2010 SMART GRID INVESTMENTS OPERATIONS

Transcription

1 EB-00-0 Exhibit G Tab Schedule Page of 00 SMART GRID INVESTMENTS OPERATIONS 0 FEEDER AUTOMATION Feeder automation ( FA ) is identified as a key priority of THESL s smart grid implementation to mitigate reliability impacts. Additionally, as more distributed generation and energy storage is embedded in the network, automation will be necessary to manage network complexities and maintain network reliability. Through a thorough and prudent vendor selection process, THESL identified that the SCADA (Supervisory Control and Data Acquisition)-controlled switches that THESL has been installing as part of its standard is the most suitable to be leveraged to perform self-healing capabilities (i.e., automatic fault detection, location, sectionalisation, isolation, and restoration). Currently THESL has installed over 00 such switches. 0 The objective of this project is to apply the feeder automation scheme to new and existing SCADA-controlled switches, essentially restoring customers on healthy sections of a feeder during fault within 0 seconds of the interruption. The scope of this demonstration includes the automation of all ten feeders in the Smart Community, which have been identified as worst performing feeders ( WPF ) or Feeders Experiencing Sustained Interruptions seven or more times ( FESI- ). Proposed work includes: Installation of new intelligent switches; Retrofit of existing intelligent switches; Radios, repeaters, and antennas to enable peer-to-peer and SCADA communications; Software to implement the self-healing algorithm; Interface at the substation to coordinate the feeder breaker with downstream switches;

2 EB-00-0 Exhibit G Tab Schedule Page of Control room applications; and Enterprise systems integration. 0 Expected benefits of the project include: Immediate reliability and customer experience improvements by reducing interruption time of customers on non-faulted sections of a feeder to less than 0 seconds; Improved location of the fault and efficient dispatch of crew resources; Increased visibility, control, and operational flexibility; Improved safety through automated operation of switching devices, with operator/field override at any moment; and Maintenance/improvement of network reliability (e.g., SAIFI/SAIDI). 0 Deferral of this project will result in an unacceptable and/or continued decline of reliability of these worst performing feeders. Alternatives in mitigating such reliability problems include asset replacement and aggressive maintenance plans, which tend to be more costly, resource intensive, and disruptive to customers. This technology solution has been in commercialization for over ten years, and is fieldproven to be highly effective and dependable in other utilities. THESL also has in-depth knowledge and substantial experience with the installation, operation, and maintenance of such switches. Further work includes development of work procedures to ensure safe operation in an automated system under normal and abnormal operating conditions, and the commensurate extensive training that accompanies technology-based solutions. Measures must be in place to ensure that the intelligent switches themselves are reliable and completely fail-safe. Upon a successful demonstration of this scheme it is expected

3 EB-00-0 Exhibit G Tab Schedule Page of that the automation will be incorporated into other poor-reliability areas of the service territory and areas where network operations are more complex. The project costs are summarized in Table below. Table : Summary of Project Costs Project Description Capital Cost ($000s) Feeder Automation Intelligent switching to realize a self healing grid,0 0 SECONDARY NETWORK AUTOMATION The underground secondary network is one of the most reliable systems in Toronto. Yet it is also one of the oldest and most complicated systems in Toronto. Failures are uncommon, but by design they tend to be low-probability high-impact outages. Though it is built with relaying in the network protectors, the relays are not intelligent relays and therefore the protector has no communication capabilities. 0 This project aims to incorporate remote monitoring and automated control into the underground secondary network, located in the former Toronto district. The scope of work includes installation of microprocessor relaying and SCADA communications to at least one network location. Sensors will also monitor vault conditions such as transformer loading, temperature, and flooding. This is the only 00 smart grid project that is not specifically piloted in the Smart Community area. Expected benefits include: Increased visibility and control of the secondary network, including the ability to monitor network conditions;

4 EB-00-0 Exhibit G Tab Schedule Page of Proactive actions to mitigate or eliminate faults and outages in major load centres (i.e., downtown Toronto); Improved management of network assets; Monitoring and management of the effects of increased penetration of distributed generation within a secondary network; and Maintenance/improvement of network reliability (e.g., SAIFI/SAIDI) 0 Deferral of this project will risk high impact outage situations in the downtown system when there is a fault in the network unit or in the secondary grid. Furthermore, to maximize reliability in the urban core, by design the protection and control in the secondary network topology does not allow power to be exported from the network. Therefore not monitoring the impacts of distributed generation in a secondary network may result in widespread tripping of the system. This technology solution has been in commercialization for many years, and is fieldproven by many large utilities that have secondary network grids. Since the technology is very mature, training and development of work practices for this project is seen as relatively low in risk. Upon a successful demonstration, it is expected that this automation will continue to be incorporated in the secondary network system. 0 The project costs are summarized in Table below. Table : Summary of Project Costs Project Description Capital Cost ($000s) Secondary Network Automation Microprocessor relays and SCADA communications in the secondary network

5 EB-00-0 Exhibit G Tab Schedule Page of 0 0 TRANSFORMER SMART METERING The provincial mandate for installing smart meters and implementation of an Advanced Metering Infrastructure ( AMI ) was the initial effort in moving towards a smart grid. Leveraging on the AMI and extending from smart meters, THESL plans to deploy smart meters on distribution transformers to enable additional new services. THESL anticipates that this will be one of the most valuable projects in the 00 smart grid portfolio. The scope of this project includes: Installation of at least 00 transformer smart meters ( TSM ) on pole-top and pad-mount transformers; Communications through the smart meter local area network ( LAN ) or directly on the wide area network ( WAN ); Integration paths to the Operational Data Store ( ODS ) and other major enterprise systems Integration with customer, feeder, and station smart meter data; Interface to the control operators through the Outage Management System ( OMS ); and Applications interface to asset managers and other key stakeholders for decision support. Expected benefits include: Monitoring of real time impacts of distributed generation and plug-in electric and hybrid electric vehicles (power quality, voltage level, current, loading, etc.); Better management of transformer assets through transformer load monitoring (current, voltage, reactive power, apparent power, active power delivered and received, etc.); Once enabled by suitable communications, provision of near-real-time outage detection through last gasp messages from the transformer smart meter and reporting back to OMS;

6 EB-00-0 Exhibit G Tab Schedule Page of Detection of technical and non-technical losses through check metering with downstream smart meters; Improve transformer-to-customer connection relationships in information records; and Improve phase load balancing. 0 This project has been identified as a key enabler of a large penetration of distributed generation and plug-in vehicles on the distribution system, as well as improved reliability and asset management, support of energy conservation by reducing losses, and delivery of social benefits. The deferral of this project may risk the ability to connect distributed energy, as well as a missed opportunity to harness the potential of the established AMI. 0 Technology solutions for this project have recently been commercialized, though largescale deployments have not yet occurred. The technology is nevertheless mature and based on proven metering, sensing, and communication technologies. The challenge in this project lies in the integrating THESL s communication system with enterprise architecture, and applying information into new services. Since the project is largely an extension of the existing AMI, it is perceived to be a low-risk project. Upon a successful demonstration, it is expected that transformer metering will be fully deployed in the Smart Community and extended into other areas of THESL s service territory. The project costs are summarized in Table below. Table : Summary of Project Costs Project Description Capital Cost ($000s) Transformer Smart Metering Smart meters installed on distribution transformers

7 EB-00-0 Exhibit G Tab Schedule Page of POWER LINE MONITORING On the existing distribution system there is no monitoring equipment installed on overhead conductor lines except for intelligent switches used for feeder automation. The objective of this project is to enhance visibility of the operating conditions of these overhead conductors through the installation of power line monitors ( PLMs ). 0 The scope of this project is to install PLMs on all ten feeders in the Smart Community pilot area. Proposed work includes: Installation of over 0 PLMs, with bidirectional loading, conductor temperature, programmable fault indication, and waveform capture capabilities; Communications through proprietary LAN or directly on the WAN; Integration paths to major enterprise systems; Interface to the control operators through the OMS; and Applications interface to asset managers and other key stakeholders for decision support, such as for capacity and reliability planning. 0 Expected benefits include: Monitoring of real time impacts of distributed generation and plug-in electric and hybrid electric vehicles (power quality, voltage level, current, etc.); Better management of overhead conductor assets through real-time monitoring (current, conductor temperature, etc.); Operational flexibility through better understanding of real time grid conditions; Better identification of outage causes through waveform capture upon a fault; Once enabled by suitable communications, provision of near real-time outage detection reporting back to OMS; Enablement of adaptive protection (programmable fault indication) to match dynamic feeder configurations and distributed generation penetration levels; and

8 EB-00-0 Exhibit G Tab Schedule Page of Detection of technical and non-technical losses through check metering with downstream customer and transformer smart meters. This project has been identified to be a key enabler of large penetration of distributed generation and plug-in vehicles on the distribution system, as well as improved reliability and asset management, and energy conservation by monitoring losses. The deferral of this project may impair the ability to promptly connect distributed energy and create a missed opportunity to improve reliability. 0 Technology solutions for this project are approaching commercialization, and are ready for demonstration. The challenge in this project lies in the integration with THESL s communication system, enterprise architecture, and application of information into new services. LAN communication is currently proprietary but opportunities do exist to leverage other existing networks or the WAN. Upon a successful demonstration, it is expected that power line monitoring will be fully deployed in the Smart Community and extended into other areas of the service territory. The project costs are summarized in Table below. 0 Table : Summary of Project Costs Project Description Capital Cost ($000s) Power Line Monitoring Monitors installed on overhead line conductors SUBMERSIBLE VAULT MONITORING On the existing distribution system there is no monitoring equipment installed in submersible transformer vaults. The objective of this project is to enhance visibility of

9 EB-00-0 Exhibit G Tab Schedule Page of the operating and environmental conditions of these submersible vaults through the installation of vault monitors ( VMs ). 0 The scope of this project is to install vault monitors in strategic locations in the demonstration area. Proposed work includes: Installation of over five vault monitors, with a transformer smart meter, flood, and temperature sensing capabilities; Communications through proprietary LAN or directly on the WAN; and Applications interface to asset managers and other key stakeholders for decision support, such as for real time condition based maintenance. 0 Expected benefits include: Better management of vault assets through real time monitoring (current, temperature, etc.), and particularly, extended asset life through better management of the environment; Once enabled by suitable communications, provision of near real-time outage detection through last gasp messages from the transformer smart meter and reporting back to OMS; Detection of technical and non-technical losses through check metering with downstream smart meters; Improved transformer-to-customer connection relationships in information records; and Increased ability to monitor vault conditions to take proactive actions that either mitigate the extent of or eliminate a fault/outage. This project offers the same potential benefits as the transformer smart meter, as well as the added capability to monitor and report on adverse vault conditions in real time to take proactive actions. The deferral of this project may impair the ability to connect

10 EB-00-0 Exhibit G Tab Schedule Page 0 of distributed energy promptly and create a missed opportunity to improve reliability and mitigate potential high risk situations in submersible vaults. Excluding the transformer smart meters (discussed previously), the technology solutions for this project are in their developmental phase and approaching commercialization. The challenge lies in integrating sensors with the transformer monitor as well as with the THESL enterprise architecture. LAN communications is currently proprietary but opportunities do exist to leverage other existing networks or the WAN. This project will focus on product demonstration and co-development to work towards commercialization. 0 The project costs are summarized in Table below. Table : Summary of Project Costs Project Description Submersible Vault Monitors installed in submersible transformer Monitoring vaults Capital Cost ($000s) 0 0 ENVIRONMENTAL SUSTAINMENT Two of the greatest changes that the Green Energy and Green Economy Act, 00 brings to THESL are the obligation to connect generation and the ability to own generation. The advanced feed-in tariff ( FIT ) program managed by the Ontario Power Authority is also expected to rapidly accelerate distributed generation adoption. Given that the distribution system was designed assuming a unidirectional power flow, the system capacities, protection and control, and operating procedures will have to be reviewed assuming distributed generation and bi-directional power flow. Energy storage technologies also exhibit great potential in this network though their benefits and the impacts must be thoroughly investigated.

11 EB-00-0 Exhibit G Tab Schedule Page of THESL previously engaged the University of Toronto and Navigant Consulting to assess and determine how to mitigate the impacts of distributed generation on the distribution system. Much has been learned through these activities. Nevertheless, during a rapid adoption phase enabled by the GEA and FIT program, it is expected that further studies and planning will be necessary to facilitate the provincial mandate. 0 Further to the accommodation of renewable generation and storage, the electrification of transportation, in particular through the influx of plug-in electric and hybrid electric vehicles, presents new challenges to THESL. Driven by the state of the economy and need to stimulate the transportation sector, these challenges include uncertain consumption patterns, higher demands on system capacity, lack of interconnection standards, and power quality concerns. 0 Moreover, the need for utilities to provide information, tools, and services to customers to enable more effective and sustainable energy conservation and demand management programs presents challenges to the LDC. The smart grid is a key enabler of such programs, yet there remain uncertainties regarding communication methods, information to be presented, and tools and interfaces that will yield the most effective and sustainable conservation efforts. The objective of the Environment Sustainment initiative is to investigate and demonstrate measures to facilitate the connection of distributed energy and electrified transportation on the distribution system, as well as to investigate effective programs for customer energy management. Projects that are currently committed include: Demonstration of up to ten smart homes in Toronto, including demonstration of in-home displays, smart appliances, web portals, home area networks, and mobile device controls, supported by behavioural science analyses; and

12 EB-00-0 Exhibit G Tab Schedule Page of Development of smart grid planning guidelines for THESL asset managers, including policy, strategy, long term planning, short term planning, standards, and supply chain requirements. 0 0 Moreover, THESL is considering further potential initiatives based on meeting requirements of the GEA: Detailed studies to further accommodate the deployment of large numbers of distributed generation and energy storage, in particular small scale solar. Establishment of connection requirements, billing and settlement requirements, and mitigation strategies to secure and strengthen the grid in a distributed energy network; Establishment of streamlined processes, such as a one-stop shop online portal, to facilitate the connection of renewable generation onto the THESL system; Detailed studies to assess the system impact of plug-in electric or hybrid electric vehicles, including loading profiles, location impacts, and power quality impacts; and Demonstration of plug-in electric or hybrid electric vehicles, including electrical connection, monitoring, communication, control, billing, and settlement requirements. These initiatives are necessary steps for THESL to gain insight into facilitating the deployment of distributed energy and plug-in vehicles, and to better understand what services and tools, enabled by the smart grid, are effective in establishing sustained customer energy management. Measures will be taken to ensure that results and lessons learned will be shared in the industry to avoid duplicative efforts, through avenues such as the Ontario Smart Grid Forum, EDA, IEEE, CEATI, and various conferences and working groups.

13 EB-00-0 Exhibit G Tab Schedule Page of The project costs are summarized in Table below. Table : Summary of Project Costs Project Description Environmental Studies and demonstrations to support the Sustainment connection of distributed generation and plug-in vehicles, and in developing effective customer management programs Operating Cost ($000s) 0