 38.7 38.7 38.7 38.7 38.7 1.00 32.3 32.3 32.4 32.5 32.5 Yass 132 1.00 12.5 12.5 12.5 12.6 12.6 0.99 12.3 12.3 12.3 12.3 12.3 76.5 Evans Lane 1.00 29.5 28.9 28.4 27.9 27.6 1.00 40.6 40.6 40.6 40.6 40.6 Mildura 0.98 7.1 7.0 6.9 6.8 6.8 0.99 5.3 5.5 5.7 5.9 6.0 Merbein 0.93 24.7 25.0 25.2 25.4 25.6 0.96 17.8 18.0 18.1 18.3 18.4 Robinvale 0.94 4.3 4.3 4.3 4.2 4.2 0.93 1.5 1.5 1.6 1.6 1.6 For Public Release December 2015 Page 142 of 183

2.9 Forecast of Reliability Target Performance The 2015/2016 financial year brings the introduction of the Service Target Performance Incentive Scheme (STPIS). The STPIS provides incentives for improved normalised reliability performance and penalises reduced normalised reliability performance against SAIDI and SAIFI targets. The following targets have been set by the AER for the network performance component of STPIS for the period 2015/2016-2018/2019. Table 4 - Reliability Performance Feeder Category Unplanned SAIDI (minutes) Unplanned SAIFI (interruptions) Urban 68.47 0.863 Short Rural 212.94 1.923 Long Rural 419.43 2.803 Further to the targets listed in Table 4 are the Reliability and Performance licence conditions set out by the NSW Minister for Energy, which impose reliability performance standards on electricity distributors. These are categorised by different feeder lengths and load densities. Reliability performance standards were met for all feeder categories in 2014/2015. Essential Energy uses this data to make efficient investment decisions for the subtransmission and distribution networks. According to the normalised index that covers the average number of interruptions (SAIFI) and the average time customers are without electricity (SAIDI) during the year, Essential Energy s network reliability in the reporting period increased compared to the previous period. Customers were without electricity for an average of 222 minutes in 2014/15 (SAIDI), compared to 181 minutes in 2013/14. The average frequency of interruptions per customer (SAIFI) was 1.97 in 2014/15, compared to 1.73 in the previous year. For Public Release December 2015 Page 143 of 183

3 IDENTIFIED SYSTEM LIMITATIONS A major part of the planning process involves performing network analysis, using the latest demand forecast, to establish network performance under different loading and network configurations relating to the planning criteria outlined in Essential Energy s licence conditions and internal guidelines. The process then identifies whether the network performance obligations are satisfied within the forward planning period or if corrective action is required to address a network limitation. It should be noted that limitations identified in this report have been assessed under the network conditions and licence requirements pertaining at the time of assembly and are subject to review in the event of any significant change to either. Essential energy defines the normal cyclic ratings for zone substation transformers as 110 per cent of nameplate rating in summer and 120 per cent of nameplate rating in winter. Only primary distribution feeder limitations where network proposals have been developed are included in this section. A distribution feeder strategic review is currently being undertaken with a view to providing more comprehensive advice in subsequent reports. The National Electricity Rules (NER) requires distribution network service providers to investigate non-network options by utilising a thorough consultation process to facilitate input into the planning of major network upgrades. This provides opportunity for interested parties and the community to submit options and ideas allowing for the development of cost effective demand management and other system support options. The NER call for a screening test to be performed for all capital projects above $5M to determine if a non-network option is credible and should be investigated further. If a non-network option is deemed to be feasible Essential Energy will conduct a detailed investigation to determine the objective and targets for a non-network option to be successful and publish this information in a Non-Network Options Report. Alternatively, an in-house demand management investigation may be conducted to identify a suitable non-network option. This section outlines the identified network limitations and provides an indication of the potential network solutions against which the credible non-network alternatives will be assessed. For Public Release December 2015 Page 144 of 183

3.1 Subtransmission Feeder Limitations IDENTIFIED SUBTRANSMISSION FEEDER LIMITATIONS Region Northern Beryl Feeder Number and Name 94M Mudgee System Limitation Details Driver Timing Loss of Mudgee ZS load for loss of 132 feeder 94M or single transformer (132/22) Capacity/ Growth Potential Transfer Existing 0 reduction required for 1 year deferral (MW) 4.7 Impact on Transmission- Distribution Connection Point Nil Potential Credible Solutions 1. Remove the Gulgong load from the existing alternate 66 supply, by the establishment of a new zone substation at alternate site (Gulgong West) 2. Install auto change over scheme from 132 to 66 Northern Dubbo Northern Nyngan 94F and 94J Dubbo STS, Nyngan STS 811 Nyngan STS to Cobar Town ZS Security of supply, voltage regulation and thermal constraint issues for all loads west of Wellington for loss of either 132 feeders 94F Voltage drops along the Nyngan to Cobar 66 #811 feeder (130km) are excessive at maximum load, and 150 spans need to be augmented to achieve required line rating Capacity/ Growth Capacity/ Growth Existing 0 40 Existing 0 2.5 Nil Nil 1. Construct 3rd Wellington to Dubbo 132 feeder 2. Install Dynamic VAr Compensation throughout the network 1. Install a 66 V/Reg and augment existing 66 line to a 65C rating 2. Establish Cobar 132/66 Zone Northern Nyngan 9GU and 94W Nyngan STS Security of supply to the Nyngan and Cobar loads for the loss of either 132 feeder 9GU or 94W feeder Capacity/ Growth Existing 0 35 Nil 1. Installation of dynamic var compensation 2. Establish a 3rd 132 feeder from Dubbo to Nyngan Northern Waggamba On loss of radial 132 supply to Goondiwindi Ergon Energy from Ergon Energy and the single 132/66/33 Waggamba 66 transformer, there is limited backup 66 supply from New South Wales Capacity/ Growth Existing 0 4.7 Nil 1. Install second 132/66/33 transformer 2. Install second 132 line from Bulli Creek to Goondiwindi South East Bega 84A Pambula Unsatisfactory voltage at Pambula ZS for loss of 66 feeder 84A Bega STS to Pambula ZS Capacity/ Growth Existing 0 Not Applicable Nil 1. Connect 66 feeder 89G into Pambula ZS South East Bega 89B Bega STS to Maher St ZS For the loss of the either radial 66 feeder 89B or 89C from Bega STS to Maher St ZS - All of Maher St ZS is lost Capacity/ Growth Existing Project Under Construction Nil 1. Under Construction - 2nd 66 feeder from Bega STS to Maher St ZS (Under construction) South East Orange 807 Orange STS to Orange West Thermal limitation on feeder 807 for loss of feeder 8C2 Capacity/ Growth Existing 0 2.5 Nil 1. Reconductor the existing powerline For Public Release December 2015 Page 145 of 183

Subtransmission Feeder Limitations Cont d IDENTIFIED SUBTRANSMISSION FEEDER LIMITATIONS Region Southern Griffith Southern Wagga Feeder Number and Name 79P and 79R Griffith STS to Tharbogang ZS #2 Hammond Ave Tee to Hammond Ave System Limitation Details Driver Timing Thermal and voltage regulation limitation on either feeder 79P or 79R for loss of the other feeder Network limitations associated with tee connection Capacity/ Growth Capacity/ Growth Existing Potential Transfer 0 reduction required for 1 year deferral (MW) 6 Impact on Transmission- Distribution Connection Point Nil Potential Credible Solutions 1. Augment existing 33 powerlines 79P and 79R and install voltage regulation at Tharbogang 2. Construct new 132/33 substation at Griffith West complete with new 33 and 132 feeders Existing 0 19.9 Nil Connect #2 feeder to Copland St substation Southern Wagga 842/5 and 845/4 Kooringal Tees to Kooringal Network limitations associated with tee connection Capacity/ Growth Existing 0 16.8 Nil Connect 842/5 feeder to Copland St and establish a second feeder from Copland St to Kooringal Southern Wagga 845/4 Copland St to Bourkelands St Thermal rating limitation under contingent conditions Capacity/ Growth Jun-19 0 1 Nil 1. Reconductor 1.5km section of 66 line #5 2. Demand Management Alternative Southern Wagga 8WM Morrow St Total loss of supply at Morrow St ZS for loss of feeder 8WM Capacity/ Growth Oct-18 0 13 Nil Construct 66 bus bar at Morrow St ZS For Public Release December 2015 Page 146 of 183

3.2 Subtransmission and Zone Limitations IDENTIFIED SUBTRANSMISSION and ZONE SUBSTATION LIMITATIONS System Limitation Region Name Details Driver Timing Potential Transfer reduction required for 1 year deferral (MW) Impact on Transmission- Distribution Connection Point Potential Credible Solutions Northern Beryl Northern Beryl Mudgee Ulan Sw Stn Security of supply to the Mudgee load upon the loss of the 132 supply or single transformer (132/22) at the Mudgee ZS Ulan 66 switching station works Capacity/ Growth Capacity/ Growth Existing 0 4.7 Nil 1. Remove the Gulgong load from the existing 66 alternate supply, by establish a new zone substation at altenate site (Gulgong West). 2. Install an automatic change over scheme from the 132 supply to the 66 supply. Existing 0 Not Applicable Nil 1. Construct additional switching station equipment South East Molong Molong 132/66/11 Security of supply to the Molong load upon the loss of single transformer (66/11) at the Molong 132/66/11 ZS Capacity/ Growth Existing 0 Not Applicable Nil 1. Install second transformer South East Queanbeyan Sutton Single Transformer substation - loss of load for transformer failure Capacity/ Growth Existing 0 3.5 Nil 1. Install second transformer For Public Release December 2015 Page 147 of 183

3.3 Primary Distribution Feeder Limitations IDENTIFIED PRIMARY DISTRIBUTION FEEDER LIMITATIONS Region Feeder Number System Limitation Normal Cyclic Extent Exceeds Normal Cyclic (%) Summer Winter Summer Winter Details Driver Timing Summer Winter 2015/16 2016 2016/17 2017 reduction required for 1 year deferral (MW) Location Potential Credible Solutions North Coast Coffs Harbour Coffs South Zone (11 distribution) All 11 Limited 17.3MVA (max) distribution on either of 2 Tx breakers feeders at Zone Thermal Capacity On going 17.3 17.3 - - - - - - Monitor. Coffs Harbour South Zone has load limitation of 17.3MVA on either of the 2 transformer circuit breakers. The limit is to prevent thermal run away (advice from manufacturer). Transfer load to adjoining zone substations to prevent exceeding 17.3MVA North Coast Coffs Harbour Woolgoolga WGA3B1 7/3.00 AAC 167 Amps @ 65 Deg C op temp. One off peak load of 3MVA in 2014/2015 Thermal Capacity Nov-14 3.2 3.2 - - - - - - Monitor. 7/3.00 AAC Libra conductor used within 700m of zone substation. Consider two options - increase operating temp to 75 Deg C - 3.8 MVA or reconductor with 7/4.50AAAC North Coast Taree Wingham 4984 Exit cable Thermal Capacity 2015/16 4.57 4.57 - - - - - - Monitor. Significant add load being undertaken by the large customer, requesting 3.5MVA transfer capacity. Peak Summer load to exceed thermal rating of ZS exit cable of 4.57MVA. Customer to undertake upgrade of the network as a large load customer Northern Tamworth Oxley Vale OXY3B9 0.25 sq inch PLYSW Thermal 2015/16 4.48 4.48 20% 20% 20% 20% 1 Tamworth Medical Precinct This is the alternate supply for the medical precinct which has requirement of 5-6MVA peak demand. Project has been raised since has refurishment and cast pothead constraints as well For Public Release December 2015 Page 148 of 183

Primary Distribution Feeder Limitations Cont d IDENTIFIED PRIMARY DISTRIBUTION FEEDER LIMITATIONS Region Feeder Number System Limitation Normal Cyclic Extent Exceeds Normal Cyclic (%) Summer Winter Summer Winter Details Driver Timing Summer Winter 2015/16 2016 2016/17 2017 reduction required for 1 year deferral (MW) Location Potential Credible Solutions South Eastern Cooma Jindabyne 66/33/11 JIN72 70mm Al PLYSW 3C Thermal rating of cable 2015/16 3.3 3.3 23% 64% 23% 64% 1 Sub 13-1748 shedded and load moved to adjacent Some load has been transferred and o/p Cobbin Cres feeder load control improvements have been JIN32,NB This feeder completed enabling project 1143741 to has town expansion be deferred until the 18-19FY occurring with Highview Estate sub division. Southern Albury Mulwala 132/22 FIN53 Voltage limitations in the 22 supply to Barooga town due existing peak loads and moderate growth Capacity/ Growth Existing 5 5 10% 10% 10% 10% 0.5 Barooga 1. Upgrade existing regulator site and install capacitor support in Barooga town 2. Establish 2nd 22 feeder from Finley to Tocumwal to provide support for FIN52 and MWA8B1. Transfer part Barooga load to Mulwala Southern Buronga Koraleigh KOR23 Thermal and Voltage limitations in the 22 feeders supplying Murray Downs Capacity/ Growth Existing 1 1 30% 0% 40% 0% 0.3 Murray Downs Reconductor 10km section of 3/4/0.093 conductor up to 7/4.50AAAC Southern Buronga Koraleigh KOR24 Voltage limitations in the 22 feeder supplying Tooleybuc and areas north Capacity/ Growth Existing 2 2 30% 0% 35% 0% 0.6 Tooleybuc Install Voltage Regulator site before Tooleybuc town and install capacitor support at load centre Southern Deniliquin Finley 66/22 FIN52 Voltage limitations in the 22 supply to Tocumwal town due existing peak loads and moderate growth Capacity/ Growth Existing 5 5 10% 10% 10% 10% 0.5 Tocumwal 1. Install capacitor support in Tocumwal town to provide voltage support 2. Establish 2nd 22 feeder from Finley to Tocumwal to provide support for FIN52 and MWA8B1 For Public Release December 2015 Page 149 of 183

Primary Distribution Feeder Limitations Cont d IDENTIFIED PRIMARY DISTRIBUTION FEEDER LIMITATIONS Region Feeder Number Southern Deniliquin Southern Griffith Moama Griffith 132 MOA23 MOA25 79P System Limitation Normal Cyclic Extent Exceeds Normal Cyclic (%) Summer Winter Summer Winter Details Driver Timing Summer Winter 2015/16 2016 2016/17 2017 Thermal and Voltage limitations in the 22 feeders supplying Moama urban areas Voltage limitations in the 33 network due to numerous proposed additional loads with expansion of Chicken broiler farms in Tabbita/ Goolgowi Capacity/ Growth Capacity/ Growth reduction required for 1 year deferral (MW) Location Existing 10 10 5% 0% 10% 0% 0.5 Moama 2015/16 10 10 60% 60% 100% 100% 4 Goolgowi/ Tabbita Potential Credible Solutions Reconductor and augmentation existing 22 feeders 1. Installation of regulators in alternate supply from 33 network from Hillston 132 supply and supply initial loads from here 2. Reconfigure Griffith 33 and establish dedicated 33 feeder to Tharbogang ZS and install new 20MVA Regulator site Southern Robinvale Robinvale 66/22 RBV Euston 22 Thermal and Voltage limitations in the 22 feeders supplying Euston Capacity/ Growth Existing 5.8 5.8 43% 43% 86% 86% 2.5 Euston Negotiate increased transfer capacity from Robinvale supply (Powercor) Southern Wagga Wagga Uranquinty UQT8B1 Existing 11 supply insufficent Capacity/ Growth Existing 1 1 10% 0% 10% 0% 0.1 Mangoplah Extend new 22 line from Olympic H/way to Mangoplah Rd at the Rock. Convert existing Mangoplah 11 between the Rock Village & Manoplah village to 22. Install step down TX's on major spur lines. For Public Release December 2015 Page 150 of 183

4 NETWORK INVESTMENTS 4.1 Regulatory Test / RIT-Ds completed or in progress There are no RIT-Ds that have been completed or were in progress in 2015. 4.2 Potential RIT-Ds for identified system limitations Essential Energy has not identified any network system limitations that may require the publication of a RIT-D. 4.3 Commited Investments 4.3.1 Refurbishment and replacement investments Essential Energy has identified refurbishment or replacement Projects as shown in Table 5. Table 5 - Refurbishment and Replacement Projects Region DAPR Section Refurbishment or Replacement Project Commission Date Estimated Cost Southern Yanco 4.3.1.1 Leeton ZS Refurbish 33/11 substation due to asset condition May-16 $5.0M Northern Moree South East Goulburn 4.3.1.2 4.3.1.3 Moree ZS Replace 11 switchboard due to asset condition Woodlawn ZS Rebuild 66/11 substation due to asset condition Feb-16 Nov-15 $3.0M $6.2M South East Goulburn North Coast Lismore 4.3.1.4 4.3.1.5 Marulan South ZS Rebuild 66/11 substation due to asset condition Murwillumbah ZS Replace 11 switchboard due to asset condition Mar-17 Mar-16 $3.2M $3.9M North Coast Grafton 4.3.1.6 Grafton North ZS Replace 11 switchboard due to asset condition Mar-16 $2.8M South East Cooma 4.3.1.7 Cooma Establish 66/11 substation in conjunction with Transgrid 132/66 substation reconstruction Mar-17 $10.1M South East Orange North Coast Stroud North Coast Coffs Harbour 4.3.1.8 4.3.1.9 4.3.1.10 Orange North ZS TransGrid rebuild Orange 66 busbar Bulahdelah ZS Replace 11 switchboard due to asset condition Dorrigo ZS Replace 11 switchboard due to asset condition Oct-17 Oct-16 Jun-17 $5.5M $2.9M $2.3M North Coast Port Macquarie 4.3.1.11 Rocks Ferry ZS Replace existing 33 Bus due to asset condition Jun-16 $1.8M For Public Release December 2015 Page 151 of 183

Region DAPR Section Refurbishment or Replacement Project Commission Date Estimated Cost Northern Dubbo 4.3.1.12 Nevertire ZS - Refurbish 132/66/22 substation due to asset condition Mar-17 $3.2M Far West Nyngan 4.3.1.13 Cobar CSA ZS Refurbish Transformers and replace aging assets Dec-16 $4.4M Far West Nyngan 4.3.1.14 Nyngan 132 ZS Replace CB s and VT s Sep-17 $4.8M North Coast Lismore 4.3.1.15 Kyogle ZS Refurbish 66/11 substation due to asset condition May-16 $2.5M North Coast Kempsey 4.3.1.16 Prince Street ZS Refurbish substation due to aging assets Jun-16 $5.3M Far West Nyngan 4.3.1.17 Nyngan to Cobar area 132 lines Refurbish lines at end of life Jun-16 $3.5M 4.3.1.1 Refurbish Leeton Zone Project Description The Leeton Zone was constructed in the 1960s and much of its electrical equipment requires replacement. This project refurbishes the substation on its existing footprint. Alternative Options Construct a new zone substation near the existing substation and decommission the existing substation. This option was not the most cost effective option. 4.3.1.2 Refurbish Moree Zone Project Description A large proportion of the electrical equipment within the Moree zone substation requires replacement. This project refurbishes the substation on its existing footprint. Alternative Options Construct a new zone substation near the existing substation and decommission the existing substation. This option was not the most cost effective option. 4.3.1.3 Refurbish Woodlawn Zone Project Description A large proportion of the electrical equipment within the Woodlawn zone substation requires replacement. This project refurbishes the substation on the existing footprint. Alternative Options Construct a new zone substation near the existing substation and decommission the existing substation. This option was not the most cost effective option. 4.3.1.4 Refurbish Marulan South Zone Project Description A large proportion of the electrical equipment within the Marulan South zone substation requires replacement. This project rebuilds the substation on an adjacent site. For Public Release December 2015 Page 152 of 183

Alternative Options Construct a new zone substation near the existing substation and decommission the existing substation. This option was not the most cost effective option. 4.3.1.5 Refurbish Murwillumbah Zone Project Description The 11 switchboard within the Murwillumbah zone substation is required to be replaced due to its asset condition. This project involves the construction of a new 11 switchroom within the existing substation footprint. The project also includes replacement of the 11 transformer cables and most of the 11 feeder cables exiting the 11 switchboard. Alternative Options The alternative was to replace the 11 switchboard within the existing building. However, this option was ruled out because the new switchboard could not be installed safely into this existing building. 4.3.1.6 Refurbish Grafton North Zone Project Description The 11 switchboard within the Grafton North zone substation is required to be replaced due to its asset condition. This project involves the construction of a new 11 switchroom within the existing substation footprint. The project also includes replacement of the 11 transformer cables and most of the 11 feeder cables exiting the 11 switchboard. Alternative Options The alternative was to replace the 11 switchboard within the existing building. However, this option was not considered suitable due to the safety risks identified with the new switchboard being installed in the existing building. 4.3.1.7 Rebuild Cooma 66/11 Project Description Due to asset age and condition of the TransGrid Cooma 132/66/11 substation, TransGrid will be constructing a new 132/66 substation 350m north of their existing site. As a result Essential Energy will construct a 66/11 substation on the existing old Cooma site to supply the surrounding Cooma 11 distribution network. All affected Essential Energy assets including 132 and 66 powerlines will be constructed by Essential Energy. Alternative Options TransGrid have assessed all options in their Options Evaluation Report. The rebuild of the Cooma substation on a new site was determined to be the preferred option based upon its technical feasibility, cost and timing. Once complete, sufficient space will be afforded for Essential Energy to construct a new 66/11 substation on the existing old Cooma substation site. Non-network solutions were not considered feasible as no practical options were identified which could supply the existing substation load. 4.3.1.8 Refurbish Orange North Zone Project Description TransGrid are refurbishing their Orange 132/66/ substation and are installing a 66 indoor switchboard. Essential Energy own 66/11 transformers and frequency injection (FI) equipment that are located within the TransGrid yard. The Essential Energy 11 switchboard is located adjacent to the TransGrid substation. The project involves Essential Energy relocating the 66/11 transformers, the 66 FI equipment and 11 transformer cables within the TransGrid substation. It also involves relocating the 66 feeders to connect into the 66 indoor switchboard. For Public Release December 2015 Page 153 of 183

Alternative Options Relocate the 66/11 transformers, the 66 FI equipment and 11 transformer cables to a new site near the existing site. However, there is no suitable location available and project costs would be higher. 4.3.1.9 Refurbish Bulahdelah Zone Project Description The Bulahdelah zone substation was originally constructed as an outdoor substation using timber structures to mount both the 33 switchgear and the 11 switchgear. The equipment has reached end of life and requires replacement. This project involves replacing the 11 equipment with an indoor switchboard and refurbishing the 33 equipment within the substation on its existing footprint. Alternative Options The option to change to outdoor equipment is more expensive than the preferred option. 4.3.1.10 Refurbish Dorrigo Zone Project Description The 11 switchboard within the Dorrigo zone substation is required to be replaced due to its asset condition. This project involves the construction of a new 11 switchroom within the existing substation footprint. The project also requires replacing the 11 transformer cables as well as replacing most of the 11 feeder cables. Alternative Options The alternative was to replace the 11 switchboard within the existing building. However, this option was ruled out because the new switchboard could not be installed safely into the existing building. 4.3.1.11 Refurbish Rocks Ferry Zone Project Description The Rocks Ferry zone substation was constructed in the 1960s and most of its electrical equipment requires replacement. This project refurbishes the 33 bus and associated equipment on its existing footprint. Alternative Options Construct a new 33 switchboard building within the existing zone substation footprint and decommission the existing outdoor 33 bus. This option was more costly than the preferred option. 4.3.1.12 Refurbish Nevertire Zone Project Description The Nevertire zone substation was constructed in 1963 and most of its electrical equipment requires replacement. This project replaces the outdoor 22 busbar with an indoor switchboard and replaces some of the 132 and 66 equipment identified in the Asset Management Plan. Alternative Options Other options considered included the installation of a fence around the existing 22 bus, or refurbishing the outdoor busbar within the existing footprint. The switchboard installation is the preferred solution from an engineering and safety perspective. 4.3.1.13 Refurbish Cobar CSA Zone Project Description The Cobar CSA zone substation was constructed in 1965 and much of its electrical equipment requires replacement. The project involves refurbishing the existing transformers and adding fans to For Public Release December 2015 Page 154 of 183

increase the maximum rating, as well as replacing a number of HV assets that have been identified for replacement. Alternative Options The alternative option is to install new transformers, which is not the most cost effective option. 4.3.1.14 Refurbish Nyngan 132 Zone Project Description Equipment within the Nyngan 132 zone substation is at end of life and requires replacement. The project involves replacing all the circuit breakers and voltage transformers, and upgrading the control and protection panels. Alternative Options The alternative option replaces the existing oil equipment with compact Gas Insulated Switchgear (GIS) and is significantly more expensive than the preferred option. 4.3.1.15 Refurbish Kyogle Zone Project Description Kyogle Zone s electrical equipment requires replacement due to its condition. This project refurbishes the substation on its existing footprint. Alternative Options The alternative options had inherent future maintenance issues, and required more outages during construction. 4.3.1.16 Refurbish Prince Street Kempsey Zone Project Description Prince Street Kempsey zone substation s electrical equipment requires replacement due to its condition. This project refurbishes the substation on its existing footprint by adding a 33 switchboard building to replace the aging outdoor equipment, and replacing the 11 switchboard with a new building. Alternative Options The alternative options were not cost effective. 4.3.1.17 Refurbish Nyngan to Cobar 132 line Project Description There are a number of sections of the Nyngan to Cobar area 132 subtransmission lines that are at end of life. This project refurbishes those sections to ensure continued supply to the Cobar area. Alternative Options There are no feasible alternatives. 4.3.2 Urgent and unforseen investments There have been no urgent or unforseen investments. For Public Release December 2015 Page 155 of 183

5 JOINT PLANNING Joint Planning is a requirement under Clause 5.14 of the NER, which requires Essential Energy to carry out joint planning with each Network Service Provider (NSP) to which its networks are connected. Consequently, Essential Energy conducts joint planning activities with Transmission Network Service Providers (TNSP s) TransGrid and Powerlink Queensland. At a DNSP level it conducts such activities with Energex, Ergon Energy, Ausgrid, Endeavour Energy, ActewAGL and Powercor. The frequency, process and methodology of such joint planning depends upon the timing of emerging network constraints due to growth, reliability and refurbishment needs as well as other external drivers such as third party connection requests to service new or augmented major loads and generators. The objective of joint planning is to identify the most efficient network or non-network option to address the need in a prudent manner, irrespective of ownership, jurisdiction or boundary. In general the process and methodology takes the form of establishing a formal Joint Planning committee between the relevant parties (Essential Energy and the NSP or in some cases multiple NSP s) which, depending upon the emerging limitation(s), severity and impact, will then as necessary, meet to jointly confirm, quantify, review, recommend and resolve the matter(s). This is undertaken using agreed technical, unit cost, fiscal, risk and sensitivity assessment assumptions and criterion to compare and evaluate the viable non-network and network alternatives in order to select, plan, and deliver the most prudent investment(s) in accordance with NER requirements and objectives. In the case of shared investments over a combined total threshold of $10M, regulatory consultation documentation and notifications are prepared and published jointly in accordance with the NER process requirements. For investments below this threshold value, the appropriate investment case documentation is shared and held by the joint parties. Where necessary, in both instances, a Joint Planning Report (JPR) is executed to define the high level responsibilities of both parties in delivering, funding and owning the investment or parts thereof. 5.1 Results of Joint Planning with the TNSP TransGrid in 2015 5.1.1 Summary of the process and methodology An existing Joint Planning committee made up of relevant network planning staff from both Essential Energy and TransGrid have met regularly throughout the past year. Issues and outcomes were minuted with actions, and where necessary, issues were referred to an overseeing joint Executive Steering Committee. For Public Release December 2015 Page 156 of 183

5.1.2 Investments jointly planned in 2015 Table 6 - TransGrid Joint Planning Projects Brief Description TransGrid Tamworth 132/66 subtransmission substation rebuild (condition based assessment) TransGrid Cooma 132/66 subtransmission substation rebuild (condition based assessment) TransGrid Orange 132/66 subtransmission substation 66 assets and secondary systems replacement (condition based assessment) TransGrid Wagga Wagga 132/66 subtransmission substation rebuild (condition based assessment) TransGrid Taree substation 33 switchyard replacement (condition based assessment) Estimated Total Capital Cost Estimated Timing $50M Jun-17 $52M Nov-15 $34M Apr-17 $52M Jun-20 $9M Jun-18 In addition to the above, several other minor projects and redundant asset transfers were coordinated and negotiated through the Joint Planning Committee in 2015. 5.1.3 Additional Information Additional information on the above investments may be obtained from the Essential Energy and TransGrid websites, and as published in the preceding and latest TransGrid Transmission Annual Planning Reports. 5.2 Results of Joint Planning with the TNSP Powerlink in 2015 5.2.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with Powerlink Queensland, this is mainly due to the past decline in demand forecasts and the fact that no limitations on the interconnecting 110 networks are imminent. Joint planning has therefore been mainly limited to telephone/email discussions between the respective network planning or customer connection teams. 5.2.2 Investments jointly planned in 2015 Nil. 5.2.3 Additional Information Nil. 5.3 Results of Joint Planning with the DNSP Energex in 2015 5.3.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with Energex, this is mainly due to the past decline in demand forecasts and the fact that no limitations on the interconnecting 66 subtransmission and 11 distribution networks are imminent. Joint planning For Public Release December 2015 Page 157 of 183

has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.3.2 Investments jointly planned in 2015 Nil. 5.3.3 Additional Information Nil. 5.4 Results of Joint Planning with the DNSP Ergon in 2015 5.4.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with Ergon Energy, this is mainly due to the past decline in demand forecasts and the fact that no limitations on the interconnecting subtransmission and distribution networks are imminent. Joint planning has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.4.2 Investments jointly planned in 2015 Nil. 5.4.3 Additional Information Nil. 5.5 Results of Joint Planning with the DNSP Ausgrid in 2015 5.5.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with Ausgrid, this is mainly due to the past decline in demand forecasts and the fact that no limitations on the interconnecting 33 and 11 networks are imminent. Joint planning has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.5.2 Investments jointly planned in 2015 Nil. 5.5.3 Additional Information Nil. 5.6 Results of Joint Planning with the DNSP Endeavour Energy in 2015 5.6.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal joint planning meetings with Endeavour Energy this is mainly due to the past decline in demand forecasts and the fact that no limitations on the interconnecting subtransmission networks are imminent. Joint planning has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.6.2 Investments jointly planned in 2015 Nil. For Public Release December 2015 Page 158 of 183

5.6.3 Additional Information Nil. 5.7 Results of Joint Planning with the DNSP ActewAGL in 2015 5.7.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with ActewAGL, this is mainly due to the fact that no limitations on the neighbouring networks are imminent. Joint planning has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.7.2 Investments jointly planned in 2015 Nil. 5.7.3 Additional Information Nil. 5.8 Results of Joint Planning with the DNSP Powercor in 2015 5.8.1 Summary of the process and methodology In 2015 there has been no important need to conduct formal Joint Planning meetings with Powercor, this mainly due to the fact that no limitations on the interconnecting 66 and 22 networks are imminent. Joint planning has therefore been limited to a few telephone/email discussions between the respective network planning teams. 5.8.2 Investments jointly planned in 2015 Nil. 5.8.3 Additional Information Nil. For Public Release December 2015 Page 159 of 183

6 NETWORK PERFORMANCE 6.1 Reliability Performance There were no criteria set for the Service Target Performance Incentive Scheme (STPIS) for Essential Energy in the 2014/15 regulatory period. Reliability reporting is in accordance with the NSW Design, Reliability and Performance Licence Conditions for Distribution Network Service Providers (Licence Conditions). The reliability measures used are System Average Interruption Duration Index (SAIDI), minutes without supply for the average customer, and System Average Interruption Frequency Index (SAIFI), number of interruptions experienced by the average customer. Performance is monitored at distribution feeder level for unplanned interruptions exclusive of major weather events and circumstances beyond the reasonable control of the distributor. Distribution feeders are categorised as Urban, Short Rural or Long Rural, based on feeder length and load density. Essential Energy s distribution network consists of 294 Urban Feeders, 915 Short Rural Feeders and 244 Long Rural Feeders, with over 60 per cent of customers on Short Rural Feeders. 6.1.1 Performance against Feeder Category Standards Reliability outcomes by feeder category for the 2014/2015 financial year fell outside licence conditions for urban and long rural feeders. Table 7 - Feeder Performance by Category Feeder Category SAIDI (minutes) SAIFI (no of interruptions) Target Actual Target Actual Urban 74 72 0.93 0.97 Short Rural 238 207 2.08 1.99 Long Rural 474 489 3.14 3.28 6.1.2 Performance against Individual Feeder Standards The performance objectives for organisational average performances by feeder category are not sufficient to identify when customers on a particular feeder experience unsatisfactory reliability performance. For this reason, SAIDI and SAIFI criteria (after excluded interruptions are disregarded) act as a trigger for investigation and exception reporting purposes. The figures contained in the licence conditions are shown in Table 8 and Table 9. Table 8 - Individual feeder standards for exception reporting specified in the Licence Conditions applicable to Essential Energy Feeder Category Urban Short Rural Long Rural SAIDI 400 1,000 1,400 SAIFI 6 8 10 Performance outside this range results in the following actions: Immediate investigation of the causes for each feeder exceeding the individual feeder standards For Public Release December 2015 Page 160 of 183

By the end of the quarter following the quarter in which the feeder first exceeded the individual feeder standard, complete an investigation report identifying the causes and action required to improve the performance Complete any operational actions identified in the investigation report by the end of the third quarter following the quarter in which the feeder first exceeded the standard Where the investigation report identifies actions, other than operational actions, required to improve the performance of each feeder to the individual feeder standards, develop a project plan, including implementation timetable, and commence its implementation by the end of the second quarter following the quarter in which the feeder first exceeded the individual feeder standards. Table 9 - Individual Feeder Performance against the Standard Summary Feeder Category Urban Short Rural Long Rural Feeders (Total Number each Type) 294 915 244 Feeders that the Standard During the Year (Total Number) 10 46 30 6.2 Quality of Supply Performance The Electricity Supply Standards adopted by Essential Energy are set out in the document CEOP8026 Electricity Supply Standard, in accordance with the Code of Practice Electricity Service Standards. A copy of CEOP8026 can be downloaded from essentialenergy.com.au CEOP8026 also outlines Essential Energy s adoption of the Australian Standard AS 60038 2012 Standard Voltages. The main areas addressed include: Voltage fluctuations managed in accordance with Australian Standards AS/NZS 61000.3.3:2012, 61000.3.5:1998 and 61000.3.7:2012 Switching transients (voltage waveform distortion) limited where possible to less than twice normal supply voltage Frequency variation and Essential Energy s role in notifying AEMO of any sustained fluctuations Voltage dips managed through best practice network improvement and augmentation Steady state voltage differences between neutral and earth limited to less than 10 volts at the customer s point of supply Lightning strikes limited in their impact on supply where possible by adherence to industry best practice system design and maintenance principles Limitation of step and touch voltage differentials managed in accordance with industry standards, namely ENA Earthing Guide AS/NZS 7000:2010 Limiting of voltage imbalance to a 6 per cent difference on the LV network using 10 minute average values between the highest and lowest phase to neutral or phase to phase steady state voltages (This may be exceeded on occasions in rural areas) Harmonic content of voltage and current waveforms managed in accordance with Australian Standards AS 61000.3.6:2012 For Public Release December 2015 Page 161 of 183

Mains signalling reliability set at a target of 99.5 per cent failsafe to ensure correct switching and metering functions. Quality of supply is monitored through power quality enquiries received from customers and also through participation in the Power Quality Compliance Audit conducted by the University of Wollongong and a number of other distributors throughout Australia. This survey studies parameters such as steady state voltage, voltage total harmonic distortion (THD), voltage sags and voltage unbalance on three phase sites. All valid complaints which are assessed as being network related or issues identified via network monitoring are addressed to ensure the situation is rectified and maintained within standards. Remedial actions could include but are not limited to; adjusting tap settings on transformers, adjusting voltage regulation levels, installing additional or larger transformers, augmenting network capacity, repairing network faults and balancing network loads.. Table 10 - Completed investigations from network complaints Network Complaint Investigations Completed 2014/2015 Category Nature of Complaint Number Voltage Number Valid Sustained over voltage 85 67 Sustained under voltage 63 40 Voltage fluctuations 209 94 Voltage dips 66 38 Voltage swell 1 0 Switching transients 0 0 N-E voltage difference 77 40 Ground fault voltage 1 0 Voltage unbalance 2 2 Mains signalling voltages (Outside defined range) 0 0 HV injection (HV/LV Intermix) 0 0 Notching 0 0 Invalid (223 confirmed invalid) Sub total (Supply Voltage Complaints) 504 281 Current Direct current 0 0 Harmonic content 0 0 Inter Harmonics 0 0 Invalid ( 0 confirmed invalid) Sub total (Supply Current Complaints) 0 0 For Public Release December 2015 Page 162 of 183

Category Nature of Complaint Number Other Quality Number Valid Mains signalling reliability 0 0 Noise & Interference 81 28 Level of supply capacity 31 21 Generation (Solar) 124 100 Generation (Wind) 0 0 Supply frequency 1 0 Level of EMF 0 0 Customer Equipment Failure 125 26 Invalid (187 confirmed invalid) Sub total (Other Quality of Supply Complaints) 362 175 Sub total (All Quality of Supply Complaints) 866 456 Reliability No. of supply failures 47 16 Duration of supply failures 0 0 Outages Miscellaneous 4 4 No. of <1 min. interruptions 83 12 Invalid (102 confirmed invalid) Sub total (Reliability of Supply) 134 32 Safety Overhead line safety 0 0 Underground safety 0 0 Electrical station safety 0 0 Service line safety 0 0 Invalid (0 confirmed invalid) Sub total (Network Safety) 0 0 Total Completed 1000 488 Other IN Communities 0 0 Under Investigation (not validated) 49 0 Totals 1049 488 For Public Release December 2015 Page 163 of 183

7 ASSET MANAGEMENT 7.1 Essential Energy s asset management approach 7.1.1 Introduction Essential Energy s current asset management approach relies on an asset management system that is made up of a number of artefacts designed to PAS 55-1:2008 and comply with the NSW Treasury requirements for Total Asset Management TPP 08-2. Essential Energy continually monitors ongoing asset management in the international standard space as well as within the electricity industry, with a focus on improving and aligning our asset management system over time. The current format of Essential Energy s asset management system includes: The network asset management plan (NAMP) is the overarching document that defines the overview of the asset management framework and the controlling and supporting process associated with Essential Energy s asset management system. Its purpose is to link the Business Plan strategic objectives and priority actions to the asset management plan outcomes by defining the asset management objectives as well as key support frameworks. Asset management plans detail specific targeted management strategies for a specific class of assets. This enables outcomes to be defined and delivered when managing assets to a defined performance gap and statutory requirements. Network management strategies which can be defined as asset management strategies applied across more than one asset group, and, in general apply across all assets and process the makeup the electrical network. These strategies provide measurable outcomes based high level guide or direction for managing network assets as a complete group. The following sections give a specific overview of asset management plans and details the specifics of Essential Energy s network management strategies to provide an overview of the high level direction used to manage network assets. 7.1.2 Asset Management Plans The AMPs are strategic business plans, used to manage the network assets and deliver service levels to meet stakeholder requirements. Essential Energy has developed 15 AMPs which cover all of its network assets. Each AMP defines the life cycle of a specific group of assets and covers the major drivers of expenditure. The groupings have been chosen to ensure that synergies between assets can be maintained, and to allow the best mix between operating and capital expenditures. Each AMP defines the service levels applicable to the asset group based on stakeholder requirements, and then compares asset capability and current performance to determine if there is a gap. Targets are defined based on the asset capability and service gap, and strategies are developed to achieve the targets. These AMPs are supported by a set of strategic plans, planning reports and individual investment cases. The planning process produces a detailed annual capital expenditure program and sets priorities for capacity augmentation, and supply security, quality and reliability over the current investment horizon. For Public Release December 2015 Page 164 of 183

7.1.3 Network Planning Strategy Essential Energy s network planning strategy ensures the network assets can continue to achieve the service level obligations at the lowest life cycle cost. The main elements of the overall Network Planning strategy are to: Provide an electricity network that is capable of supplying a customer s load requirements before they connect to the network Forecast where new network augmentation or zone substations and associated sub transmission lines and subtransmission stations are required Maintain an appropriate quality of supply and level of reliability on the existing network in accordance with the reliability and quality of supply strategies Facilitate preparation of annual and longer term budgets, that are economically efficient, taking into account both prudent capital investment and on-going maintenance costs 7.1.4 Distribution Growth Strategy Essential Energy has developed this strategy to instil a systematic and consistent approach to the management of demand and load growth throughout the asset management functions. Consequently, the Distribution Growth Strategy provides guidance to, and is a key input for other relevant network strategies, including the Network Asset Management Plan (NAMP) and the supporting Asset Management Plans (AMPs). The Distribution Growth Strategy defines the components that constitute distribution network demand and load growth, the impacts of such peak demand and load growth, and how those components need to be managed. The strategy informs the investment expenditure for network optimisation, augmentation and the management of growth on Essential Energy s distribution network. Additionally the Distribution Growth Strategy includes Demand Management initiatives to allow optimisation of distribution network utilisation and to facilitate the deferment or cancelation of some traditional type augmentation projects. Investments have been included for increasing the proactive monitoring capabilities for load and demand growth and voltage performance of the distribution network that will assist in system optimisation and increasing network utilisation. These investments for Demand Management and Network monitoring will allow for the deferral, reduction or cancellation of investments to cater for demand growth on some parts of the network. 7.1.5 Reliability Strategy The primary purpose of the reliability strategy is to comply with jurisdictional network reliability indices and requirements stipulated in the Reliability and Performance Licence Conditions for Electricity Distributors issued in July 2014 by the Minister for Energy. This includes both overall network reliability standards (Schedule 2) and individual feeder standards (Schedule 3). To comply with these requirements, Essential Energy has established the following strategic approaches to manage network reliability: Reliability management framework, structured to meet regulations and standards but not surpass. Individual Feeder Standards management, targets reliability improvement of individual distribution feeders were underlying performance has trended above the Individual Feeder Standards (Schedule 3) set out in the Reliability and Performance Licence Conditions Worst performing feeder segment management, targets the worst performing one per cent of Essential Energy s network using causal analysis to identify any feeder segments with underlying issues. In developing the worst performing feeder segment strategy For Public Release December 2015 Page 165 of 183

through stakeholder engagement, it has been identified that the program has the support of consumer groups; with many agreeing that it is in line with the needs of the customer In keeping with the Reliability management framework, under the Australian Energy Regulator s Service Target Performance Incentive Scheme (STPIS) Essential Energy is aiming to maintain reliability and achieve a cost neutral STPIS outcome. These strategies are based on the following assumptions: STPIS reliability targets are achievable within reasonable levels of expenditure An operating paradigm where the worst network performance experienced by a customer is expected to be addressed in a financially prudent manner. 7.1.6 Power Quality Strategy The primary purpose of the Power Quality Strategy is to provide direction across Essential Energy s asset management functions to ensure compliance with the standards and regulations stipulated in Electricity Supply Standard (CEOP8026). The scope of this strategy covers measurement, monitoring, maintenance and improvement of power quality across Essential Energy s network. The strategic elements of the overall Power Quality strategy are: Reactive Measures Investigate received power quality complaints and customer feedback quickly and efficiently Verify that power quality problems are indeed network related and are outside the levels prescribed in Electricity Supply Standards Rectify any local or wider area problem in a timely, economic and effective manner, including the use of alternate remediation solutions Consult with and keep customers advised during all steps of investigation and rectification process. Proactive Measures Migrate towards a more proactive power quality management approach through an improved visibility of network power quality performance delivered by leveraging the rollout of network technology and monitoring equipment as detailed in Distribution Network Growth Strategy CEOP2091 Implement a gradual reduction in the maximum distribution voltage to 248 volts which will minimise overvoltage situations and provide headroom for distributed generation Systematic modelling and management of HV feeder voltage profiles and performance Improved management of new and additional loads and embedded generator connections Reliance is placed on network asset management practices to improve network supply quality. For Public Release December 2015 Page 166 of 183

7.1.7 Bushfire Prevention Strategy Essential Energy has developed and implemented several strategies to prevent or minimise the occurrence of fire ignition from electrical assets. The following strategic elements are those relating more specifically to bushfire prevention even though many others exist which may have an indirect relationship. Bushfire prevention strategies include: Undertake asset inspection 7 and maintenance in a prioritised manner with a focus on high fire risk areas, and ensure fire start risks are identified and actioned Undertake vegetation management in the form of tree cutting and clearing to minimise the risk of trees or vegetation coming into contact with live lines or equipment and igniting fires Provide advice and information to owners of private lines to inform them of fire risks on their lines and to make recommendations on risk control actions Institute operational limitations 8 on total fire ban days to minimise the risk of lines or equipment inadvertently starting a bushfire Identify high bushfire risk zones to ensure operations and maintenance activities are undertaken with an increased awareness of bushfire start risk Analyse fire starts proven to be caused by electrical equipment and undertake root cause analysis to identify control or prevention measures that can be instituted or developed. 7.1.8 Environmental Management Strategy The environmental management strategy applicable to Essential Energy s network assets seeks to ensure that the business continues to operate the assets in accordance with stakeholder environmental requirements and relevant environmental regulations, while minimising the overall lifecycle costs. To achieve this outcome, Essential Energy employs an environmental compliance strategy which consists of the following strategic elements: Environmental risk is monitored and assessed Environmental management is included in the asset management process and complies with the Safety, Health and Environmental Manual. 7.1.9 Refurbishment Strategy Essential Energy s refurbishment strategy seeks to ensure that network assets continue to achieve service level obligations while minimising the total life-cycle cost by ensuring the efficient and optimal replacement timing of these assets. Refurbishment strategic elements are: Refurbishment need is established through inspection and condition based risk analysis; Refurbishment timing is planned and executed to minimise network risk and to achieve expenditure smoothing 7 Asset inspection includes the use of LIdar and pre-bushfire season annual fly over inspection of the network 8 Operational limitations include managing the number of auto reclose operations on specific circuit breakers on total fire ban days. For Public Release December 2015 Page 167 of 183

Refurbishment decisions take root-cause analysis results into account. 7.1.10 Maintenance Strategy Essential Energy s maintenance strategy seeks to ensure that the network assets continue to achieve service level obligations while minimising the total life-cycle cost through effective maintenance practices that achieve the productive life of network assets within the business risk tolerance. To achieve this outcome Essential Energy uses a maintenance strategy that consists of the following strategic elements: Asset condition is actively monitored through inspection and defect prioritisation. Testing, preventative and corrective maintenance activities are employed Asset data is captured through maintenance practices Essential spare parts are actively managed Risk-based techniques are employed to prioritise maintenance activities Total life-cycle costs of asset ownership is minimised through opex/capex trade-off and prioritisation of works. 7.1.11 Network Operating Strategy The operating strategy applicable to Essential Energy s network assets seeks to enable achievement of service level obligations while minimising the overall life-cycle costs, through active risk management and operational practices that maintain compliance with design parameters. To achieve this outcome Essential Energy employs an operating strategy that consists of the following strategic elements: Asset availability is proactively managed Operational risk is understood and managed Operation is aided by engineered protective measures and 24 hour monitoring where possible Assets are operated within design parameters and, where design parameters are unknown, conservative limits are applied in-line with industry guidelines and standards Operational resources are strategically deployed Guaranteed service levels payments. 7.1.12 Asset Disposal Strategy Essential Energy s network assets disposal strategy seeks to ensure that the environmental impact of asset disposal is minimised, while any remaining value is maximised. The elements of this disposal strategy are: Environmental hazards are identified and managed Useful parts are recovered Disposal value is maximised. For Public Release December 2015 Page 168 of 183

7.1.13 Delivering the Network Management Strategies The network management strategies outlined above are general in nature but provide the basis for specific asset class asset management plans (AMPs) where details and expenditure are determined, optimised and justified. These asset management plans enable the delivery of the strategies through the successful completion of identified, justified and approved projects and programs of work which are detailed within the AMPs. The delivery of the projects and on-going programs is undertaken by Network Operations, Network Delivery, Engineering, accredited service providers and external contractors. 7.2 Treatment of Distribution Losses Distribution losses refer to the energy used in transporting itself across the distribution network. Of the total 2014/15 energy input into Essential Energy s widely spread network, 7.38 per cent was made up of losses. Essential Energy currently makes network augmentation investment decisions in line with the reliability requirement of the regulatory test where there is no provision to take into account network losses. However, the relative impact of network losses is considered qualitatively in the comparison of advantages and disadvantages of alternative options. Essential Energy s investment decisions are guided primarily by the need to achieve the service level obligations at the lowest life cycle cost and network losses are an optimisation to the composition of the system rather than a determinant of the network itself. Accordingly, Essential Energy s approach ensures that the value of network losses influences decision making with respect to: any network planning and subsequent augmentation specifically the selection of voltage, conductor and transformers network performance, operation and switching asset maintenance and replacement decisions procurement of equipment. Essential Energy has transitioned from the regulatory test to the RIT-D for assessing the cost effectiveness of different investment options in accordance with the 2012 Distribution Network Planning and Expansion Framework Rule Change at the beginning of 2014. Under the RIT-D it is a requirement to take into account market benefits (including network losses) in an investment decision. Essential Energy applies the RIT-D where appropriate for evaluating the effectiveness of different investment options. Network losses are considered in the project development stage, as well as in the detailed planning and approval stages. 7.3 Asset issues impacting identified system limitations Network limitations are identified in the preparation of long term strategic network development plans. These limitations are then subject to detailed planning studies which consider any related issues arising from individual asset management strategies which are likely to have a material impact on the studied network. The detailed planning studies include an assessment of non-network alternatives, fault levels, voltage levels, quality of supply considerations, asset replacement, asset refurbishments and new connection applications. Present value analysis is used to align the constraint solutions with other network requirements and optimise the investment profile to achieve service level obligations at the lowest life cycle cost. For Public Release December 2015 Page 169 of 183

7.4 Obtaining further information on the asset management strategy and methodology Further information on Essential Energy s asset management approach is available by contacting: Essential Energy DM Coordinator PO Box 5730 Port Macquarie NSW 2444 Email: dmcoordinator@essentialenergy.com.au For Public Release December 2015 Page 170 of 183

8 DEMAND MANAGEMENT 8.1 Demand management activities in the preceding year Essential Energy s internal demand management procedures for 2015 complied with the NSW Code of Practice - Demand Management for Electricity Distributors and the National Electricity Rules. The process for 2015 included: Maintenance of a Register of Interested Parties Development and publication of Essential Energy s DM Engagement Strategy Development of common NNSW DM procedure Review of emerging constraints in line with RIT-D process Publication of Consultation Papers via Australian Energy Market Operator (AEMO) and Essential Energy external web pages. Notification to Interested Parties of Demand Management opportunities. Use of non-network service providers to investigate and advise on demand management options. Consultation with prospective Demand Management Service Providers. Collaborative agreements with leading academic institutions Participation in related industry working groups Pooling of demand management knowledge and resources with other NSW distributors under Networks NSW guidance. A review of uncommitted major network augmentation proposals was conducted and in most cases the revised timing for the constraint has deferred the need for the augmentation. As a result there have been no consultations or demand management investigations for major network augmentations undertaken in 2015. New Innovative Demand Management developments during 2015 included: Constraint and Growth mapping which aims to promote non-network proposals from a variety of proponents Creation of standards, guidelines and specifications for field based switched capacitors which will be used to approach the market to source and guide the application of such cost effective technology for business as usual demand management applications Based on the growing interest in battery storage technology behind the meter, Essential Energy is actively reviewing connection standards, metering and tariffs through trials with the aim of guiding the uptake of battery storage whilst ensuring such technology does not negatively impact the network resulting in costly network expenditure. In addition, Essential Energy is currently exploring the possible value battery storage technology can provide through deferring or avoiding network expenditure and appropriate signals required to yield such potential Due to the varying customer density of Essential Energy s network across diverse terrain, there are areas of Essential Energy s network that result in high cost to serve very few customers causing cross-subsidisation of network tariffs. These parts of the network (typically fringes of the current network) present potential viable areas to transfer customers to an off-grid solution and decommission network assets in direct interest of minimising cost to all customers. In the long term interest of customers, Essential Energy is currently exploring the practicality of implementing such least cost solutions within these areas triggered by network investment For Public Release December 2015 Page 171 of 183

Initiation of Control System Optimisation studies for problematic areas of the network, which aims to further improve the cost effectiveness of the load control system and identify least cost alternative load control technology compared to traditional load control equipment There were a number of zone substation capacitor bank installations completed in 2015. Ongoing Innovative Demand Management developments during 2015 included: Ongoing optimisation of power electronic equipment control and application in field trials for energy storage, reactive power and embedded generation to further enhance the cost effectiveness of such technology in business as usual applications to addressing network constraints. Continued development in this technology may lead to mutually beneficial outcomes for both consumers and networks through increased penetration of renewables and mitigation of the adverse effects on network power quality currently experienced. Evaluation of conservation voltage reduction technologies allowing a reduction in both consumers energy and peak demand Evaluation of mid-sized static synchronous compensator for use in power factor correction, as a relatively simple alternative to traditional network augmentation but with major improvements to power quality over existing power factor correction technologies Development of optimisation techniques for existing and future field based power factor correction, ensuring Essential Energy maximises the value of equipment currently being installed on the network and into the future. Knowledge gained from previous innovative demand management developments has resulted in continued improvement to the business case for Demand Management throughout 2015, this has allowed Essential Energy to provide a more cost reflective evaluation of demand management options. This includes: The Energy and Network Capacity project has allowed Essential Energy to capture the long term costs of the inherently lumpy augmentation characteristics of network assets, in the past Essential Energy has struggled to implement demand management programs based on cost effectively deferring any single network element The Energy and Demand Audits project showed that substantial low cost demand management options are available and some only require minor changes to consumer processes or equipment, resulting in benefits both to the individual consumer and the network through the reduction in peak demand. As such, Essential Energy is currently implementing strategies to take advantage of the benefits found across power factor correction and pumping loads, and further researching a number of other promising demand management options which still hold a degree of uncertainty, such as standby generation, load shifting, load shedding and air conditioner efficiency The Grid Interactive Inverter program highlighted the benefits of various inverter control techniques, specification requirements specific to Essential Energy s network and optimised control techniques to maximise network support. Since the commencement of the program, a number of other suppliers have offered to deliver similar benefits; the evaluation of such emerging products and the reduced costs, in addition to other known benefits, continues to permit cost reflective evaluation of demand management options within Essential Energy. For Public Release December 2015 Page 172 of 183

8.2 Plans for demand management and embedded generation Essential Energy has a number of strategic objectives in regards to ensuring positive outcomes for its customers now and in the future through proactive and efficient promotion, development and implementation of demand management and non-network alternatives, including; Enhancement of the business case to further enable demand management and nonnetwork alternatives as a primary element of the planning process and as a broadbased strategy Efficient development and refinement of demand management and non-network alternatives based technical skills, experience and solutions, potentially including: o The development or adoption of Horizon Papers / Technology roadmaps which aim to provide a view of the optimal (in terms of performance and value) long term solutions under each demand management and non-network alternatives category o Trials and review of the available demand management and non-network alternatives technologies and products, including the following possible trials / research: Power Factor Correction - combination four quadrant inverter development Generation, Energy Storage - Residential Energy Storage Pilot, including management and control, Generator Availability evaluation Control - load control as a means of voltage control, HAN development, including survey electricity end-uses, Commercial Air Conditioning load control trial, Alternative Control trials Demand Response - Demand Response System trial Loss reduction - Evaluation of network items for loss reduction potential/cost Alternative measures Minimum Energy Performance Standards (MEPS) engagement Voltage control - implementation of Volt/VAr control including Conservation Voltage Reduction (CVR) Voltage control using switched reactors Encouraging EV charging onto controlled load circuits and tariffs. o Integration of the successful solutions into the business as usual operation, for use in evaluation against existing network augmentations (in conjunction with more accurate valuation methodologies) and for evaluation as a solution for broad-based demand management. Enable and encourage external stakeholder involvement across the following groups; o Customers including the investigation and development of engaging, informing and encouraging customers to reduce peak demand. Integration of those outcomes with the appropriate business plans. o Demand Management service providers - including investigation into methods of engagement, and implementation of those methods and policies in the business. For Public Release December 2015 Page 173 of 183

Reduction of peak demand through the implementation of prudent demand management and non-network alternatives initiatives, potentially including: o Community and customer engagement, information and encouragement rollout; Pricing initiatives Education initiatives Customer Data initiatives Enhanced Service Provider Communications o Demand Management and Non-Network Alternative broad-based rollout; Power Factor Correction rollout Air Conditioning Control Pilot & rollout Hot Water Control Pilot & rollout Pool Pump Control Pilot & rollout. Essential Energy continues to work toward the development of technologies and strategies which will enable demand management and reduced network augmentation investment now and into the future. 8.3 Issues arising from applications to connect embedded generation Essential Energy s distribution network continues to experience isolated issues relating to voltage rise from embedded generation units, resulting in over voltage tripping of the inverters, and in some cases supplying customers with voltages in excess of Australian Standard limits. Since the inclusion of a one per cent voltage rise limit in the Service and Installation Rules of New South Wales, issues related to individual customers, i.e. issues due solely to voltage rise in customer service mains, have reduced with the majority of issues identified related to legacy systems. There are still issues in newer systems where the service conductor is incorrectly sized, identified, or the maximum system output is calculated based on an underestimated service length. Additionally there is some evidence of gaming by a small number of installers adjusting the element conductor details to achieve the required voltage rise. There are also issues that revolve around voltage rise along low voltage distribution feeders due to a high penetration of embedded generation within localised areas. This issue typically arises in overhead network areas consisting of original overhead network low voltage conductor; which represents a significant proportion of Essential Energy s network area. Export limited inverters have allowed for the reduction in voltage rise issues at the customer s switchboard and provides greater equity in systems where multiple customers share a single transformer. The export limit allows customers to install the most economically sized systems while capping the amount that can be fed back into the network. The embedded generation installer often nominates an export limit during the initial application, and Essential Energy has suggested appropriate export limits depending on network limitations and the size of the installation. Going forward, Essential Energy s focus is to identify more efficient options to address the issue of large increases in low voltage network voltage swing brought about by localised pockets of embedded generation, for the long term interests of energy consumers. A potential emerging issue likely to be experienced is the requirement for capital investment to resolve issues caused solely by the connection of embedded generation. This is a long term network issue, experienced as embedded generation penetration rates continue to increase under the current tariff structures. For Public Release December 2015 Page 174 of 183

In simple terms, as network investment to resolve issues caused by the connection of embedded generation occurs, connected embedded generation reduces the revenue being recovered over the life of that investment to a value below that of the investment required. This creates inequity, leaving the revenue burden on unrelated customers that are likely not to have embedded generation. This is an emerging issue that will be monitored to inform future network strategies. 8.4 Generation Connection Details We are unable to differentiate between embedded generation enquiries and general connection enquiries as only simple statistics are recorded. The telephone statistics are based on the number of calls through 13 21 91 and selected option 4 (for Network Connections, including solar), and the online portal counts total number of enquiries. An average of approximately 1500 applications per month are processed relating to embedded generation, down from an average of 1800 per month last financial year. Table 11 - Connection enquiries and applications Connection Enquiries and Applications Number 2014/15 Phone connection enquiries (general and generation) 18,732 Online Enquiries Portal connection enquiries (general and generation) generation applications processed 17,949 Days to process generation applications 1.6 467 Figure 6 - Monthly record of processed Generation applications for the 2014/15 Financial Year For Public Release December 2015 Page 175 of 183

9 INVESTMENTS in METERING and INFORMATION TECHNOLOGY 9.1 Metering Essential Energy s current meter population consists of a mix of accumulation, interval data and smart type meters. Metering assets are required to meet complex statutory and regulatory requirements including meter performance obligations as defined by AEMO to ensure accuracy of energy consumption recorded. Sample tests are conducted and meter types that fail to meet the required targets are replaced. Each technology change in meter type achieves greater benefits from additional functionality. However, an increase in support costs is required to achieve that functionality and the additional capital and operational expenditure required to deploy and support an interval or smart meter population must be offset against benefits to the network business. The significant changes that have occurred in the metering industry within Australia and the forecast changes to the NEM Rules means that the metering and tariff strategies need to be frequently monitored and reviewed. It is anticipated that a program of deployment of smart meters for residential customers will occur from 1 December 2017. This date is dependent on AEMC releasing its final rule determination on the Competition in Metering and Related Services due 26 November 2015. The program could be led either by electricity retailers or a third party metering service provider. In the short term Essential Energy will continue its current strategy of utilising the default meter for the situation and meter replacement will continue as per compliance sample testing. Actual and forecast meter replacements and metering expenditure for the previous year and five year forecast period are shown in Table 12 and Table 13. Table 12 - Meter Change Program Meter Type Actual Forecast 14/15 15/16 16/17 17/18 18/19 19/20 Single Phase 13,136 30,520 30,520 30,520 30,520 0 Three Phase 0 5,100 5,100 14,514 14,514 14,514 Table 13 - Metering Asset Expenditure Program Type Actual Proposed $M $M 14/15 15/16 16/17 17/18 18/19 19/20 Meters New/Upgrades 2.85 2.31 4.83 2.42 2.33 2.33 Relays New/Upgrades 0.33 0.27 0.27 0.27 0.27 0.27 Meter Refurbishment 1.96 5.45 5.62 7.64 7.5 3.5 Relay Refurbishment 1.97 2.81 2.81 2.81 2.81 2.81 Meters Zone Sub PQ 0.00 0.29 0.27 0.28 0.29 0.28 For Public Release December 2015 Page 176 of 183

9.2 Information Technology Essential Energy s Information Communication and Technology (ICT) assets provide the organisation with the systems and tools necessary for the ongoing operation of the business. They are essential for the business to effectively and efficiently perform its mission, meet the requirements of its stakeholders, and achieve its vision and objectives. ICT assets are divided into two general categories: Hardware hardware assets include end user systems such as PCs and telecommunications devices, network, as well as ICT platforms such as servers and data storage. Software software assets are the systems used to support the business and range from corporate systems (e.g. PeopleSoft) to end user applications (e.g. MS Office Suite). Table 14 - Major Corporate Software Assets Product/Application Vendor Implemented Version Server Operating System Year Implemented Active Directory Microsoft 2008 R2 Windows 2001 Adapter for Active Database TIBCO 6.3.0 Linux 2004 Administrator TIBCO 5.7.1 Linux 2004 Business Works TIBCO 5.10.0 Windows/Linux 2004 BusinessWorks EJB Plugin BusinessWorks SmartMapper TIBCO 5.3.0 Linux 2004 TIBCO 5.5.0 Linux 2004 Call Taker GE 5.2.2.7.0.6 Windows 2005 Contact Management System (CMS) - Networks Cognos Corporate Website CRM Dashboard Essential Energy N/A AIX (Lotus Notes) 2012 IBM Essential Energy Oracle IBM/Cognos Deliveryware Esker 5.0 Windows 2004 EDDiS Essential Energy N/A Windows 1998 E-Health Computer Associates 6.2 Windows 2005 Email IBM 8.5.1 AIX 1995 EnergyWeb Hansen 7.2 2004 Esker Esker 2000 For Public Release December 2015 Page 177 of 183

Product/Application Vendor Implemented Version Server Operating System Year Implemented EssentialNet Microsoft Sharepoint 2010 2011 Flowtalk Hansen 5.0.2 Meter Reading Geomatic 3.5.2648 Hosted (Unknown) 2011 MR6 IVR Message recorder ILW Communications Custom Windows 2001 Hawk TIBCO 4.9.0 Windows/Linux 2004 HRMS Oracle 8.8 Windows/Linux 2002 IT Wiki mediawiki.org 1.17.0 Linux 2011 Job Scheduling System (JSS) Yambay 5.3.3 Windows 2012 EnergyWeb (PeacePlus) Hansen 9.00SP15 AIX/Linux 2004 Field Service System (FSS - mdrover) Yambay 5.3.3 Windows 2012 FSCM Oracle 8.49 Windows/Linux 2002 LANDesk LANDesk 9.5 Microsoft Office Microsoft 2010 and 2013 Windows 2012 NECF Portal (PeacePlus) Hansen 9.00SP15 Linux 2013 Network Operations Portal Network Status and Environment (NSE) Essential Energy N/A Windows 2012 Essential Energy N/A Windows 2012 Openwave Openwave Citrix Oracle Enterprise Manager Oracle 11gR1 Linux/AIX 2008 CIS (PeacePlus) Hansen 9.00SP15 AIX/Linux/Window s 1998 PeopleSoft Oracle 9.2 Windows/Unix 2015 Portal Oracle 8.4 Windows/Linux 2003 Power-On Fusion GE 5.2.2.7.0.6 Linux 2012 Rendezvous TIBCO 8.3.2 Windows/Linux 2004 Sametime IBM 8.0.2 AIX 1995 System Centre Config Manager Microsoft Windows 2014 For Public Release December 2015 Page 178 of 183

Product/Application Vendor Implemented Version Server Operating System Year Implemented Service Manager VMWare 9.1.1 Sharepoint Microsoft 2010 Spectrum Computer Associates 9.2.1.5.104 Windows 2005 Network Access Requests GE 3.8.10.11 Windows 2009 TIBCO Runtime Agent TIBCO 5.7.0 Windows/Linux 2004 Traveller Wave (Radio) IBM Systec/Twisted Pair 5.7.3 Windows 2006 Webview GE 7.01 Windows 2005 Whispir Whispir To ensure that ICT expenditure is justified and effective, Essential Energy prioritises ICT project outcomes based on: meeting regulatory and legal compliance obligations maintaining core capabilities within the organisational risk envelope supporting strategic efficiency objectives. ICT investment for the 2015/16 to 2018/19 period will be $72 M. The major business program projects included in are: Table 15 - Major Business Program Projects Major Business Projects Forecast FY15-19 $M Asset Management 19.2 Works Management 7.3 PowerOn Fusion upgrade 6.9 Peoplesoft capability leverage 5.2 Smallworld upgrade and integration 4.5 Data Management 3.3 For Public Release December 2015 Page 179 of 183

Table 16 shows the total ICT AER proposal for the 2014/15 to 2018/19 period: Table 16 - ICT Asset Proposal Category FY15 (Results) FY16 FY17 FY18 FY19 FY15-19 Application upgrades 1.44 1.75 1.63 1.46 1.33 7.61 Asset Management 0.00 0.00 6.28 12.94 0.00 19.22 Customer 0.00 0.40 0.05 0.00 0.00 0.45 Data Management 0.09 1.21 1.58 0.42 0.00 3.30 Document Management 0.00 0.00 0.52 0.00 0.00 0.52 ICT - Comms 0.02 1.40 0.00 0.00 0.00 1.43 ICT device management 0.84 1.31 0.42 0.42 0.42 3.42 ICT - foundation 0.00 2.44 1.93 0.95 0.54 5.86 ICT modernisation and transformation 4.42 5.88 1.29 0.00 0.00 11.59 ICT miscellaneous -0.02 0.00 0.00 0.00 0.00-0.02 Network Billing and CIS 5.87 0.00 0.00 0.00 0.00 5.87 PeopleSoft 8.00 1.94 2.66 0.57 0.00 13.17 Security 0.00 0.40 0.00 0.00 0.00 0.40 Smallworld 0.21 0.92 1.72 1.90 0.00 4.75 Smart Vehicles 0.15 0.08 0.12 0.12 0.12 0.60 Vegetation Management 2.32 0.00 0.00 0.00 0.00 2.32 Workflow Automation 0.00 0.45 0.12 0.15 0.00 0.71 Works Management 0.00 0.21 4.46 2.58 0.00 7.25 Total 23.66 18.65 22.79 26.16 4.44 95.69 For Public Release December 2015 Page 180 of 183

10 REGIONAL DEVELOPMENT PLANS The tables in the preceding sections (1-10) are structured along Essential Energy s planning hierarchy of: Operational Region > Connection Point > Subtransmission > Subtransmission > Zone > Distribution Feeder. Semi-geographic single line diagrams of the electrical network for each supply area have been included in the relevant sections of the Zone and Subtransmission feeder demand forecasts and where system limitations have been identified these are noted on those diagrams. The maps in Figure 7 show the operational regions and the major supply points associated with each region. The four regions applied for the majority of the time period covered by this document, though recently Essential Energy has consolidated into only three regions. For Public Release December 2015 Page 181 of 183

Figure 7 - Diagram of Essential Operational Regions Regions to 5 October 2015 Regions from 6 October 2015 For Public Release December 2015 Page 182 of 183

11 GLOSSARY AEMC AEMO AER AMP CVR DNSP GWh ICT IPART MEPS MVA MVAr MW NECF NEM NER pf RIT-D STS SAIDI SAIFI STPIS Sw Stn TNSP Tx ZS Australian Energy Market Commission Australian Energy Market Operator Australian Energy Regulator Asset Management Plan Conservation Voltage Reduction Distribution Network Service Provider Gigawatt-Hour Information and Communication Technology Independent Pricing and Regulatory Tribunal Kilovolt Minimum Energy Performance Standards Megavolt-Ampere Megavolt-Ampere-Reactive Megawatt National Electricity Customer Framework National Energy Market National Electricity Rules Power Factor Regulatory Investment Test for Distribution Subtransmission System Average Interruption Duration Index System Average Interruption Frequency Index Service Target Performance Incentive Scheme Switching Station Transmission Network Service Provider Transformer Zone For Public Release December 2015 Page 183 of 183